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{{#Wiki_filter:LICENSE RENEWAL APPLICATION LaSalle County Station, Units 1 and 2 Facility Operating License Nos.NPF-11 and NPF-18 This Page Intentionally Left Blank Table of Contents TABLE OF CONTENTS SECTION 1 Administrative Information
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===1.0 ADMINISTRATIVE===
 
INFORMATION
.......................................................
1-1 1.1 GENERAL INFORMATION
-10 CFR 54.19 ..........................................
1-1 1.1.1 N am e of A pplica nt ...................................................................................
1-1 1.1.2 A dd ress of A pplicant ...............................................................................
1-1 1.1.3 Descriptions of Business or Occupation of Applicant
..............................
1-1 1.1.4 Descriptions of Organization and Management of Applicant
..................
1-1 1.1.5 Class of License, Use of the Facility, and Period of Time for W hich the License Is Sought ..................................................................
1-2 1.1.6 Earliest and Latest Dates for Alterations, If Proposed ............................
1-2 1.1.7 Restricted Data ...............
.... ... .......................
1-3 1.1.8 R eg ulatory A ge ncies ...............................................................................
1-3 1.1.9 Local N ew s P ublications
.........................................................................
1-3 1.1.10 Conforming Changes to Standard Indemnity Agreement
.......................
1-4 1.2 GENERAL LICENSE INFORMATION
....................................................
1-5 1.2.1 Application Updates, Renewed Licenses, and Renewal T e rm O pe ratio n ......................................................................................
1-5 1.2.2 Incorporation by R eference .....................................................................
1-5 1.2 .3 C ontact Inform ation .................................................................................
1-5 1 .3 P U R P O S E ..............................................................................................
1-6
 
==1.4 DESCRIPTION==
 
OF THE PLANT ............................................................
1-6 1.5 APPLICATION STRUCTURE
.................................................................
1-6 1.6 A C R O N Y M S .........................................................................................
1-10 1.7 GENERAL REFERENCES
...................................................................
1-13 LaSalle County Station, Units 1 and 2 License Renewal Application Page ii Table of Contents SECTION 2 2.0 SCOPING AND SCREENING METHODOLOGY FOR IDENTIFYING STRUCTURES AND COMPONENTS SUBJECT TO AGING MANAGEMENT REVIEW, AND IMPLEMENTATION RESULTS .............
2.0-1 2.1 SCOPING AND SCREENING METHODOLOGY
.......................................
2.1-1 2 .1 .1 Intro d u ctio n ..........................................................................................
2 .1-1 2.1.2 Information Sources Used for Scoping and Screening
........................
2.1-4 2.1.3 Technical Basis Documents
................................................................
2.1-5 2.1.4 Interim Staff Guidance Discussion
....................................................
2.1-15 2.1.5 S coping P rocedure ............................................................................
2.1-17 2.1.6 S creening P rocedure .........................................................................
2.1-27 2.1.7 G eneric Safety Issues .......................................................................
2.1-35 2 .1 .8 C o n clus io n .........................................................................................
2 .1-3 5 2.2 PLANT LEVEL SCOPING RESULTS ........................................................
2.2-1 2.3 SCOPING AND SCREENING RESULTS: MECHANICAL
.......................
2.3-1 2.3.1 Reactor Vessel, Internals, and Reactor Coolant System ...............
2.3-1 2.3.1.1 Reactor Coolant Pressure Boundary System .............................
2.3-2 2 .3.1.2 R eactor V esse l ...........................................................................
2 .3-7 2.3.1.3 Reactor Vessel Internals
...........................................................
2.3-12 2.3.2 Engineered Safety Features Systems ...........................................
2.3-16 2.3.2.1 High Pressure Core Spray System ...........................................
2.3-17 2.3.2.2 Low Pressure Core Spray System ............................................
2.3-21 2.3.2.3 Reactor Core Isolation Cooling System ....................................
2.3-25 2.3.2.4 Residual Heat Removal System ...............................................
2.3-29 2.3.2.5 Standby Gas Treatment System ...............................................
2.3-34 2.3.3 A uxiliary S ystem s ............................................................................
2.3-37 2.3.3.1 Closed Cycle Cooling Water System ........................................
2.3-38 2.3.3.2 Combustible Gas Control System .............................................
2.3-42 2.3.3.3 Compressed Air System ...........................................................
2.3-46 2.3.3.4 Control Rod Drive System ........................................................
2.3-48 2.3.3.5 Control Room Ventilation System .............................................
2.3-53 2.3.3.6 Cranes, Hoists and Refueling Equipment System ....................
2.3-58 2.3.3.7 Demineralizer Water Makeup System ......................................
2.3-61 2.3.3.8 Diesel Generator and Auxiliaries System .................................
2.3-64 2.3.3.9 Drywell Pneumatic System .......................................................
2.3-70 2.3.3.10 Electrical Penetration Pressurization System ...........................
2.3-74 2.3.3.11 Essential Cooling Water System ..............................................
2.3-76 2.3.3.12 Fire Protection System .............................................................
2.3-81 LaSalle County Station, Units 1 and 2 License Renewal Application Page iii Table of Contents 2.3.3.13 Fuel Pool Cooling and Storage System ....................................
2.3-86 2.3.3.14 Nonessential Cooling Water System ........................................
2.3-90 2.3.3.15 Nonsafety-Related Ventilation System .....................................
2.3-95 2.3.3.16 Plant Drainage System .............................................................
2.3-98 2.3.3.17 Primary Containment Ventilation System ...............................
2.3-105 2.3.3.18 Process Radiation Monitoring System ....................................
2.3-109 2.3.3.19 Process Sampling and Post Accident Monitoring System ...... 2.3-114 2.3.3.20 Radw aste System ...................................................................
2.3-119 2.3.3.21 Reactor Water Cleanup System .............................................
2.3-122 2.3.3.22 Safety-Related Ventilation System .........................................
2.3-126 2.3.3.23 Standby Liquid Control System ..............................................
2.3-131 2.3.3.24 Suppression Pool Cleanup System ........................................
2.3-134 2.3.3.25 Traversing Incore Probe System ............................................
2.3-136 2.3.4 Steam and Power Conversion System .....................
2.3-139 2.3.4.1 Condensate System ...............................................................
2.3-140 2.3.4.2 Condenser and Air Removal System ......................................
2.3-145 2.3.4.3 Feedw ater System ..................................................................
2.3-148 2.3.4.4 Main Steam System ................................................................
2.3-152 2.3.4.5 Main Turbine and Auxiliaries System ....................................
2.3-156 2.4 SCOPING AND SCREENING RESULTS: STRUCTURES AND COMPONENT SUPPORTS ........................................................................
2.4-1 2 .4 .1 A uxiliary B uild ing ........................................................................
2 .4-2 2.4.2 Component Supports Commodity Group ....................................
2.4-7 2 .4 .3 C oo ling Lake .............................................................................
2 .4 -11 2.4.4 Diesel Generator Building .........................................................
2.4-16 2.4.5 Lake Screen House ..................................................................
2.4-20 2 .4 .6 O ffgas B uilding .........................................................................
2.4-25 2.4.7 Prim ary C ontainm ent ................................................................
2.4-28 2.4.8 R adw aste B uilding ....................................................................
2.4-37 2.4 .9 R eactor B uilding .......................................................................
2.4-4 1 2.4.10 Structural Commodity Group ....................................................
2.4-47 2.4.11 Sw itchyard Structures
...............................................................
2.4-53 2.4.12 Tank Foundations and Dikes ....................................................
2.4-56 2 .4 .13 T urbine B uilding ........................................................................
2 .4-59 2.4 .14 Y ard S tructures
.........................................................................
2.4-63 2.5 SCOPING AND SCREENING RESULTS: ELECTRICAL
..........................
2.5-1 2.5.1 Electrical Systems ................................
2.5-1 2.5.2 Electrical C om m odities ...............................................................
2.5-1 2.5.2.1 Identification of Electrical Commodities
....................................
2.5-1 2.5.2.2 Application of Screening Criterion 10 CFR 54.21 (a)(1)(i) to the Electrical Components and Commodities
...................................
2.5-3 2.5.2.3 Elimination of Electrical Commodity Groups With No License Renewal Intended Functions
..................................
2.5-3 2.5.2.4 Application of Screening Criteria 10 CFR 54.21 (a)(1)(ii) to E lectrical C om m odities ...............................................................
2.5-4 LaSalle County Station, Units 1 and 2 Page iv License Renewal Application Table of Contents 2.5.2.5 Electrical Commodities Subject to Aging Management Review 2.5-5 2.5.2.5.1 Cable Connections (Metallic Parts) ............................................
2.5-5 2.5.2.5.2 Electrical Penetrations
................................................................
2.5-5 2.5.2.5.3 High Voltage Insulators
...............................................................
2.5-5 2.5.2.5.4 Insulation Material for Electrical Cables and Connections
..........
2.5-5 2.5.2.5.5 Metal Enclosed Bus ....................................................................
2.5-6 2.5.2.5.6 Switchyard Bus and Connections, Transmission Conductors, and Transmission Connectors
....................................................
2.5-6 LaSalle County Station, Units 1 and 2 License Renewal Application Page v Table of Contents SECTION 3 3.0 AGING MANAGEMENT REVIEW RESULTS ............................................
3.0-1 3.1 AGING MANAGEMENT OF REACTOR VESSEL, INTERNALS AND REACTOR COOLANT SYSTEM ................................................................
3.1-1 3 .1 .1 Intro d u ctio n ..........................................................................................
3 .1-1 3 .1 .2 R e s u lts .................................................................................................
3 .1-1 3.1.2.1 Materials, Environments, Aging Effects Requiring Management and Aging Management Programs ......................................................
3.1-1 3.1.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport .............................................................................
3 .1-6 3.1.2.3 Time-Limited Aging Analysis .............................................................
3.1-14 3 .1 .3 C o n clu sio n .........................................................................................
3 .1-14 3.2 AGING MANAGEMENT OF ENGINEERED SAFETY FEATURES ...........
3.2-1 3 .2 .1 Intro d u ctio n ..........................................................................................
3 .2 -1 3 .2 .2 R e s u lts .................................................................................................
3 .2 -1 3.2.2.1 Materials, Environments, Aging Effects Requiring Management and Aging Management Programs ......................................................
3.2-1 3.2.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport .............................................................................
3.2-7 3.2.2.3 Time-Limited Aging Analysis .............................................................
3.2-12 3 .2 .3 C onclusion
........................................................................................
3.2-12 3.3 AGING MANAGEMENT OF AUXILIARY SYSTEMS ................................
3.3-1 3 .3 .1 Intro d uctio n ..........................................................................................
3 .3 -1 3 .3 .2 R e s u lts .................................................................................................
3 .3 -2 3.3.2.1 Materials, Environments, Aging Effects Requiring Management And Aging Management Programs .....................................................
3.3-3 3.3.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport ...........................................................................
3.3-30 3.3.2.3 Time-Limited Aging Analysis .............................................................
3.3-35 3 .3 .3 C o nclusio n .........................................................................................
3 .3-3 5 3.4 AGING MANAGEMENT OF STEAM AND POWER CONVERSION S Y S T E M ....................................................................................................
3 .4 -1 3 .4 .1 Intro d u ctio n ..........................................................................................
3 .4 -1 3 .4 .2 R e s u lts .................................................................................................
3 .4 -1 3.4.2.1 Materials, Environments, Aging Effects Requiring Management and Aging Management Programs .............................................................
3.4-1 3.4.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport ..................................................................................
3.4-6 3.4.2.3 Time-Limited Aging Analysis ...............................................................
3.4-9 3 .4 .3 C o nclusio n .........................................................................................
3 .4 -10 LaSalle County Station, Units 1 and 2 License Renewal Application Page vi Table of Contents 3.5 AGING MANAGEMENT OF STRUCTURES AND COMPONENT S U P P O R T S ................................................................................................
3 .5-1 3 .5 .1 Intro d u ctio n ..........................................................................................
3 .5-1 3 .5 .2 R e s u lts .................................................................................................
3 .5 -1 3.5.2.1 Materials, Environments, Aging Effects Requiring Management and Aging Management Programs ......................................................
3.5-2 3.5.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport ...........................................................................
3.5-19 3.5.2.3 Time-Limited Aging Analysis .............................................................
3.5-30 3 .5 .3 C o nclusio n .........................................................................................
3 .5-3 1 3.6 AGING MANAGEMENT OF ELECTRICAL COMPONENTS
....................
3.6-1 3 .6 .1 Intro d uctio n ..........................................................................................
3 .6 -1 3 .6 .2 R e s u lts .................................................................................................
3 .6 -1 3.6.2.1 Materials, Environments, Aging Effects Requiring Management And Aging Management Programs ....................................................
3.6-1 3.6.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport .............................................................................
3.6-5 3.6.2.3 AMR Results Not Consistent With or Not Addressed in the GALL R e p o rt ................................................................................................
3 .6 -1 0 3.6.2.4 Time-Limited Aging Analysis .............................................................
3.6-11 3 .6 .3 C o nclusio n .........................................................................................
3 .6 -1 1 SECTION 4 4.0 TIME-LIMITED AGING ANALYSES .............................................................
4-1 4.1 IDENTIFICATION AND EVALUATION OF TIME-LIMITED AGING A N A L Y S E S ...................................................................................................
4 -1 4.1.1 Identification of LSCS Time-Limited Aging Analyses ..............................
4-1 4.1.2 Evaluation of LSCS Time-Limited Aging Analyses .................................
4-3 4 .1.3 A cceptance C riteria .................................................................................
4-3 4 .1.4 S um m ary of R esults ................................................................................
4-4 4.1.5 Identification of Exemptions Pursuant to 10 CFR 50.12 .........................
4-4 4.2 REACTOR VESSEL AND INTERNALS NEUTRON EMBRITTLEMENT A N A L Y S E S ...................................................................................................
4 -7 4.2.1 Neutron Fluence Analyses ......................................................................
4-9 4.2.2 Upper-Shelf Energy Analyses ...............................................................
4-22 4.2.3 Adjusted Reference Temperature Analyses .........................................
4-32 4.2.4 Pressure-Temperature Limits ................................................................
4-43 4.2.5 Axial Weld Failure Probability Assessment Analyses ...........................
4-44 4.2.6 Circumferential Weld Failure Probability Assessment Analyses ...........
4-47 4.2.7 Reactor Pressure Vessel Reflood Thermal Shock Analysis .................
4-51 4.2.8 RPV Core Plate Rim Hold-Down Bolt Loss of Preload Analysis ...........
4-57 LaSalle County Station, Units 1 and 2 License Renewal Application Page vii Table of Contents 4.2.9 Jet Pump Riser Brace Clamp Loss of Preload Analysis .......................
4-58 4.2.10 Jet Pump Slip Joint Repair Clamp Loss of Preload Analysis ................
4-59 4.3 M ETAL FATIG UE ANALYSES ...................................................................
4-60 4.3.1 ASME Section III, Class I Fatigue Analyses ........................................
4-60 4.3.2 ASME Section III, Class 2 and 3 and ANSI B31.1 Allowable Stress A n a ly se s ...............................................................................................
4 -7 4 4.3.3 Environmental Fatigue Analyses for RPV and Class 1 Piping ..............
4-76 4.3.4 Reactor Vessel Internals Fatigue Analyses ..........................................
4-90 4.3.5 High-Energy Line Break (HELB) Analyses Based on Fatigue .............
4-92 4.3.6 Main Steam Relief Valve Discharge Piping Fatigue Analyses ..............
4-93 4.4 ENVIRONMENTAL QUALIFICATION (EQ) OF ELECTRIC C O M P O N E N T S ..........................................................................................
4-95 4.4.1 Environmental Qualification (EQ) of Electric Components
...................
4-95 4.5 CONCRETE CONTAINMENT TENDON PRESTRESS ANALYSES ..........
4-98 4.5.1 Concrete Containment Tendon Prestress Analyses ............................
4-98 4.6 PRIMARY CONTAINMENT FATIGUE ANALYSES .................................
4-104 4.6.1 Primary Containment Liner and Penetrations Fatigue Analyses ........ 4-104 4.6.2 Primary Containment Refueling Bellows Fatigue Analysis ................
4-106 4.6.3 Primary Containment Downcomer Vents Fatigue Analysis ................
4-107 4.7 OTHER PLANT-SPECIFIC TIME-LIMITED AGING ANALYSES .............
4-109 4.7.1 Reactor Building Crane Cyclic Loading Analysis ................................
4-109 4.7.2 Main Steam Line Flow Restrictors Erosion Analysis ...........................
4-111 4 .8 R E F E R E N C E S .........................................................................................
4-112 List of Appendices APPENDIX A -FINAL SAFETY ANALYSIS REPORT APPENDIX B -AGING MANAGEMENT PROGRAMS APPENDIX C -RESPONSE TO BWRVIP LICENSE RENEWAL APPLICATION ACTION ITEMS APPENDIX D -TECHNICAL SPECIFICATION CHANGES (Not Used)APPENDIX E -APPLICANT'S ENVIRONMENTAL REPORT -OPERATING LICENSE RENEWAL STAGE LaSalle County Station, Units 1 and 2 License Renewal Application Page viii Table of Contents List of Tables Table 2.1-1 Table 2.2-1 Table 2.3.1-1 Table 2.3.1-2 Table 2.3.1-3 Table 2.3.2-1 Table 2.3.2-2 Table 2.3.2-3 Table 2.3.2-4 Table 2.3.2-5 Table 2.3.3-1 Table 2.3.3-2 Table 2.3.3-3 Table 2.3.3-4 Table 2.3.3-5 Table 2.3.3-6 Table 2.3.3-7 Table 2.3.3-8 Table 2.3.3-9 Table 2.3.3-10 Table 2.3.3-11 Table 2.3.3-12 Table 2.3.3-13 Table 2.3.3-14 Table 2.3.3-15 0 Passive Structure and Component Intended Function D e fi n itio n s ..........................................................................................
2 .1-3 2 Plant Level Scoping Results ................................................................
2.2-2 Components Subject to Aging Management Review -Reactor Coolant Pressure Boundary System ....................................................
2.3-6 Components Subject to Aging Management Review -Reactor V e s s e l ................................................................................................
2 .3 -1 0 Components Subject to Aging Management Review -Reactor V esse l Internals
.................................................................................
2 .3-15 Components Subject to Aging Management Review -High Pressure Core Spray System ............................................................
2.3-19 Components Subject to Aging Management Review -Low Pressure Core Spray System ............................................................
2.3-24 Components Subject to Aging Management Review -Reactor Core Isolation Cooling System ..........................................................
2.3-28 Components Subject to Aging Management Review -Residual Heat Rem oval System .......................................................................
2.3-33 Components Subject to Aging Management Review -Standby G as Treatm ent System ......................................................................
2.3-36 Components Subject to Aging Management Review -Closed Cycle Cooling W ater System .............................................................
2.3-41 Components Subject to Aging Management Review -Combustible G as C ontrol S ystem ..........................................................................
2.3-45 Components Subject to Aging Management Review -Compressed A ir S yste m ..........................................................................................
2 .3 -4 7 Components Subject to Aging Management Review -Control Rod D rive S yste m ......................................................................................
2 .3-52 Components Subject to Aging Management Review -Control Room Ventilation System ...................................................................
2.3-57 Components Subject to Aging Management Review -Cranes, Hoists and Refueling Equipment System ..........................................
2.3-60 Components Subject to Aging Management Review -Demineralized W ater M akeup System .....................................................................
2.3-63 Components Subject to Aging Management Review -Diesel Generator and Auxiliaries System .....................................................
2.3-69 Components Subject to Aging Management Review -Drywell P neum atic S ystem ...........................................................................
2.3-72 Components Subject to Aging Management Review -Electrical Penetration Pressurization System .................................................
2.3-75 Components Subject to Aging Management Review -Essential C ooling W ater System ......................................................................
2.3-79 Components Subject to Aging Management Review -Fire Protection S y ste m ..............................................................................................
2 .3 -8 5 Components Subject to Aging Management Review -Fuel Pool C ooling and Storage System .............................................................
2.3-89 Components Subject to Aging Management Review -Nonessential C ooling W ater System ......................................................................
2.3-94 Components Subject to Aging Management Review -Nonsafety-Related Ventilation System ..............................................
2.3-97 LaSalle County Station, Units 1 and 2 License Renewal Application Page ix Table of Contents Table 2.3.3-16 Table 2.3.3-17 Table 2.3.3-18 Table 2.3.3-19 Table 2.3.3-20 Table 2.3.3-21 Table 2.3.3-22 Table 2.3.3-23 Table 2.3.3-24 Table 2.3.3-25 Table 2.3.4-1 Table 2.3.4-2 Table 2.3.4-3 Table 2.3.4-4 Table 2.3.4-5 Table 2.4-1 Table 2.4-2 Table 2.4-3 Table 2.4-4 Table 2.4-5 Table 2.4-6 Table 2.4-7 Table 2.4-8 Table 2.4-9 Table 2.4-10 Components Subject to Aging Management Review -Plant D rainage S ystem ............................................................................
2.3-103 Components Subject to Aging Management Review -Primary Containment Ventilation System ....................................................
2.3-107 Components Subject to Aging Management Review -Process Radiation Monitoring System ...........................................................
2.3-113 Components Subject to Aging Management Review -Process Sampling and Post Accident Monitoring System ...........................
2.3-118 Components Subject to Aging Management Review -Radwaste S y ste m ...........................................................................................
2 .3 -12 1 Components Subject to Aging Management Review -Reactor Water Cleanup System ..................................................................
2.3-125 Components Subject to Aging Management Review -Safety-Related Ventilation System .............................................................
2.3-130 Components Subject to Aging Management Review -Standby Liquid Control System ...................................................................
2.3-133 Components Subject to Aging Management Review -Suppression Pool Cleanup System ...............................................
2.3-135 Components Subject to Aging Management Review -Traversing Incore P robe S ystem .....................................................................
2.3-138 Components Subject to Aging Management Review -Condensate System ........................................................................
2.3-143 Components Subject to Aging Management Review -Condenser and Air Removal System .................................................................
2.3-144 Components Subject to Aging Management Review -Feedwater S y ste m .............................................................................................
2 .3 -14 7 Components Subject to Aging Management Review -Main S team S yste m ..................................................................................
2 .3-155 Components Subject to Aging Management Review -Main Turbine and A uxiliaries S ystem .....................................................................
2.3-158 Components Subject to Aging Management Review -Auxiliary B u ild in g ................................................................................................
2 .4 -5 Components Subject to Aging Management Review -Component Supports Commodity Group ................................................................
2.4-9 Components Subject to Aging Management Review -C o o ling La ke ......................................................................................
2 .4 -15 Components Subject to Aging Management Review -Diesel G e nerator B uilding .............................................................................
2 .4-18 Components Subject to Aging Management Review -Lake Screen H o u se .................................................................................................
2 .4 -2 3 Components Subject to Aging Management Review -Offgas B u ild in g ..............................................................................................
2 .4 -2 7 Components Subject to Aging Management Review -Primary C o nta inm e nt ......................................................................................
2 .4 -33 Components Subject to Aging Management Review -Radwaste B u ild in g ..............................................................................................
2 .4 -3 9 Components Subject to Aging Management Review -Reactor B u ild in g ..............................................................................................
2 .4 -4 5 Components Subject to Aging Management Review -Structural C om m odity G roup .............................................................................
2 .4-5 1 LaSalle County Station, Units 1 and 2 License Renewal Application Page x Table of Contents Table 2.4-11 Table 2.4-12 Table 2.4-13 Table 2.4-14 Table 2.5.2-1 Table 3.0-1 Table 3.1.1 Table 3.1.2-1 Table 3.1.2-2 Table 3.1.2-3 Table 3.2.1 Table 3.2.2-1 Table 3.2.2-2 Table 3.2.2-3 Table 3.2.2-4 Table 3.2.2-5 Table 3.3.1 Table 3.3.2-1 Table 3.3.2-2 Table 3.3.2-3 Table 3.3.2-4 Table 3.3.2-5 Table 3.3.2-6 Table 3.3.2-7 Table 3.3.2-8 Table 3.3.2-9 Table 3.3.2-10 Components Subject to Aging Management Review -Switchyard S tru ctu re s ..........................................................................................
2 .4 -5 5 Components Subject to Aging Management Review -Tank Foundation and D ikes ........................................................................
2.4-58 Components Subject to Aging Management Review -Turbine B u ild in g ..............................................................................................
2 .4 -6 1 Components Subject to Aging Management Review -Yard S tru ctu re s ..........................................................................................
2 .4 -6 7 Electrical Commodities Subject to Aging Management Review ...........
2.5-7 LaSalle Service Environm ents .............................................................
3.0-5 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System .................................
3.1-16 Reactor Coolant Pressure Boundary System Summary of Aging M anagem ent Evaluation
..........................................................
3.1-43 Reactor Vessel Summary of Aging Management Evaluation
............
3.1-56 Reactor Vessel Internals Summary of Aging Management E v a lu a tio n ..........................................................................................
3 .1-8 2 Summary of Aging Management Evaluations for the Engineered S afety Features ..................................................................................
3 .2-13 High Pressure Core Spray System Summary of Aging M anagem ent Evaluation
....................................................................
3.2-33 Low Pressure Core Spray System Summary of Aging M anagem ent Evaluation
....................................................................
3.2-39 Reactor Core Isolation Cooling System Summary of Aging M anagem ent Evaluation
....................................................................
3.2-4 5 Residual Heat Removal System Summary of Aging M anagem ent Evaluation
....................................................................
3.2-58 Standby Gas Treatment System Summary of Aging M anagem ent Evaluation
....................................................................
3.2-65 Summary of Aging Management Evaluations for the Auxiliary S y ste m s .............................................................................................
3 .3 -3 6 Closed Cycle Cooling Water System Summary of Aging Management Evaluation
...............................
3.3-92 Combustible Gas Control System Summary of Aging M anagem ent Evaluation
....................................................................
3.3-99 Compressed Air System Summary of Aging Management E va luatio n ........................................................................................
3 .3-10 3 Control Rod Drive System Summary of Aging Management E va lu atio n ........................................................................................
3 .3-10 6 Control Room Ventilation System Summary of Aging M anagem ent Evaluation
..................................................................
3.3-112 Cranes, Hoists and Refueling Equipment System Summary of Aging M anagem ent Evaluation
........................................................
3.3-121 Demineralized Water Makeup System Summary of Aging M anagem ent Evaluation
..................................................................
3.3-124 Diesel Generator and Auxiliaries System Summary of Aging M anagem ent Evaluation
..................................................................
3.3-128 Drywell Pneumatic System Summary of Aging Management E va lu atio n ........................................................................................
3 .3-14 2 Electrical Penetration Pressurization System Summary of Aging Management Evaluation
........................................................
3.3-148 LaSalle County Station, Units 1 and 2 License Renewal Application Page xi Table of Contents Table 3.3.2-11 Table 3.3.2-12 Table 3.3.2-13 Table 3.3.2-14 Table 3.3.2-15 Table 3.3.2-16 Table 3.3.2-17 Table 3.3.2-18 Table 3.3.2-19 Table 3.3.2-20 Table 3.3.2-21 Table 3.3.2-22 Table 3.3.2-23 Table 3.3.2-24 Table 3.3.2-25 Table 3.4.1 Table 3.4.2-1 Table 3.4.2-2 Table 3.4.2-3 Table 3.4.2-4 Table 3.4.2-5 Table 3.5.1 Table 3.5.2-1 Table 3.5.2-2 Table 3.5.2-3 Table 3.5.2-4 Table 3.5.2-5 Table 3.5.2-6 Table 3.5.2-7 Table 3.5.2-8 Table 3.5.2-9 Essential Cooling Water System Summary of Aging M anagem ent Evaluation
..................................................................
3.3-150 Fire Protection System Summary of Aging Management E v a lu a tio n ........................................................................................
3 .3 -16 2 Fuel Pool Cooling and Storage System Summary of Aging M anagem ent Evaluation
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3.3-172 Nonessential Cooling Water System Summary of Aging M anagem ent Evaluation
..................................................................
3.3-178 Nonsafety-Related Ventilation System Summary of Aging M anagem ent Evaluation
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3.3-187 Plant Drainage System Summary of Aging Management E va luatio n ........................................................................................
3 .3-19 2 Primary Containment Ventilation System Summary of Aging M anagem ent Evaluation
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3.3-198 Process Radiation Monitoring System Summary of Aging M anagem ent Evaluation
..................................................................
3.3-204 Process Sampling and Post Accident Monitoring System Summary of Aging Management Evaluation
....................................
3.3-209 Radwaste System Summary of Aging Management Evaluation
...... 3.3-216 Reactor Water Cleanup System Summary of Aging M anagem ent Evaluation
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3.3-219 Safety-Related Ventilation System Summary of Aging M anagem ent Evaluation
..................................................................
3.3-226 Standby Liquid Control System Summary of Aging M anagem ent Evaluation
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3.3-230 Suppression Pool Cleanup System Summary of Aging M anagem ent Evaluation
..................................................................
3.3-236 Traversing Incore Probe System Summary of Aging M anagem ent Evaluation
..................................................................
3.3-239 Summary of Aging Management Evaluations for the Steam and Power Conversion System ..........................................................
3.4.11 Condensate System Summary of Aging Management Evaluation
.... 3.4-30 Condenser and Air Removal System Summary of Aging M anagem ent Evaluation
....................................................................
3.4-35 Feedwater System Summary of Aging Management Evaluation
...... 3.4-38 Main Steam System Summary of Aging Management Evaluation
..... 3.4-42 Main Turbine and Auxiliaries System Summary of Aging Management Evaluation
...............................
3.4-46 Summary of Aging Management Evaluations for the Structures and C om ponent Supports ..................................................................
3.5-32 Auxiliary Building Summary of Aging Management Evaluation
.........
3.5-73 Component Supports Commodity Group Summary of Aging M anagem ent Evaluation
....................................................................
3.5-89 Cooling Lake Summary of Aging Management Evaluation
..............
3.5-103 Diesel Generator Building Summary of Aging Management E v a lu a tio n ........................................................................................
3 .5 -10 9 Lake Screen House Summary of Aging Management Evaluation
... 3.5-121 Offgas Building Summary of Aging Management Evaluation
..........
3.5-137 Primary Containment Summary of Aging Management Evaluation.
3.5-146 Radwaste Building Summary of Aging Management Evaluation
..... 3.5-176 Reactor Building Summary of Aging Management Evaluation
........ 3.5-187 LaSalle County Station, Units 1 and 2 License Renewal Application Page xii Table of Contents Table 3.5.2-10 Table 3.5.2-11 Table 3.5.2-12 Table 3.5.2-13 Table 3.5.2-14 Table 3.6.1 Table 3.6.2-1 Table 4.1-1 Table 4.1-2 Table 4.2.1-1 Table 4.2.1-2 Table 4.2.1-3 Table 4.2.1-4 Table 4.2.1-5 Table 4.2.1-6 Table 4.2.2-1 Table 4.2.2-2 Table 4.2.3-1 Table 4.2.3-2 Table 4.2.3-3 Table 4.2.3-4 Table 4.2.5-1 Table 4.2.5-2 Table 4.2.6-1 Table 4.2.6-2 Structural Commodity Group Summary of Aging Management E va lu atio n ........................................................................................
3 .5 -2 0 5 Switchyard Structures Summary of Aging Management E va lu atio n ........................................................................................
3 .5 -2 17 Tank Foundations and Dikes Summary of Aging Management E va lu atio n ........................................................................................
3 .5 -2 24 Turbine Building Summary of Aging Management Evaluation
.........
3.5-227 Yard Structures Summary of Aging Management Evaluation
..........
3.5-237 Summary of Aging Management Programs for the Electrical C o m po ne nts .......................................................................................
3 .6 -12 Electrical Commodities Summary of Aging Management E v a lu a tio n ..........................................................................................
3 .6 -2 1 Generic TLAA Applicability to LSCS .......................................................
4-5 Summary of Results -LSCS Time-Limited Aging Analysis ....................
4-6 LSCS Unit 1 -Maximum Neutron Fluence (>1.0 MeV) in RPV Beltline Shell Plates at 54 EFPY (n/cm2) ..............................................
4-16 LSCS Unit 1 -Maximum Neutron Fluence (>1.0 MeV) in RPV Beltline W elds at 54 EFPY (n/cm 2) .......................................................
4-17 LSCS Unit 1 -Maximum Neutron Fluence (>1.0 MeV) in RPV Beltline Nozzles at 54 EFPY (n/cm 2) ....................................................
4-18 LSCS Unit 2 -Maximum Neutron Fluence (>1.0 MeV) in RPV Beltline S hell Plates (n/cm 2) .................................................................
4-19 LSCS Unit 2 -Maximum Neutron Fluence (>1.0 MeV) in RPV Beltline W elds at 54 EFPY (n/cm 2) .......................................................
4-20 LSCS Unit 2 -Maximum Neutron Fluence (>1.0 MeV) in RPV Beltline and Welds Nozzles at 54 EFPY(n/cm2)
..................................
4-21 LSCS Unit 1 -54 EFPY (60-Year)
Upper Shelf Energy (USE) .............
4-25 LSCS Unit 2 -54 EFPY (60-Year)
Upper Shelf Energy (USE) .............
4-29 LSCS Unit 1 54 EFPY Adjusted Reference Temperature (ART)Values for Beltline Plates and W elds ....................................................
4-35 LSCS Unit 1 54 EFPY Adjusted Reference Temperature (ART)Values for Beltline Nozzles and Welds and Integrated Surveillance Program W elds .................................................................
4-38 LSCS Unit 2 54 EFPY Adjusted Reference Temperature (ART)Values for Beltline Plates and W elds ....................................................
4-40 LSCS Unit 2 54 EFPY Adjusted Reference Temperature (ART)Values for Beltline Nozzles and Welds and Integrated Surveillance Program W elds .................................................................
4-4 1 Comparison of NRC 64 EFPY Axial Weld Failure Probability Assessment for CE (CEOG) RPV to LSCS Unit 1 54 EFPY Axial Weld Failure Probability Assessment
..........................................
4-45 Comparison of NRC 64 EFPY Axial Weld Failure Probability Assessment for CB&I RPV to LSCS Unit 2 54 EFPY Axial Weld Failure Probability Assessm ent ............................................................
4-46 Comparison of NRC 64 EFPY Circumferential Weld Failure Probability Assessment for CE (CEOG) RPV to LSCS Unit 1 54 EFPY Circumferential Weld Failure Probability Assessment
...........
4-49 Comparison of NRC 64 EFPY Circumferential Weld Failure Probability Assessment for CB&I RPV to LSCS Unit 2 54 EFPY Circumferential Weld Failure Probability Assessment
...........
4-50 LaSalle County Station, Units 1 and 2 License Renewal Application Page xiii Table of Contents Table 4.2.7-1 Table 4.2.7-2 Table 4.3.1-1 Table 4.3.1-2 Table 4.3.1-3 Table 4.3.2-1 Table 4.3.3-1 Table 4.3.3-2 Table 4.3.3-3 Table 4.3.3-4 Table 4.3.4-1 Table 4.7.1-1 List of Figures Figure 2.1-1 Figure 2.1-2 Figure 4.2.1-1 Figure 4.2.1-2 Figure 4.2.2-1 Figure 4.2.2-2 Figure 4.2.7-1 Figure 4.2.7-2 Figure 4.5.1-1 Figure 4.5.1-2 Figure 4.5.1-3 Figure 4.5.1-4 Crack Stability Analysis for Beltline Shells During Main Steam L in e B re a k .......................................................................................
4 -5 3 Crack Stability Analysis for Beltline Shells During Recirculation L ine B re a k ..............................................................................
4 -54 LSCS Unit 1 Year Transient Cycle Projections
..............................
4-63 LSCS Unit 2 Year Transient Cycle Projections
..............................
4-68 RPV Components Exempt Per ASME Section III, N-415.1 ...................
4-73 Stress Range Reduction Factors for ASME Section III, Class 2 and 3 and ANSI B31.1 Piping ...............................................................
4-74 LSCS Unit 1 (CE) Reactor Pressure Vessel (RPV)Environmental Fatigue Analysis Results ...............................................
4-80 LSCS Unit 2 (CB&I) Reactor Pressure Vessel (RPV)Environmental Fatigue Analysis Results ...............................................
4-83 LSCS Unit 1 -Class 1 Piping System Environmental Fatigue A nalysis R esults ......................................................................
4-87 LSCS Unit 2 Class 1 Piping System Environmental Fatigue A nalysis R esults ...................................................................................
4-88 Reactor Vessel Internals Fatigue Analyses ..........................................
4-90 LSCS Unit 1 and LSCS Unit 2 Reactor Building Crane Load Cycles.. 4-110 LaSalle County Station Scoping and Screening Flowchart
..................
2.1-3 LaSalle SBO Recovery Boundary ......................................................
2.1-14 LSCS Unit 1 Combustion Engineering Reactor Vessel B eltline C om ponents ............................................................................
4-14 LSCS Unit 2 Chicago Bridge and Iron Reactor Vessel B e ltline C om ponents .............................................................................
4-15 N12 Water Level Instrumentation Nozzle Extraction Path ....................
4-23 N6 LPCI Nozzle-to-Shell Weld and Nozzle Forging E xtractio n P aths ....................................................................................
4 -2 3 K vs. a/T for Recirculation Line Break at t = 480 Seconds ....................
4-55 K vs. a/T for Recirculation Line Break at t = 1,200 Seconds ................
4-55 LSCS Unit 1 Vertical Containment Tendon Lift-off Forces .............
.4-100 LSCS Unit 2 Vertical Containment Tendon Lift-off Forces .............
.4-101 LSCS Unit 1 Horizontal (Hoop) Tendon Lift-off Forces ......................
4-102 LSCS Unit 2 Horizontal (Hoop) Tendon Lift-off Forces ......................
4-103 LaSalle County Station, Units 1 and 2 License Renewal Application Page xiv This Page Intentionally Left Blank 0 Section 1 -Administrative Information
 
===1.0 ADMINISTRATIVE===
 
INFORMATION
 
===1.1 GENERAL===
INFORMATION
-10 CFR 54.19 1.1.1 NAME OF APPLICANT Exelon Generation Company, LLC (Exelon), hereby applies for renewed operating licenses for LaSalle County Station, Units 1 and 2 (LSCS).1.1.2 ADDRESS OF APPLICANT Exelon Generation Company, LLC 200 Exelon Way Kennett Square, PA 19348 1.
 
==1.3 DESCRIPTION==
S OF BUSINESS OR OCCUPATION OF APPLICANT Exelon Generation Company, LLC is a Delaware limited liability company which is wholly owned by Exelon Ventures Company, a Delaware limited liability company, which in turn is wholly owned by Exelon Corporation, a corporation formed under the laws of the Commonwealth of Pennsylvania.
Exelon Generation Company, LLC is the licensed operator of LaSalle County Station, Units 1 and 2, which is the subject of this application.
The current LaSalle County Station, Units 1 and 2 operating licenses will expire as follows: o At midnight on April 17, 2022 for Unit 1 (Facility Operating License No. NPF-11).o At midnight December 16, 2023 for Unit 2 (Facility Operating License No. NPF-18).Exelon Generation Company, LLC will continue as the licensed operator on the renewed operating licenses.1.
 
==1.4 DESCRIPTION==
S OF ORGANIZATION AND MANAGEMENT OF APPLICANT Exelon Corporation is a corporation organized under the laws of the Commonwealth of Pennsylvania with its headquarters and principal place of business in Chicago, Illinois.
Exelon Corporation is a publicly traded corporation whose shares are widely traded on the New York Stock Exchange.
Exelon Generation Company, LLC, is organized under the laws of the Commonwealth of Pennsylvania.
Exelon Generation Company, LLC does not have a board of Directors.
All of the Principal Officers of Exelon Generation Company, LLC are U.S. citizens.
Exelon Generation Company, LLC is not owned, controlled, or dominated by an alien, a foreign corporation, or a foreign government.
The LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-1 Section 1 -Administrative Information Principal Officers of Exelon Generation Company, LLC, and their addresses, are presented below: Princip al Officers (Exelon Generation Company, LLC)Name Title Address President and CEO Exelon 200 Exelon Way Generation Kennett Square, PA 19348 Senior Vice President Exelon Michael J. Pacilio Generation; President and Chief W infied Road Nuclear Officer, Exelon Nuclear Warrenville, IL 60555 Exelon Nuclear Chief Operating 4300 Winfield Road Officer Warrenville, IL 60555 Senior Vice President Exelon 300 Exelon Way Ronald J. DeGregorio Generation; President, Exelon Kennett Square, PA 19348 Power John F. Barnes Chief Operating Officer, Exelon 300 Exelon Way Power Kennett Square, PA 19348 EVP, Exelon and CEO 111 Market Place, Baltimore, MD Joseph Nigro Constellation 21202 111 Market Place, Baltimore, MD Mark P. Huston President, Retail, 21202 111 Market Place, Baltimore, MD Edward J Quinn President, Wholesale 21202 111 Market Place, Baltimore, MD Bryan P. Wright Chief Financial Officer 1202 21202 Paymon Aliabadi Chief Enterprise Risk Officer 10 S.
 
==Dearborn St,==
Chicago, IL 60603 1.1.5 CLASS OF LICENSE, USE OF THE FACILITY, WHICH THE LICENSE IS SOUGHT AND PERIOD OF TIME FOR Exelon Generation Company, LLC requests renewal of the Class 103 operating licenses for LaSalle County Station, Units 1 and 2, for a period of 20 years beyond the expiration of the current licenses to allow continued use of the facilities for the commercial generation of electricity.
LSCS Unit 1 license (NPF-1 1) expires at midnight on April 17, 2022. LSCS Unit 2 license (NPF 18)expires at midnight on December 16, 2023.In this application, Exelon Generation Company, LLC also requests the renewal of specific licenses under 10 CFR Parts 30, 40, and 70 that are subsumed in or combined with the current operating licenses.1.1.6 EARLIEST AND LATEST DATES FOR ALTERATIONS, IF PROPOSED No physical plant alterations or modifications have been identified as necessary in connection with this application.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-2 Section 1 -Administrative Information
 
====1.1.7 RESTRICTED====
 
DATA With regard to the requirements of 10 CFR 54.17(f), this application does not contain any "Restricted Data," as that term is defined in the Atomic Energy Act of 1954, as amended, or other defense information, and it is not expected that any such information will be part of the licensed activities.
In accordance with the requirements of 10 CFR 54.17(g), the applicant will not permit any individual to have access to, or any facility to possess restricted data or classified national security information until the individual and/or facility has been approved for such access under the provisions of 10 CFR Parts 25 and/or 95.1.1.8 REGULATORY AGENCIES Exelon Generation Company, LLC recovers its share of the costs incurred from operating LaSalle County Station, Units 1 and 2, in its own wholesale rates.The rates charged and services provided by Exelon Generation Company, LLC are subject to regulation by the Federal Energy Regulatory Commission under the Federal Power Act. Exelon Generation Company, LLC is also subject to regulation as a public utility company by the Securities and Exchange Commission under the Public Utility Holding Company Act of 1935, as amended.Securities and Exchange Commission 450 Fifth Street, NW Washington, DC 20549 Federal Energy Regulatory Commission 888 First St. N.E.Washington, DC 20426 1.1.9 LOCAL NEWS PUBLICATIONS News publications in circulation near LaSalle County Station, Units 1 and 2 that are considered appropriate to give reasonable notice of the application are as follows: The Times 110 W. Jefferson St.Ottawa, IL 61350 The News Tribune 426 Second St.LaSalle, IL 61301 The Morris Daily Herald 1804 N. Division St.Morris, IL 60450 LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-3 Section 1 -Administrative Information 1.1.10 CONFORMING CHANGES TO STANDARD INDEMNITY AGREEMENT 10 CFR Part 54.19(b) requires that "each application must include conforming changes to the standard indemnity agreement, 10 CFR 140.92, Appendix B, to account for the expiration term of the proposed renewed license." The current indemnity agreement (No. B-84) for LaSalle County Station, Units 1 and 2, states in Article VII that the agreement "shall terminate at the time of expiration of that license specified in Item 3 of the Attachment to the agreement, which is the last to expire; provided that, except as may otherwise be provided in applicable regulations or orders of the Commission, the term of this agreement shall not terminate until all the radioactive material has been removed from the location and transportation of the radioactive material from the location has ended as defined in subparagraph 5(b), Article f'. Item 3 of the Attachment to the indemnity agreement includes license numbers NPF-1 1 and NPF-1 8.Applicant requests that any necessary conforming changes be made to Article VII and Item 3 of the Attachment, and any other sections of the indemnity agreement as appropriate to ensure that the indemnity agreement continues to apply during both the terms of the current licenses and the terms of the renewed licenses.
Applicant understands that no changes may be necessary for this purpose if the current license numbers are retained.LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-4 Section 1 -Administrative Information
 
===1.2 GENERAL===
LICENSE INFORMATION
 
====1.2.1 APPLICATION====
 
UPDATES, RENEWED LICENSES, AND RENEWAL TERM OPERATION In accordance with 10 CFR 54.21(b), during NRC review of this application, an annual update to the application to reflect any change to the current licensing basis that materially affects the contents of the license renewal application will be provided.In accordance with 10 CFR 54.21(d), Exelon Generation Company, LLC will maintain a summary list in the LSCS Updated Final Safety Analysis Report (UFSAR) of activities that are required to manage the effects of aging for the systems, structures or components in the scope of license renewal during the period of extended operation and summaries of the time-limited aging analyses evaluations.
 
====1.2.2 INCORPORATION====
 
BY REFERENCE There are no documents incorporated by reference as part of the application.
Any document references, either in text or in Section 1.7 are listed for information only.1.2.3 CONTACT INFORMATION Any notices, questions, or correspondence in connection with this filing should be directed to: Michael P. Gallagher Vice President License Renewal Projects Exelon Generation Company, LLC 200 Exelon Way Kennett Square, PA 19348 with copies to: Albert A. Fulvio Manager License Renewal Exelon Nuclear 200 Exelon Way Kennett Square, PA 19348 Shannon Rafferty-Czincila License Renewal Project Technical Lead Exelon Nuclear 200 Exelon Way Kennett Square, PA 19348 LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-5 Section 1 -Administrative Information
 
===1.3 PURPOSE===
This document provides information required by 10 CFR 54 to support the application for renewed licenses for LaSalle County Station Units 1 and 2. The application contains technical information required by 10 CFR 54.21 and environmental information required by 10 CFR 54.23. The information contained herein is intended to provide the NRC with an adequate basis to make the findings required by 10 CFR 54.29.
 
==1.4 DESCRIPTION==
 
OF THE PLANT The LaSalle County Station, Units 1 and 2 is a dual unit facility located in the agricultural area of Brookfield Township, LaSalle County, Illinois.
It is approximately 55 direct-line miles southwest of Chicago. The plant is on flat terrain about 220 feet above the Illinois River channel which traverses north central Illinois some 3.5 miles to the north of the site.The power generation complex includes several contiguous buildings, two Reactor buildings, an Auxiliary building (housing the control room), the Turbine building, Diesel-Generator buildings, the Radwaste building, the Service building, and the Offgas building.
Other buildings such as the gatehouse, warehouses, etc., are also located in the general plant area. A lake screen house on the intake flume is located about 800 feet east of the main building complex. A small river screen house, located on the Illinois River, provides makeup water to the cooling lake for the LaSalle County Station.The nuclear reactor system for each LSCS unit includes a single-cycle, forced circulation, General Electric boiling-water reactor (GE BWR Type 5). Both units were approved for a 5% stretch power uprate on May 9 of 2000 followed by a 1.65% Measurement Uncertainty Recapture (MUR) power uprate on September 16, 2010. Each LSCS unit reactor is currently licensed to a rated core thermal power of 3546 MWt and is housed within GE Mark II (wet) containment.
Normal heat sink cooling for the station is provided from a perched cooling lake of 2058 acres. The ultimate heat sink for emergency core cooling is a submerged pond and intake flume that underlies the cooling lake and the natural grade of the site. The gross electric output of each unit is approximately 1207 MWe and the net output of each unit is approximately 1178 MWe from each General Electric (GE) turbine-generator.
The NSSS supplier was GE (Nuclear Energy Division).
The plant, except for the NSSS, was designed by Sargent & Lundy (S&L)Engineers.
 
===1.5 APPLICATION===
 
STRUCTURE This license renewal application is structured in accordance with Regulatory Guide 1.188, "Standard Format and Content for Applications to Renew Nuclear Plant Operating Licenses," and NEI 95-10, "Industry Guideline for Implementing the Requirements of 10 CFR Part 54 -The License Renewal Rule," Revision 6.In addition, Section 3, Aging Management Review Results and Appendix B, LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-6 Section 1 -Administrative Information Aging Management Programs and activities are structured to address the guidance provided in NUREG-1 800, "Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants", Revision 2.NUREG-1 800 references NUREG-1 801, "Generic Aging Lessons Learned (GALL) Report," Revision 2. NUREG-1801 was used to determine the adequacy of existing programs for purposes of managing aging and which existing programs should be augmented for license renewal. The results of the aging management review, using NUREG-1801, have been documented and are illustrated in table format in Section 3, "Aging Management Review Results" of this application.
The application is divided into the following major sections: Section 1 -Administrative Information This section provides the administrative information required by 10 CFR 54.17 and 10 CFR 54.19. It describes the plant and states the purpose for this application.
Included in this section are the names, addresses, business descriptions, and organization and management descriptions of the applicant, as well as other administrative information.
This section also provides an overview of the structure of the application, general references, and a listing of acronyms used throughout the application.
Section 2 -Structures and Components Subject To Aging Management Review This section describes and justifies the methods used in the integrated plant assessment to identify those structures and components subject to an aging management review in accordance with the requirements of 10 CFR 54.21 (a)(2). These methods consist of: 1) scoping, which identifies the systems, structures, and components that are within the scope of 10 CFR 54.4(a), and 2) screening under 10 CFR 54.21 (a)(1), which identifies those in scope structures and components that perform their intended function without moving parts or a change in configuration or properties, and that are not subject to replacement based on a qualified life or specified time period.Additionally, the results for systems and structures are described in this section.Scoping results are presented in Section 2.2 "Plant Level Scoping Results".Screening results are presented in Sections 2.3, 2.4, and 2.5.The screening results consist of lists of passive long-lived mechanical and structural components that require aging management review. Brief descriptions of mechanical systems and structures within the scope of license renewal are provided as background information.
Mechanical system and structure intended functions are provided for in scope systems and structures.
For each in scope system and structure, components requiring an aging management review are identified, associated component intended functions are identified, and appropriate reference to the Section 3 Table providing the aging management review results is made.Electrical components and selected structural components, such as electrical cables and component supports, respectively, were evaluated as LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-7 Section 1 -Administrative Information commodities.
Under the commodity approach, components were evaluated based upon common environments and materials.
Components requiring an aging management review are presented in Sections 2.4 and 2.5. Component intended functions and reference to the applicable Section 3 Table is provided.Section 3 -Aging Management Review Results 10 CFR 54.21 (a)(3) requires a demonstration that the effects of aging will be adequately managed so that the intended functions will be maintained consistent with the current licensing basis throughout the period of extended operation.
Section 3 presents the results of the aging management reviews.Section 3 is the link between the scoping and screening results provided in Section 2 and the aging management programs provided in Appendix B.Aging management review results are presented in tabular form, in a format in accordance with NUREG-1 800, "Standard Review Plan for Review of License Renewal Applications." For mechanical systems, aging management review results are provided in Sections 3.1 through 3.4 for the Reactor Vessel, Internals, and Reactor Coolant System; Engineered Safety Features, Auxiliary Systems, and Steam and Power Conversion System respectively.
Aging management review results for containments, structures, and component supports are provided in Section 3.5. Aging management review results for electrical and instrumentation and controls are provided in Section 3.6.Tables are provided in each of these sections in accordance with NUREG-1 800, which provide aging management review results for components, materials, environments, and aging effects which are addressed in NUREG-1801, and information regarding the degree to which the proposed aging management programs are consistent with those recommended in NUREG-1 801.Section 4 -Time-Limited Aging Analyses Time-limited aging analyses (TLAAs), as defined by 10 CFR 54.3 are listed in this section. This section includes each of the TLAAs identified in the NRC Standard Review Plan for License Renewal Applications and in LSCS plant-specific analyses.
This section includes a summary of the time-dependent aspects of the analyses.
A demonstration is provided to show that the analyses remain valid for the period of extended operation, the analyses have been projected to the end of the period of extended operation, or the effects of aging on the intended function(s) will be adequately managed for the period of extended operation, consistent with 10 CFR 54.21 (c)(1)(i)-(iii).
Appendix A -Updated Final Safety Analysis Report Supplement As required by 10 CFR 54.21(d), the Updated Final Safety Analysis Report (UFSAR) supplement contains a summary of activities credited for managing the effects of aging for the period of extended operation.
In addition, summary descriptions of time-limited aging analyses evaluations are provided.
Table 3.0-1, "FSAR Supplement for Aging Management of Applicable Systems," from Revision 2 of NUREG-1 800 was used as guidance for the content of the applicable aging management program summaries.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-8 Section 1 -Administrative Information Appendix B -Aging Management Programs Appendix B describes the programs and activities that are credited for managing aging effects for components or structures during the period of extended operation based upon the aging management review results provided in Section 3 and the time-limited aging analyses results provided in Section 4.Sections B.2 and B.3 discuss those programs that are contained in Section XI and Section X, respectively, of NUREG-1801.
A description of the aging management program is provided and a conclusion is drawn based upon the results of an evaluation to each of the ten elements provided in NUREG-1801.
In some cases, exceptions and justifications for managing aging are provided for specific NUREG-1 801 elements.
Additionally, operating experience related to the aging management program is provided.Appendix C -Response to BWRVIP License Renewal Applicant Action Items This Appendix provides the requested responses to applicant action items contained in the NRC safety evaluation reports associated with NRC approved Boiling Water Reactor Vessel and Internals Program reports.Appendix D -Technical Specification Changes This Appendix satisfies the requirement in 10 CFR 54.22 to identify technical specification changes or additions necessary to manage the effects of aging during the period of extended operation.
There were no Technical Specification Changes identified necessary to manage the effects of aging during the period of extended operation.
Appendix E -Environmental Information
-LaSalle County Station Units 1 and 2 This Appendix satisfies the requirements of 10 CFR 54.23 to provide a supplement to the environmental report that complies with the requirements of subpart A of 10 CFR Part 51 for LaSalle County Station Units 1 and 2.LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-9 Section 1 -Administrative Information
 
===1.6 ACRONYMS===
Acronym Meaning AC Alternating Current ACI American Concrete Institute AMP Aging Management Program AMR Aging Management Review ANL Argonne National Laboratory ANSI American National Standards Institute ASCE American Society of Civil Engineers ASME American Society of Mechanical Engineers ASTM American Society for Testing and Materials ATWS Anticipated transients without scram BTP Branch Technical Position BWR Boiling Water Reactor BWRVIP Boiling Water Reactor Vessels and Internals Project C (-C) Degrees Celsius CASS Cast austenitic stainless steel CFR Code of Federal Regulations CLB Current licensing basis CUF Cumulative Usage Fatigue CUFen Environmentally Adjusted Cumulative Usage Factor DBA Design basis accident DBD Design basis document DBE Design basis event DC Direct Current DO Dissolved Oxygen DORL Division of Operating Reactors Licensing DOT Department of Transportation EAF Environmentally-Assisted Fatigue ECCS Emergency Core Cooling System ECT Eddy Current Testing EDG Emergency Diesel Generator EFPY Effective full-power years EPRI Electric Power Research Institute LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-10 Section 1 -Administrative Information Acronym Meaning EPA Environmental Protection Agency EPU Extended Power Uprate EQ Environmental Qualification ESF Engineered Safety Features F (TF) Degrees Fahrenheit FAC Flow-accelerated corrosion Fen Environmentally Assisted Fatigue Correction Factor FHAR Fire Hazards Analysis Report FHS Fuel Handling and Storage System FSAR Final Safety Analysis Report FSSD Fire safe shutdown GALL Generic Aging Lessons Learned Report NUREG 1801 GL Generic Letter GSI GSI Generic Safety Issue HELB High energy line break HEPA High efficiency particulate air HVAC Heating, ventilation, and air conditioning HX Heat exchanger I & C Instrumentation and controls IASCC Irradiation assisted stress corrosion cracking IEEE Institute of Electrical and Electronics Engineers IGA Intergranular Attack IGSCC Intergranular stress corrosion cracking IN Information Notice INPO Institute of Nuclear Power Operations IPA Integrated plant assessment ISI Inservice inspection ISG Interim Staff Guidance IST Inservice testing LBB Leak before break LER Licensee event report LSCS LaSalle County Station, Units 1 and 2 LLRT Local leak rate test LOCA Loss-of-coolant accident LRA License Renewal Application LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-11 Section 1 -Administrative Information Acronym Meaning LTOP Low Temperature Overpressure Protection MCC Motor control center MEAP Material/Environment/Aging affect/Program as summarized on AMR line-items MG Motor generator MIC Microbiologically influenced corrosion MOV Motor-operated valve MSIV Main steam isolation valve MSIP Mechanical Stress Improvement Process MSV Main stop valve MSRV Main Steam Relief Valve MUR Measurement Uncertainty Recapture (power uprate)MWt Megawatts-thermal MWe Megawatts-electric NDE Nondestructive examination NDT Nil Ductility Temperature NEI Nuclear Energy Institute NFPA National Fire Protection Association NPS Nominal Pipe Size NRC Nuclear Regulatory Commission NRR Office of Nuclear Reactor Regulation NSR Nonsafety-Related OE Operating experience P&ID Piping and instrumentation diagram PM Preventive maintenance PTS Pressurized Thermal Shock P-T curves Pressure-temperature limit curves PUA Plant-unique analyses PWR Pressurized Water Reactor RCPB Reactor coolant pressure boundary RCS Reactor Coolant System RG Regulatory guide RPS Reactor protection system RTNDT nil-ductility transition reference temperature RPV Reactor Pressure Vessel RW Radwaste Systems LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-12 Section 1 -Administrative Information Acronym SBO SCC SSC SR SRV SSCs SSE TLAAs UFSAR UHS USE Meaning Station Blackout Stress corrosion cracking Systems Structures and Components Safety-Related Safety Related Ventilation System Systems, structures, and components Safe shutdown earthquake Time-limited aging analyses Updated Final Safety Analysis Report Ultimate heat sink Upper-shelf energy LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-13 Section 1 -Administrative Information
 
===1.7 GENERAL===
REFERENCES 1.7.1 10 CFR 54, "Requirements for Renewal of Operating Licenses for Nuclear Power Plants." 1.7.2 NEI 95-10, "Industry Guidelines for Implementing the Requirements of 10 CFR Part 54 -The License Renewal Rule," Revision 6, June 2005.1.7.3 Regulatory Guide 1.188, "Standard Format and Content for Applications to Renew Nuclear Power Plant Operating Licenses," Revision 1.1.7.4 NUREG-1 800, "Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants" United States Nuclear Regulatory Commission, Revision 2.1.7.5 NUREG-1 801, "Generic Aging Lessons Learned (GALL) Report," United States Nuclear Regulatory Commission, Revision 2.1.7.6 10 CFR 50.48, "Fire Protection." 1.7.7 10 CFR 50.49, "Environmental Qualification of Electric Equipment Important to Safety for Nuclear Power Plants." 1.7.8 10 CFR 50.62, "Requirements for Reduction of Risk from Anticipated Transients Without Scram (ATWS) Events for Light-Water-Cooled Nuclear Power Plants." 1.7.9 10 CFR 50.63, "Loss of All Alternating Current Power." 1.7.10 10 CFR 50.65, "Requirements for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants." 1.7.11 10 CFR 50, Appendix B, "Quality Assurance Criteria for Nuclear Power Plants and Fuel Reprocessing Plants." 1.7.12 10 CFR 51, "Environmental Protection Regulations for Domestic Licensing and Related Regulatory Functions." 1.7.13 NUREG-0800, Section 9.5.1.1, Appendix B, "Supplemental Fire Protection Review Criteria for License Renewal," Revision 5, March 2007.1.7.14 NUREG-0933, "Resolution of Generic Safety Issues," U.S. Nuclear Regulatory Commission, Supplement 34, December 2011.1.7.15 EPRI Technical Report 1010639, Non-Class 1 Mechanical Implementation Guideline and Mechanical Tools, Revision 4.1.7.16 Plant Support Engineering:
License Renewal Electrical Handbook, Revision 1 to EPRI Report 1003057 (1013475), Final Report, February 2007.1.7.17 "Plant Support Engineering:
Aging Effects for Structures and Structural Components (Structural Tools)," EPRI, Final Report, December 2007, 1015078.LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-14 Section 1 -Administrative Information 1.7.18 NEI 05-01, "Severe Accident Mitigation Alternatives (SAMA) Analysis Guidance Document, Revision A, November 2005.LaSalle County Station, Units 1 and 2 License Renewal Application Page 1-15 This Page Intentionally Left Blank Section 2 -Scoping and Screening Methodology and Results 2.0 SCOPING AND SCREENING METHODOLOGY FOR IDENTIFYING STRUCTURES AND COMPONENTS SUBJECT TO AGING MANAGEMENT REVIEW, AND IMPLEMENTATION RESULTS This section describes the process for identifying structures and components subject to aging management review in the LaSalle County Station (LSCS)license renewal integrated plant assessment.
For the systems, structures, and components (SSCs) within the scope of license renewal, 10 CFR 54.21 (a)(1)requires the license renewal applicant to identify and list those structures and components subject to Aging Management Review (AMR). 10 CFR 54.21(a)(2) further requires that the methods used to implement the requirements of 10 CFR 54.21 (a)(1) be described and justified.
Section 2 of this application satisfies these requirements.
The process is performed in two steps. Scoping refers to the process of identifying the plant systems and structures that are to be included within the scope of license renewal in accordance with 10 CFR 54.4. The intended functions that are the bases for including the systems and structures within the scope of license renewal are also identified during the scoping process.Screening is the process of determining which components associated with the in scope systems and structures are subject to an aging management review in accordance with 10 CFR 54.21 (a)(1) requirements.
A detailed description of the LSCS scoping and screening process is provided in Section 2.1.The scoping and screening methodology is consistent with the guidelines presented in NEI-95-10, Industry Guidelines for Implementing the Requirements of 10 CFR Part 54 -The License Renewal Rule, Revision 6 (reference 1.7.2).The plant level scoping results identify the systems and structures within the scope of license renewal in Section 2.2. The screening results identify components subject to aging management review in the following LRA sections:* Section 2.3 for mechanical systems* Section 2.4 for structures and component supports* Section 2.5 for electrical LaSalle County Station, Units 1 and 2 Page 2.0-1 License Renewal Application This Page Intentionally Left Blank Section 2 -Scoping and Screening Methodology and Results 2.1 SCOPING AND SCREENING METHODOLOGY 2.
 
==1.1 INTRODUCTION==
 
This introduction provides an overview of the scoping and screening process used at LSCS. Subsequent sections provide details of how the process was implemented.
The initial step in the scoping process was to define the entire plant in terms of systems and structures.
Each of these systems and structures were evaluated against the scoping criteria in 10 CFR 54.4(a)(1), (a)(2), and (a)(3), to determine if the system or structure performs or supports a safety-related intended function, if system or structure failure could prevent the satisfactory accomplishment of a safety-related function, or if the system or structure performs functions that demonstrate compliance with the requirement of one of the five license renewal regulated events. The intended function(s) that are the bases for including systems and structures within the scope of license renewal were also identified.
A mechanical system was included within the scope of license renewal if any portion of the system met the scoping criteria of 10 CFR 54.4. Mechanical systems determined to be within the scope of license renewal were then further evaluated to determine those system components that are required to perform or support the identified system intended function(s).
The in scope boundaries of mechanical systems were identified and are described in Section 2.3. These boundaries are also depicted on the license renewal boundary drawings (LRBD)by the use of boundary flags which identify license renewal system interfaces.
The in scope boundaries of the mechanical systems are highlighted in color. In scope mechanical components are shown highlighted in green or red.Mechanical components that are required to perform or support safety-related functions or are required to demonstrate compliance with one of the five license renewal regulated events are shown highlighted in green. Nonsafety-related mechanical components that are included within the scope of license renewal because they provide structural support to safety-related SSCs are shown highlighted in red. Nonsafety-related mechanical components that are included within the scope of license renewal because component failure could prevent the accomplishment of a safety-related function due to potential spatial interaction with safety-related SSCs are shown highlighted in red. Additional details on scoping evaluations and boundary drawing development are provided in Section 2.1.5.A structure was included within the scope of license renewal if any portion of the structure met the scoping criteria of 10 CFR 54.4. Structures were then further evaluated to determine those structural components that are required to perform or support the identified structure intended function(s).
The portions of each structure within the scope of license renewal that are required to perform or support the identified structure intended function(s) were identified and are described in Section 2.4. The structures that are within the scope of license LaSalle County Station, Units 1 and 2 Page 2.1-1 License Renewal Application Section 2 -Scoping and Screening Methodology and Results renewal are highlighted in green on the site plan. Additional details on scoping evaluations and boundary drawing development are provided in Section 2.1.5.Electrical and Instrumentation and Control (I&C) systems were scoped like mechanical systems and structures per the scoping criteria in 10 CFR 54.4(a)(1), (a)(2), and (a)(3). Electrical and I&C components within the in scope electrical and I&C systems were included within the scope of license renewal. Likewise, electrical and I&C components within in scope mechanical systems were included within the scope of license renewal. Consequently, further system evaluations to determine which electrical components were required to perform or support the system intended functions were not performed during the scoping process. Additional details on electrical and I&C system scoping are provided in Section 2.1.5.After completion of the scoping and boundary evaluations, the screening process was performed to evaluate the structures and components within the scope of license renewal to identify the long-lived and passive structures and components subject to an Aging Management Review (AMR). In addition, the passive intended functions of structures and components subject to AMR were identified.
Additional details on the screening process are provided in Section 2.1.6.Selected components, such as equipment supports, structural items (e.g., penetration seals, structural bolting, insulation), and passive electrical components, were scoped and screened as commodities.
As such, they were not evaluated with the individual system or structure, but were evaluated collectively as a commodity group. Commodity groups are identified in Table 2.2-1. Passive structural commodities are identified in Section 2.4, and passive electrical commodities are identified in Section 2.5. Commodity groups utilized are consistent with NUREG-1 800, Table 2.1-5, and previous license renewal applications accepted by the NRC.Figure 2.1-1 provides a flowchart of the general scoping and screening process for mechanical systems, structures, and electrical systems.0 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-2 Section 2 -Scoping and Screening Methodology and Results Figure 2.1-1 LaSalle County Station Scoping and Screening Flowchart SCOPING: Each system and structure is processed through both paths.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-3 Section 2 -Scoping and Screening Methodology and Results 2.1.2 INFORMATION SOURCES USED FOR SCOPING AND SCREENING A number of different current licensing basis (CLB) and design basis information sources were utilized in the scoping and screening process. The CLB for LSCS is consistent with the definition provided in 10 CFR 54.4. The significant source documentation is discussed below.These source documents are available in hard copy or electronic format.Document records such as licensing correspondence and NRC Safety Evaluation Reports are available in a searchable database, such that applicable documents can be identified and located by searching the appropriate topic.2.1.2.1 Updated Final Safety Analysis Report The LSCS UFSAR follows the established guidelines published in NUREG-0800, "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants," dated July 1981. The LSCS UFSAR has since been updated regularly in accordance with the requirements of 10 CFR 50.71(e).The UFSAR provided significant input for system and structure descriptions and functions.
2.1.2.2 Fire Protection Report The Fire Protection Report (FPR) describes the fire protection configuration for the confinement, detection, and suppression of fires, and demonstrates the capability to achieve and maintain safe shutdown conditions in the event of a fire, in support of the Fire Protection Program functions.
2.1.2.3 Environmental Qualification Master List The scope of the electrical equipment and components that must be environmentally qualified for use in a harsh environment at LSCS is identified in the Passport equipment database.
The Passport equipment database is discussed in Section 2.1.2.6. The database includes a listing of equipment and components, and includes fields that identify specific equipment information such as manufacturer, plant location, and qualification level. The Passport equipment database Environmental Qualification (EQ) data field is a mandatory and design basis field, which means that the field must be populated and that the data is controlled and has been verified accurate.2.1.2.4 Maintenance Rule Database The Maintenance Rule Database documents the results of Maintenance Rule scoping for LSCS systems and structures.
The Maintenance Rule Database provided an additional source of information to identify system and structure functions.
LaSalle County Station, Units 1 and 2 Page 2.1-4 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 2.1.2.5 Engineerina Drawings Engineering drawings at LSCS provide system, structure, and component configuration details and safety classification information.
These drawings were utilized to determine SSC functional requirements and materials of construction in support of scoping and screening evaluations.
2.1.2.6 Controlled Plant Component Database LSCS maintains a controlled plant component database that contains component level design and maintenance information.
The plant component database is called the Passport equipment database.
The Passport equipment database lists plant components at the level of detail for which discrete maintenance or modification activities typically are performed.
The Passport equipment database provides a comprehensive listing of plant components and their quality classifications.
Unique equipment component tag numbers identify each component in the database.2.1.2.7 Other CLB References NRC Safety Evaluation Reports include NRC staff review of LSCS licensing submittals.
Some of these documents may contain licensee commitments.
Licensing correspondence includes relief requests, Licensee Event Reports, and responses to NRC communications such as NRC bulletins, generic letters, or enforcement actions. Some of these documents may contain licensee commitments.
Engineering evaluations and calculations can provide additional information about the requirements or characteristics associated with the evaluated systems, structures, or components.
 
====2.1.3 TECHNICAL====
 
BASIS DOCUMENTS Technical basis documents were prepared in support of the license renewal project. Engineers experienced in nuclear plant systems, programs, and operations prepared the basis documents.
Basis documents contain technical evaluations and bases for decisions or positions associated with license renewal requirements as described below. Basis documents are prepared, reviewed, and approved in accordance with controlled project procedures, and are based on the CLB source documents described in Section 2.1.2.The following sections describe the technical basis documents associated with the LSCS scoping and screening methodology.
2.1.3.1 License Renewal Systems and Structures List One of the first steps necessary to begin the license renewal scoping process was to identify a comprehensive list of systems and structures to be evaluated for license renewal scoping. While there exists a variety of document sources LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-5 Section 2 -Scoping and Screening Methodology and Results that identify and list systems and structures at LSCS, no single source provided the comprehensive list in a format appropriate for 10 CFR 54.4 license renewal system and structure scoping. Therefore, a basis document was prepared to establish a comprehensive list of license renewal systems and structures, and to document the basis for the list. Starting with the systems and structures list contained in the Passport equipment database, the list was evaluated against the LSCS UFSAR, plant design drawings, the maintenance rule database, and other plant CLB documents.
Plant systems and structures were arranged into logical groupings for scoping reviews, and the groupings were defined as license renewal systems and structures.
Components evaluated as commodity groups were also identified.
The basis document assures all plant structures and components included in the scoping review are associated with a system, structure, or commodity group.The basis document grouped license renewal systems and structures into the following categories:
* Reactor Vessel, Internals, and Reactor Coolant System* Engineered Safety Features* Auxiliary Systems* Steam and Power Conversion System* Electrical Components
* Structures and Component Supports This grouping of the LSCS license renewal systems and structures is based on the LSCS UFSAR and the guidance of NUREG-1 801 "Generic Aging Lessons Learned (GALL) Report," Revision 2 (reference 1.7.5). The complete list of systems, structures, and commodity groups evaluated for license renewal is provided in Section 2.2 of this application.
Certain structures and equipment were excluded at the outset because they are not considered to be systems, structures, or components that are part of the CLB and do not have design or functional requirements related to the 10 CFR 54.4(a)(1), (a)(2), or (a)(3) scoping criteria.
These include: driveways and parking lots, temporary equipment, health physics equipment, portable measuring and testing equipment, tools, and motor vehicles.2.1.3.2 Identification of Safety-Related Systems and Structures Safety-related systems and structures are included within the scope of license renewal in accordance with 10 CFR 54.4(a)(1) scoping criterion.
LSCS plant systems and structures that have been designed to safety-related standards are identified in the UFSAR. LSCS plant components that have been classified as safety-related are identified as "SR" in the controlled safety classification data field in the Passport equipment database.
LSCS safety classification procedures were reviewed against the license renewal "Safety-related" scoping criterion in 10 CFR 54.4(a)(1), to confirm that LSCS safety-related classifications are consistent with license renewal requirements.
This review is included in a technical basis document.
The basis document also provides a summary list of the systems and structures that are safety-related at LSCS.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-6 Section 2 -Scoping and Screening Methodology and Results These systems and structures are included within the scope of license renewal in accordance with the 10 CFR 54.4(a)(1) scoping criterion.
The LSCS UFSAR definition of safety-related is as follows: Safety-related structures, systems, and components are those required to assure:* The integrity of the reactor coolant pressure boundary,* The capability to shut down the reactor and maintain it in a safe shutdown condition, or" The capability to prevent or mitigate the consequences of accidents which could result in potential offsite exposures in excess of the guideline exposures of 10 CFR 100 or 10 CFR 50.67 as applicable.
This definition is consistent with 10 CFR 54.4(a)(1) for the purposes of license renewal scoping. The wording differences are addressed as follows: Design Basis Events The LSCS UFSAR definition of safety-related does not specifically refer to design basis events, while 10 CFR 54.4(a)(1) refers to design basis events as defined in 10 CFR 50.49(b)(1).
For LSCS license renewal, an additional technical basis document was prepared to confirm that all applicable design basis events were considered.
The basis document includes a review of all systems or structures that are relied upon to remain functional during and following design-basis events as defined in 10 CFR 50.49 (b)(1). This includes confirming that design basis internal and external events including Design Basis Accidents (DBAs), Anticipated Operational Transients, Abnormal Operational Transients, and natural phenomena as described in the current licensing basis (CLB) are considered when scoping for license renewal.Safety-related systems and structures required to support 10 CFR 54.4(a)(1) functions are included within the scope of license renewal in accordance with 10 CFR 54.4(a)(1).
Nonsafety-related systems and structures required to support 10 CFR 54.4(a)(1) functions are included within the scope of license renewal in accordance with 10 CFR 54.4(a)(2).
Exposure Limits The license renewal rule refers to exposure limits as defined in 10 CFR 50.34(a)(1), 10 CFR 50.67(b)(2), or 10 CFR 100.11, as applicable.
These different exposure limit requirements appear in three different Code sections to address similar accident analyses performed by licensees for different reasons. The exposure limit requirements in 10 CFR 50.34(a)(1) are applicable to facilities seeking a construction permit, and are, therefore, not applicable to LSCS license renewal. The exposure limit requirements in 10 CFR 50.67(b)(2) are applicable to facilities seeking to revise the current accident source term used in their design basis radiological analyses.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-7 Section 2 -Scoping and Screening Methodology and Results The original UFSAR Chapter 15 Accident Analyses were performed to address 10 CFR 100 guidelines.
In support of a full scope implementation of Alternative Source Term (AST) methodology in accordance with Regulatory Guide 1.183, AST radiological consequence analyses were performed for the design basis accidents that result in offsite exposures.
The Loss-of-Coolant Accident and the Fuel Handling Accident were analyzed.
The dose consequences for these limiting design basis accidents result in doses that are within the guidelines of 10 CFR 50.67. The AST analytical methods described in Regulatory Guide 1.183 and dose limits defined in 10 CFR 50.67 comprise the design basis for the LaSalle design basis accidents.
When supplemented with the broad review of CLB design basis events, the LSCS UFSAR definition of "safety-related" is consistent with 10 CFR 54.4(a)(1), and results in a comprehensive list of safety-related systems and structures that were included within the scope of license renewal.This is consistent with NUREG-1800 Section 2.1.3.1.1.
Additional detail on the application of the 10 CFR 54.4(a)(1) scoping criterion is provided in Section 2.1.5.1.2.1.3.3 10 CFR 54.4(a)(2)
Scoping Criteria All nonsafety-related systems, structures, and components whose failure could prevent satisfactory accomplishment of any of the functions identified in 10 CFR 54.4(a)(1), were included within the scope of license renewal in accordance with 10 CFR 54.4(a)(2) requirements.
To assure complete and consistent application of this scoping criterion, a technical basis document was prepared.This license renewal scoping criteria requires consideration of the following:
: 1. Nonsafety-related SSCs required to provide functional support for a safety-related 10 CFR 54.4(a)(1) function.2. Nonsafety-related systems connected to and providing structural support for a safety-related SSC.3. Nonsafety-related systems with a potential for spatial interaction with safety-related SSCs.The first item is addressed during the scoping process, by identifying the nonsafety-related systems and structures required to functionally support the accomplishment of a safety-related intended function under 10 CFR 54.4(a)(1), and then including these supporting systems and structures in scope of license renewal under 10 CFR 54.4(a)(2).
The remaining two items concern nonsafety-related systems with potential physical or spatial interaction with safety-related systems, structures, and components.
Scoping of these systems is the subject of NEI 95-10, Appendix F. To assure complete and consistent application of 10 CFR 54.4(a)(2) requirements and NEI 95-10, a technical basis document LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-8 Section 2 -Scoping and Screening Methodology and Results was prepared.
The basis document includes a review of the CLB references relevant to physical or spatial interactions.
The basis document describes the LSCS approach to scoping of nonsafe ty-related systems with a potential for physical or spatial interaction with safety-related SSCs. The basis document provides appropriate guidance to assure that license renewal scoping for 10 CFR 54.4(a)(2) met the requirements of the license renewal rule and NEI 95-10. Additional detail on the application of the 10 CFR 54.4(a)(2) scoping criterion is provided in Section 2.1.5.2.2.1.3.4 Scoping for Regulated Events Technical basis documents were prepared to address license renewal scoping of SSCs relied on in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection, Environmental Qualification, Anticipated Transients Without Scram, and Station Blackout.
The Commission's regulations for pressurized thermal shock are not applicable to the LSCS boiling water reactor design. These basis documents are summarized below: Fire Protection Systems, structures, and components relied on in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for fire protection (10 CFR 50.48) are included within the scope of license renewal in accordance with 10 CFR 54.4(a)(3) requirements.
The scope of systems and structures required for the fire protection program to comply with the requirements of 10 CFR 50.48 includes: " Systems and structures required to demonstrate post-fire safe shutdown capabilities" Systems and structures required for fire protection (detection, suppression, and barriers)NRC guidance, including NUREG-0800 Section 9.5.1, Appendix B (reference 1.7.13) states that the scope of 10 CFR 50.48 goes beyond the protection of safety-related equipment, and also includes fire protection systems, structures, and components needed to minimize the effects of a fire and to prevent the release of radioactive material to the environment.
Fire protection system and structure scoping for LSCS is performed consistent with this guidance, and is documented in the technical basis document.The fire protection technical basis document summarizes results of a detailed review of the plant's fire protection program documents that demonstrate compliance with the requirements of 10 CFR 50.48. The basis document provides a list of systems and structures credited in the plant's fire protection program documents.
For the listed systems and structures, the basis document also identifies appropriate CLB references.
The identified systems LaSalle County Station, Units 1 and 2 Page 2.1-9 License Renewal Application Section 2 -Scoping and Screening Methodology and Results and structures are included within the scope of license renewal in accordance with 10 CFR 54.4(a)(3) scoping criteria.The fire detection and suppression systems at LSCS are plant-wide systems that protect a wide variety of plant equipment.
Not all portions of these systems are required to demonstrate compliance with 10 CFR 50.48. Some portions of the fire detection and suppression systems protect plant areas in which a fire would not impact any equipment important to safety or significantly increase the risk of radioactive releases to the environment.
Portions of the fire suppression and detection systems are not included within the scope of license renewal if (1) those portions of the system are provided to protect areas that do not contain any SSCs within the scope of license renewal and (2) those portions of the system can be isolated from the in scope portions of the system. The portions of the fire suppression and detection systems that are not included within the scope of license renewal are identified in the system scoping document.
Those portions of fire detection and suppression systems that are not included in scope can be isolated from the remaining in scope system by closing the associated isolation valve. The isolation valve is included within the scope of license renewal.Environmental Qualification Criterion 10 CFR 54.4(a)(3) requires that all systems, structures, and components relied on in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for environmental qualification (10 CFR 50.49) be included within the scope of license renewal.The LSCS Environmental Qualification (EQ) program includes 1) safety-related electrical equipment, 2) nonsafety-related electrical equipment whose failure under postulated environmental conditions could prevent the accomplishment of safety functions, and 3) certain post-accident monitoring equipment, as defined in 10 CFR 50.49(b)(1), 10 CFR 50.49(b)(2), and 10 CFR 50.49(b)(3) respectively.
This equipment is included within the scope of license renewal.The environmental qualification basis document summarizes the results of a review of LSCS EQ program documents.
The EQ basis document provides a list of systems that include EQ components.
The EQ basis document also provides a list of structures that provide the physical boundaries for the postulated harsh environments, and contain environmentally qualified electrical equipment.
These systems and structures are included within the scope of license renewal in accordance with 10 CFR 54.4(a)(3) scoping criteria.Anticipated Transients Without Scram Criterion 10 CFR 54.4(a)(3) requires that all systems, structures, and components relied on in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for anticipated transients without scram (10 CFR 50.62) be included within the scope of license renewal.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-10 Section 2 -Scoping and Screening Methodology and Results An Anticipated Transient Without Scram (ATWS) is an anticipated operational occurrence that generates an automatic scram signal, accompanied by a failure of the reactor protection system to automatically shutdown the reactor.The ATWS rule (10 CFR 50.62) requires improvements in the design and operation of light-water cooled water reactors to reduce the likelihood of failure to automatically shutdown the reactor, and to mitigate the consequences of an ATWS event. LSCS Unit 1 and Unit 2 are boiling water reactors.
For boiling water reactors (BWR), the following requirements apply: 1. Each BWR must have an alternate rod injection (ARI) system with redundant scram air header exhaust valves. The ARI system must be independent of the existing reactor trip system.2. Each BWR must have a standby liquid control system with defined boron injection capabilities.
Standby liquid control system automatic initiation is not required for plants issued a construction permit before July 26, 1984, unless already installed.
: 3. Each BWR must have equipment to trip the recirculation pumps automatically under conditions indicative of an ATWS.The ATWS basis document summarizes the results of a review of the LSCS current licensing basis with respect to ATWS. The LSCS design features to meet the requirements of 10 CFR 50.62 for ATWS mitigation include:* Alternate Rod Insertion (ARI) system features to satisfy the requirements of 10 CFR 50.62 (c)(3). The ARI plant system is included in the License Renewal Reactivity Control system." Standby Liquid Control (SLC) system to meet the requirements of 10 CFR 50.62 (c)(4)." ATWS Recirculation Pump Trip (RPT) system to satisfy the requirements of 10 CFR 50.62 (c)(5).The ATWS basis document provides a list of the systems required by 10 CFR 50.62 to reduce the risk from ATWS events. The basis document also provides a list of structures that provide physical support and protection for the ATWS systems. These systems and structures are included within the scope of license renewal in accordance with 10 CFR 54.4(a)(3) scoping criteria.Station Blackout Criterion 10 CFR 54.4(a)(3) requires that all systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for station blackout (10 CFR 50.63) be included within the scope of license renewal.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-11 Section 2 -Scoping and Screening Methodology and Results A station blackout (SBO) event is a complete loss of alternating current (AC)electric power to the essential and nonessential switchgear buses in a nuclear power plant (i.e., loss of the offsite electric power system concurrent with generator trip and unavailability of the onsite emergency AC power sources).SBO does not include the loss of available AC power to buses fed by station batteries through inverters or by alternate AC sources, nor does it assume a concurrent single failure or design basis accident.LSCS satisfies the requirement of 10 CFR 50.63 as an AC-independent, 4-hour coping plant. LSCS capabilities, commitments and analyses that demonstrate compliance with 10 CFR 50.63 are documented in the UFSAR Section 15.9 and in NRC safety evaluation reports and correspondence related to the SBO rule.The NUREG-1 800 guidance on scoping of equipment relied on to meet the requirements of the SBO rule (10 CFR 50.63) for license renewal has been incorporated into the LSCS scoping methodology.
In accordance with the NUREG-1 800 requirements, the SSCs required to recover from the SBO event are included within the scope of license renewal. Recovery is defined as the repowering of the plant AC distribution system from offsite sources or onsite emergency AC sources.For LSCS, the boundary between the offsite transmission system and the plant electrical distribution system has been defined at four 345 kV switchyard circuit breakers:
breakers 1-13 and 11-13 for the input to system auxiliary transformer 142 and breakers 1-6 and 4-6 for the input to system auxiliary transformer 242.This boundary is consistent with the NRC standard review plan for license renewal, NUREG-1800, section 2.5.2.1.1 for the boundary for the Station Blackout recovery path. The NUREG states that the in scope plant system portion of the offsite power system that is used to connect to the offsite power source is the equipment out to the first circuit breaker with the offsite distribution system. This typically includes equipment in the switchyard.
The breaker control circuits and the structures associated with these breakers and the switchyard relay house are also in scope for license renewal. See Figure 2.1-2 for the LSCS SBO recovery path boundary.Figure 2.1-2 also shows LSCS connections to the 345 kV transmission system.The 345 kV transmission system via the LSCS 345 kV switchyard is the preferred (and alternate for Division 1 and Division 2) power sources for LSCS safety-related loads. Two physically independent circuits are provided for each unit, one via the unit's assigned system auxiliary transformer, and the other from the system auxiliary transformer of the other unit. The system auxiliary transformers step the 345 kV voltage down to 4160 V for the safety-related 4160 V switchgear and associated downstream safety-related loads. As an example, the 4160 V safety-related switchgear source power paths from the normal offsite source from the 345 kV transmission system, and, from the alternate offsite source from the 345 kV transmission system are described below using the safety-related 4160 V 142Y (1A) switchgear as an example.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-12 Section 2 -Scoping and Screening Methodology and Results-The normal offsite source from the 345 kV system is through the Unit 1 System Auxiliary Transformer 142 and then through breaker 1422 to energize the safety-related 4160 V 142Y (1A) switchgear.
-The alternate offsite source from the 345 kV system is through the Unit 2 System Auxiliary Transformer 242 and then through breakers 2422, 2424 and 1424 to energize the 4160 V safety-related 142Y (1A) switchgear.
The power paths for the remaining Division 1 and Division 2 LSCS safety-related 4160 V switchgear are similar.The SBO basis document summarizes the results of a review of the LSCS current licensing basis with respect to station blackout.
The basis document provides lists of systems and structures credited in LSCS SBO evaluations.
For the listed systems and structures, the basis document also identifies appropriate CLB references.
These systems and structures are included within the scope of license renewal in accordance with 10 CFR 54.4(a)(3) scoping criteria.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-13 Section 2 -Scoping and Screening Methodology and Results Figure 2.1-2 LASALLE SBO RECOVERY BOUNDARY UNS 01 E LINE 0X 0101 10-11 9-10 1-9(LINE LI 0102 01 2-3 3-4)1-2 NE 03 NOT IN SCOPE It q. -, 11-13 I 1-13()1-6 I 4-IN SCOPE SA~T142 11413 2413 141Y ) ) 241Y 1412 ) ) )2412 1414 Lj2414 1422 142Y 242Y 422 1423 ) 1424 2424 2423 IJ'DG 1A DG2A 14321)4 143 D1B DG1 B SAT 242)2432 24.33)DG2B3 LEGEND JA11 DIESEL CIRCUIT BREAKER TRANSFORMER GENERATOR LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-14 Section 2 -Scoping and Screening Methodology and Results 2.1.4 INTERIM STAFF GUIDANCE DISCUSSION The NRC has encouraged applicants for license renewal to address Interim Staff Guidance (ISG) issues in license renewal applications.
The following is a listing of ISGs reviewed that have not been incorporated in NUREG-1 800 or NUREG-1801 as of October 2014.LR-ISG-2006-03 LR-ISG-201 1-01 LR-ISG-2011-02 LR-ISG-2011-03 LR-ISG-2011-04 LR-ISG-2011-05 LR-ISG-2012-01 LR-ISG-2012-02 Staff Guidance for Preparing Severe Accident Mitigation Alternatives Analyses Aging Management of Stainless Steel Structures and Components in Treated Borated Water, Revision 1 Aging Management Program for Steam Generators Generic Aging Lessons Learned (GALL) Report Revision 2 AMP XI.M41, "Buried and Underground Piping and Tanks" Updated Aging Management Criteria for Reactor Vessel Internal Components of Pressurized Water Reactors Ongoing Review of Operating Experience Wall Thinning Due to Erosion Mechanisms Aging Management of Internal Surfaces, Fire Water Systems, Atmospheric Storage Tanks, and Corrosion Under Insulation Draft LR-ISG-2013-01 Aging Management of Loss of Coating Integrity for Internal Service Level III (Augmented)
Coatings The following sections provide summaries of how each of the ISG issues is addressed in the LSCS LRA: 2.1.4.1 Staff Guidance for Preparing Severe Accident Mitigation Alternatives Analyses (LR-ISG-2006-03)
This LR-ISG provides interim guidance to applicants for license renewal in which the NRC endorses the guidance of NEI 05-01, "Severe Accident Mitigation Alternatives (SAMA) Analysis Guidance Document" (reference 1.7.18). The LSCS severe accident mitigation alternatives analysis provided as a part of Appendix E to this application is consistent with the guidance of NEI 05-01, as discussed in this LR-ISG.2.1.4.2 Aging Management of Stainless Steel Structures and Components in Treated Borated Water, Revision 1 (LR-ISG-201 1-01)This LR-ISG provides interim guidance to applicants for license renewal as to one acceptable approach to managing the aging effects of stainless steel structures and components exposed to treated borated water. New guidance has also been provided for BWR spent fuel storage racks for which there is currently no specific guidance in the GALL Report for the loss of material aging LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-15 Section 2 -Scoping and Screening Methodology and Results effect. LSCS incorporates the guidance presented in this LR-ISG for BWRs and utilizes the One-Time Inspection (B.2.1.21) program and Water Chemistry (B.2.1.2) program to manage loss of material of stainless steel control rod blades, defective fuel, and spent fuel storage racks exposed to treated water in the Fuel Pool Cooling and Storage System. Results are provided in Section 3, Aging Management Review Results.2.1.4.3 Aging Management Program for Steam Generators (LR-ISG-2011-02)
This guidance does not apply to LSCS which is a boiling water reactor.2.1.4.4 Changes to the Generic Aging Lessons Learned (GALL) Report Revision 2 AMP XI.M41, "Buried and Underground Piping and Tanks" (LR-ISG-2011-03)This LR-ISG provides interim guidance to applicants for license renewal as to one acceptable approach to managing the aging effects of buried and underground piping and tanks within the scope of license renewal. LR-ISG-2011-03 revises the guidance provided in NUREG-1801, Revision 2, XI.M41,"Buried and Underground Piping and Tanks" program. The LSCS Selective Leaching (B.2.1.22) program, External Surfaces Monitoring of Mechanical Components (B.2.1.24) program, and Buried and Underground Piping (B.2.1.28) program incorporate the guidance presented in this LR-ISG.2.1.4.5 Updated Aging Management Criteria for Reactor Vessel Internal Components of Pressurized Water Reactors (LR-ISG-2011-04)
This guidance does not apply to LSCS which is a boiling water reactor.2.1.4.6 Ongoing Review of Operating Experience (LR-ISG-2011-05)
This LR-ISG provides interim guidance to applicants for license renewal revising NUREG-1 800 acceptance criteria and review procedures to better address the ongoing review of operating experience with respect to license renewal aging management programs.
The LSCS license renewal application incorporates the guidance presented in this LR-ISG. Ongoing review of operating experience is addressed in Appendix A, Section A. 1.6 and Appendix B, Section B.1.4.2.1.4.7 Wall Thinning Due to Erosion Mechanisms (LR-ISG-2012-01)
This LR-ISG provides interim guidance to applicants for license renewal as to one acceptable approach to managing the aging effect of wall thinning due to various erosion mechanisms in piping and components within the scope of license renewal. LR-ISG-2012-01 revises the guidance provided in NUREG-1801, Revision 2, XI.M17, "Flow-Accelerated Corrosion" program. The LSCS Flow-Accelerated Corrosion (B.2.1.10) program incorporates the guidance presented in this LR-ISG.LaSalle County Station, Units 1 and 2 Page 2.1-16 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 2.1.4.8 Aging Management of Internal Surfaces, Fire Water Systems, Atmospheric Storage Tanks, and Corrosion Under Insulation (LR-ISG-2012-02)This LR-ISG provides interim guidance to applicants for license renewal as to one acceptable approach to managing the effects of aging. The ISG addresses recurring internal corrosion, representative minimum sample size for internal inspections, fire water system blockage, revised scope and inspection for tanks, corrosion under insulation, volumetric examination of underground piping, and pressurization of elastomers.
The LSCS Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program, Fire Water System (B.2.1.17) program, Aboveground Metallic Tanks (B.2.1.18) program, External Surfaces Monitoring of Mechanical Components (B.2.1.24) program, Open-Cycle Cooling Water System (B.2.1.12) program, Selective Leaching (B.2.1.22) program and Closed Treated Water Systems (B.2.1.13) program incorporate the guidance presented in this LR-ISG.2.1.4.9 Aging Management of Loss of Coating Integrity for Internal Service Level III (Augmented)
Coatinas (Draft LR-ISG-2013-01; ADAMS Accession No.ML13262A442)
This draft LR-ISG provides interim guidance to applicants for license renewal as to one acceptable approach to managing loss of coating integrity due to blistering, cracking, flaking, peeling, or physical damage of Service Level III (augmented) coatings.
Draft LR-ISG-2013-01 provides for a new NUREG-1801 aging management program for Service Level III (augmented) coatings.LSCS will implement a Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) plant-specific program for managing the loss of coating integrity in Service Level III (augmented) coatings which incorporates the guidance presented in this draft LR-ISG.2.1.5 SCOPING PROCEDURE The scoping process is the systematic process used to identify the LSCS systems, structures, and components within the scope of the license renewal rule. The scoping process was initially performed at the system and structure level, in accordance with the scoping criteria identified in 10 CFR 54.4(a).System and structure functions and intended functions were identified from a review of the source CLB documents.
In scope boundaries were established and documented in the scoping evaluations, based on the identified intended functions.
The in scope boundaries form the basis for identification of the in scope components, which is the first step in the screening process described in Section 2.1.6. System and structure scoping evaluations are documented and have been retained in a license renewal database.
The system and structure scoping results are provided in Section 2.2.The LSCS scoping process began with the development of a comprehensive list of plant systems and structures, as described in Section 2.1.3.1. The systems and structures were grouped into one of the following categories:
LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-17 Section 2 -Scoping and Screening Methodology and Results" Reactor Vessel, Internals, and Reactor Coolant System" Engineered Safety Features" Auxiliary Systems* Steam and Power Conversion System" Structures and Component Supports* Electrical Components Each LSCS system and structure was then scoped for license renewal using the criteria of 10 CFR 54.4(a). These criteria are briefly identified as follows:* Title 10 CFR 54.4(a)(1)-
Safety-Related" Title 10 CFR 54.4(a)(2)
-Nonsafety-Related affecting safety-related" Title 10 CFR 54.4(a)(3)
-Regulated Events: o Fire Protection (10 CFR 50.48)o Environmental Qualification, EQ (10 CFR 50.49)o Pressurized Thermal Shock (10 CFR 50.61) (PWRs only)o Anticipated Transient Without Scram, ATWS (10 CFR 50.62)o Station Blackout, SBO (10 CFR 50.63)The application of each of these criteria is discussed in Section 2.1.5.1, Section 2.1.5.2, and Section 2.1.5.3 below: 2.1.5.1 Safety-Related
-10 CFR 54.4(a)(1)
In accordance with 10 CFR 54.4(a)(1), the systems, structures, and components within the scope of license renewal include: Safety-related systems, structures, and components which are those relied upon to remain functional during and following design-basis events (as defined in 10 CFR 50.49(b)(1))
to ensure the following functions
-(i) The integrity of the reactor coolant pressure boundary;(ii) The capability to shutdown the reactor and maintain it in a safe shutdown condition; or (iii) The capability to prevent or mitigate the consequences of accidents which could result in potential offsite exposures comparable to those referred to in 10 CFR 50.34(a)(1), 10 CFR 50.67(b)(2), or 10 CFR 100.11, as applicable.
At LSCS, the safety-related plant components are identified in controlled engineering drawings and summarized in the Passport equipment database.The safety-related classifications in the LSCS Passport equipment database were populated using a controlled procedure, with classification criteria consistent with the above 10 CFR 54.4(a)(1) criteria.
The classification criteria differences have been evaluated in a license renewal basis document as described in Section 2.1.3.2 and accounted for during the license renewal scoping process.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-18 Section 2 -Scoping and Screening Methodology and Results Safety-related classifications for systems and structures are based on system and structure descriptions and analyses in the UFSAR, or on design basis documents such as engineering drawings, design specifications, evaluations, or calculations.
Safety-related structures are those structures listed in the UFSAR and classified as Seismic Category I. Systems and structures that are identified as safety-related in the UFSAR or in design basis documents have been classified as satisfying the criteria of 10 CFR 54.4(a)(1) and have been included within the scope of license renewal. Safety-related components listed in the Passport equipment database were also reviewed and the system or structure associated with the safety-related component was included within the scope of license renewal in accordance with 10 CFR 54.4(a)(1) criteria.
The review also confirmed that plant conditions, internal and external events including design basis accidents (DBAs), anticipated operational transients, abnormal operational transients, and natural phenomena as described in the current licensing basis (CLB), were considered for license renewal scoping.2.1.5.2 Nonsafety-Related Affecting Safety-Related
-10 CFR 54.4(a)(2)
In accordance with 10 CFR 54.4(a)(2), the systems, structures, and components within the scope of license renewal include:* All nonsafety-related systems, structures, and components whose failure could prevent satisfactory accomplishment of any of the functions identified in 10 CFR 54.4(a)(1)(i), (ii), or (iii).This scoping criterion requires an assessment of nonsafety-related SSCs with respect to the following application or configuration categories:
* Functional support for safety-related SSC 10 CFR 54.4(a)(1) functions* Connected to and provide structural support for safety-related SSCs* Potential for spatial interactions with safety-related SSCs Each of these three categories is discussed below: Functional Support for Safety-Related SSC 10 CFR 54.4(a)(1)
Functions This category addresses nonsafety-related SSCs that are required to function in support of a safety-related SSC intended function.
The functional requirement distinguishes this category from the other categories, where the nonsafety-related SSCs are required only to maintain adequate integrity to preclude structural failure or spatial interactions.
The nonsafety-related SSCs that were included within the scope of license renewal to support a safety-related SSC in performing a 10 CFR 54.4(a)(1) intended function are identified on the license renewal boundary drawings in green.The LSCS UFSAR and other CLB documents were reviewed to identify nonsafety-related systems or structures required to support satisfactory accomplishment of a safety-related function.
Nonsafety-related systems or structures credited in CLB documents to support a safety-related function have been included within the scope of license renewal. LSCS classifies systems LaSalle County Station, Units 1 and 2 Page 2.1-19 License Renewal Application Section 2 -Scoping and Screening Methodology and Results that are required to perform or support a safety-related function as safety-related, with the following exceptions: " The Area Radiation Monitoring System includes nonsafety-related SSCs that are functionally relied upon to directly mitigate the consequences of the radwaste gas leak abnormal operational transient.
* The Condenser and Air Removal System includes the nonsafety-related main condenser which is credited for holdup and plateout of MSIV leakage following a LOCA. Additionally, manual isolation of the nonsafety-related main condenser off-gas outlet valves and manual tripping of the nonsafety-related mechanical vacuum pump is credited following a control rod drop accident to minimize radioactive releases.* The Cranes, Hoists and Refueling Equipment System includes nonsafety-related cranes, hoists and refueling equipment that provide a safe means for handling loads above or near safety-related components.
* The Main Steam System includes nonsafety-related SSCs that contain leakage from the MSIVs and routes the leakage to the main condenser for holdup and plateout prior to release following a LOCA.* Main Turbine and Auxiliaries System includes the nonsafety-related low pressure turbine exhaust hoods which are credited for holdup and plateout of MSIV leakage following a LOCA.* The Plant Computer System includes nonsafety-related SSCs that are functionally relied upon to support operator actions that mitigate the consequences of analyzed accidents as presented in the UFSAR Accident Analyses, including abnormal operating transients.
* The Plant Drainage System includes nonsafety-related floor drains in the Reactor Building that are credited for the mitigation of flooding as a result of a high energy line break (HELB) or a moderate energy line break (MELB) in the Reactor Building.
Additionally, the nonsafety-related drywell drain lines that are routed through the suppression chamber airspace prior to exiting the primary containment are in scope to ensure their pressure boundary integrity to prevent drywell to suppression chamber bypass leakage." The Process Radiation Monitoring System includes the nonsafety-related station vent stack wide range radiation monitor which is credited to sense process conditions and generate signals to actuate control room alarms to prompt operator actions in response to a radwaste gas leak abnormal operational transient.
* The Reactivity Control System includes the nonsafety-related rod worth minimizer which is credited to prevent rod withdrawal error at low power.Additionally, the rod worth minimizer is credited for a control rod drop accident.LaSalle County Station, Units 1 and 2 Page 2.1-20 License Renewal Application Section 2 -Scoping and Screening Methodology and Results The Safety-Related Ventilation System includes nonsafety-related SSCs that provide a pathway to the station vent stack for the potential release of fission products following certain abnormal operational transients.
These nonsafety-related systems, nonsafety-related portions of safety-related systems, and structures were included within the scope of license renewal in accordance with 10 CFR 54.4(a)(2).
As an additional confirmation of scoping to meet 10 CFR 54.4(a)(2) criteria, a supporting system review was completed as part of the scoping process. The scoping process was performed on a system and structure basis. For systems included within the scope of license renewal in accordance with the requirements of 10 CFR 54.4(a)(1), the scoping evaluation included the identification of any additional systems, including nonsafety-related systems, that are required to support the safety-related system intended functions.
It was then confirmed that these identified supporting systems were also included in scope. Except as identified above, the LSCS systems required to support 10 CFR 54.4(a)(1) functions are classified safety-related, and as such included within the scope of license renewal in accordance with 10 CFR 54.4(a)(1).
The identification of supporting systems was not required for structures since structural intended functions do not rely on supporting systems.The next three 10 CFR 54.4(a)(2) scoping categories are the subject of NEI 95-10, Appendix F. The guidance requires that, when demonstrating that failures of nonsafety-related systems would not adversely impact the ability to maintain intended functions, a distinction must be made between nonsafety-related systems that are directly connected to safety-related systems and those that are not directly connected to safety-related systems. For a nonsafety-related piping system that is directly connected to and provides structural support for a safety-related piping system, the nonsafety-related piping and supports shall be included within the scope of license renewal up to (1) the analytical boundary defined in the CLB seismic analysis for the safety-related piping or, (2) if the seismic boundary is not clearly defined in the CLB information, up to the point beyond which the failure of the nonsafety-related piping will not render the safety-related portion of the piping system unable to perform its intended function under CLB design conditions.
The location of the point beyond which the failure of the nonsafety-related piping will not render the safety-related portion of the piping system unable to perform its intended function under CLB design conditions is identified using the guidance presented in NEI 95-10, Appendix F, Section 4.For nonsafety-related systems which are not connected to safety-related piping or components, or are outside the structural support boundary for the attached safety-related piping system, but have a spatial relationship such that their failure could adversely impact the performance of a safety-related SSC's intended function, there are two scoping options: a mitigative option or a preventive option. When mitigative features (e.g., pipe whip restraints, jet impingement shields, spray and drip shields, seismic supports, flood barriers, and physical barriers such as floors, walls, and doors) are provided to protect safety-related SSCs from failures of nonsafety-related SSCs, this LaSalle County Station, Units 1 and 2 Page 2.1-21 License Renewal Application Section 2 -Scoping and Screening Methodology and Results demonstration should show that mitigating devices are adequate to protect safety-related SSCs from failures of nonsafety-related SSCs regardless of failure location.
If this level of protection can be demonstrated, then only the mitigative features need to be included within the scope of license renewal.However, if it cannot be demonstrated that the mitigative features are adequate to protect safety-related SSCs from the consequences of failures of nonsafety-related SSCs, then the preventive option is used, which requires that the nonsafety-related SSC be brought into the scope of license renewal.The methodology for identification of LSCS SSCs that satisfy the 10 CFR 54.4(a)(2) scoping criterion was based on a review of applicable CLB documents, as well as plant-specific and industry operating experience.
The mitigative and preventive options are both used to demonstrate that safety-related SSCs are adequately protected from failure of nonsafety-related SSCs.Connected to and Provide Structural Support for Safety-Related SSCs For nonsafety-related SSCs directly connected to safety-related SSCs the nonsafety-related piping and supports, up to and including the first seismic or equivalent anchor (such as a series of supports that have been evaluated as a part of a plant-specific piping design analysis to ensure that forces and moments are restrained in three (3) orthogonal directions) beyond the safety/nonsafety interface, are within the scope of license renewal per 10 CFR 54.4(a)(2).
The "first seismic or equivalent anchor" is defined such that the failure in the nonsafety-related pipe run beyond the first seismic or equivalent anchor will not render the safety-related portion of the piping unable to perform its intended function under CLB design conditions.
An alternative to specifically identifying a seismic anchor or equivalent anchor that supports the safety-related/nonsafety-related piping interface is to include enough of the nonsafety-related piping run to ensure these anchors are included and thereby ensure the piping and anchor intended functions are maintained.
The intended function consists of two facets 1) providing structural support for the safety-related/nonsafety-related interface and 2) ensuring nonsafety-related piping loads are not transferred through the safety-related/nonsafety-related interface.
The following methods (a) thru (g) were used to define end points for the portion of nonsafety-related piping attached to safety-related piping to be included in the scope of license renewal. In these cases the nonsafety-related piping was included in scope for 10 CFR 54.4(a)(2) up to one of the following:
a) A combination of restraints or supports that encompasses at least two (2)supports in each of three (3) orthogonal directions.
b) A base-mounted component (e.g., pump, heat exchanger, tank, etc.) that is a rugged component and is designed not to impose loads on connecting piping. The license renewal scope includes the base-mounted component as it has a support function for the safety-related piping.c) A flexible connection that is considered a pipe stress analysis model end point when the flexible connection effectively decouples the piping LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-22 Section 2 -Scoping and Screening Methodology and Results system (i.e. does not support loads or transfer loads across it to connecting piping).d) A free end of nonsafety-related piping, such as a drain pipe that ends at an open floor drain.e) For nonsafety-related piping runs that are connected at both ends to safety-related piping, the entire run of nonsafety-related piping is included in scope.f) A point where buried piping exits the ground. The buried portion of the piping should be included in the scope of license renewal. A determination that the buried piping is well founded on compacted soil that is not susceptible to liquefaction must be documented.
g) A smaller branch line where the moment of inertia ratio of the larger piping to the smaller piping is equal to or greater than the acceptable ratio defined by the current licensing basis, because significantly smaller piping does not impose loads on larger piping and does not support larger piping.These scoping boundaries are determined from review of the physical installation details, design drawings, or seismic analysis calculations.
Failure in the nonsafety-related piping beyond the above anchor locations would not impact structural support for the safety-related piping. The associated piping and components included within the scope of license renewal are identified on the license renewal boundary drawings in red.Symbols identifying the anchor locations and the seismic analysis boundaries that define the structural support boundary for safety-related piping systems are shown on the license renewal boundary drawings in blue. Note that if the connected nonsafety-related piping system contains water, steam or oil, then the in scope boundary may extend beyond the locations described above due to potential for spatial interaction with safety-related SSCs.Potential for Spatial Interactions with Safety-Related SSCs Nonsafety-related systems that are not connected to safety-related piping or components, or are outside the structural support boundary for the attached safety-related piping system, and have a spatial relationship such that their failure could adversely impact the performance of a safety-related SSC intended function, must be evaluated for license renewal scope in accordance with 10 CFR 54.4(a)(2) requirements.
As described in NEI 95-10, Appendix F, there are two options when performing this scoping evaluation:
a mitigative option and a preventive option.The mitigative option involves crediting plant mitigative features to protect safety-related SSCs from failures of nonsafety-related SSCs. Examples of plant mitigative features include pipe whip restraints, jet impingement shields, spray and drip shields, seismic supports, flood barriers, and physical barriers (e.g., floors, walls, doors). This option requires a demonstration that the mitigating features are adequate to protect safety-related SSCs from failures of LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-23 Section 2 -Scoping and Screening Methodology and Results nonsafety-related SSCs regardless of failure location.
If this level of protection can be demonstrated, then only the mitigative features need be included within the scope of license renewal. Mitigative plant design features are used in the Turbine Building and Offgas Building to exclude SSCs from the scope of license renewal at LSCS by defining the boundaries for areas where spatial interaction is not a concern.The preventive option involves identifying the nonsafety-related SSCs that have a spatial relationship such that failure could adversely impact the performance of a safety-related SSC intended function, and including the identified nonsafety-related SSC within the scope of license renewal without consideration of plant mitigative features.
With the exception of the Turbine Building and Offgas Building, LSCS applied the preventive option for 10 CFR 54.4(a)(2) scoping.The preventive option assumes potential spatial interaction in structures or portions of structures that contain active or passive SSCs that have safety-related functions.
The structures of concern for potential spatial interaction were identified based on a review of the CLB to determine which structures contained active or passive safety-related SSCs. Plant walkdowns were performed as required to confirm that all structures containing safety-related SSCs were identified.
With the exception of the Turbine Building and Offgas Building, it was assumed that all nonsafety-related SSCs within these structures were located in proximity to safety-related SSCs where potential spatial interaction could occur.The Turbine Building and Offgas Building have few areas containing safety-related SSCs. Mitigative features were used to prevent spatial interaction between these safety-related SSCs and nonsafety-related SSCs in other areas. No credit was taken for separation by distance alone without a mitigative feature capable of preventing the spatial interaction.
The mitigative features were included in the scope of license renewal. This evaluation was documented in a technical basis document.Nonsafety-related piping and components that contain water, oil, or steam, and are located inside structures that contain safety-related SSCs, are included in scope for potential spatial interaction under criterion 10 CFR 54.4(a)(2), unless located in an area where there is no concern with spatial interaction.
High-energy lines with potential spatial interaction are included in the scope of license renewal under 10 CFR 54.4(a)(1) or (a)(2) depending on their safety classification.
Safety-related high-energy lines are in scope under 10 CFR 54.4(a)(1), and nonsafety-related high-energy lines are in scope under 10 CFR 54.4(a)(2).
Potential spatial interaction due to leakage or spray is assumed for system pressure as low as atmospheric.
Air and gas systems (non-liquid) are not a hazard to other plant equipment, and have therefore been determined not to have spatial interactions with safety-related SSCs. SSCs containing air or gas cannot adversely affect safety-related SSCs due to leakage or spray, since gas systems contain no liquids that could spray or leak onto safety-related systems to cause shorts or other malfunctions.
LSCS operating experience was reviewed and confirmed LaSalle County Station, Units 1 and 2 Page 2.1-24 License Renewal Application Section 2 -Scoping and Screening Methodology and Results that there have been no failures due to aging in systems containing air or gas that have adversely impacted the accomplishment of a safety function.Additionally, air and gas systems are classified as moderate energy systems.As described in NEI 95-10, Appendix F, paragraph 5.2.2.2.2, physical impact from pipe whip or jet impingement from moderate energy systems do not occur and need not be considered.
Thus the nonsafety-related systems containing air or gas are not included in the scope of license renewal for spatial interaction.
The supports are included in scope to prevent the nonsafety-related piping from falling down and potentially impacting safety-related SSCs.The piping systems included in the scope of license renewal under 10 CFR 54.4(a)(2) for potential spatial interaction with safety-related SSCs are identified on the license renewal boundary drawings in red.Scoping of Abandoned Equipment Abandoned equipment is not included within the scope of license renewal if it has been confirmed to be isolated, vented, and drained. If this confirmation cannot be made, the system or portions thereof, are included within the scope of license renewal for aging management.
Abandoned equipment is not relied on to perform any function delineated in 10 CFR 54.4(a)(1) or (a)(3) as it is nonoperational.
However, failure of abandoned equipment could potentially impact the performance of the safety-related function of surrounding equipment if the abandoned equipment contains water, steam, or oil. The abandoned equipment excluded from scope has been vented, fluids drained, and isolated, and therefore, this equipment does not perform any intended function for license renewal. In addition, disconnection of wiring for power, control, or parameter indication and air supplies is not necessary to assure that the abandoned equipment has no potential spatial interaction with surrounding equipment.
2.1.5.3 Regulated Events -10 CFR 54.4(a)(3)
In accordance with 10 CFR 54.4(a)(3), the systems, structures, and components within the scope of license renewal include: All systems, structures and components relied on in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for fire protection (10 CFR 50.48), environmental qualification (10 CFR 50.49), pressurized thermal shock (10 CFR 50.61), anticipated transients without scram (10 CFR 50.61), and station blackout (10 CFR 50.63).The regulation for pressurized thermal shock (10 CFR 50.61) is applicable to pressurized water reactors only, and therefore not applicable to LSCS which is a boiling water reactor. For each of the other four regulations, a technical basis document was prepared to provide input into the scoping process. Each of the regulated event basis documents (described in Section 2.1.3.4) identify the systems and structures that are relied upon to demonstrate compliance with the applicable regulation.
The basis documents also identify the source documentation used to determine the scope of components within the system LaSalle County Station, Units 1 and 2 Page 2.1-25 License Renewal Application Section 2 -Scoping and Screening Methodology and Results that are credited to demonstrate compliance with each of the applicable regulated events. Guidance provided by the technical basis documents was 0 incorporated into the system and structure scoping evaluations, to determine the SSCs credited for each of the regulated events. SSCs credited in the regulated events have been classified as satisfying criteria of 10 CFR 54.4(a)(3) and have been included within the scope of license renewal.2.1.5.4 System and Structure Intended Functions For the systems and structures within the scope of license renewal, the intended functions that are the bases for including them within the scope of license renewal are identified and documented in the scoping evaluation.
The system or structure intended functions are based on the applicable CLB reference documents.
For systems, the system level intended function descriptions associated with 10 CFR 54.4(a)(1) were standardized based on nuclear safety criteria for boiling water reactors as documented in industry standard ANSI/ANS-52.1-1983.
The use of standardized 10 CFR 54.4(a)(1) functions provided for consistent function application and appropriate level of detail for system level intended function descriptions.
The component level intended functions are the passive component functions that are necessary to support the system or structure intended function(s).
The structure and component intended functions are further described in Section 2.1.6.2.2.1.5.5 Scoping Boundary Determination Systems and structures that are included within the scope of license renewal are then further evaluated to determine the population of in scope structures and components.
This part of the scoping process is also a transition from the scoping process to the screening process. The process for evaluating mechanical systems is different from the process for structures, primarily because the plant design document formats are different.
Mechanical systems are depicted primarily on the system piping and instrumentation diagrams (P&ID) that show the system components and their functional relationships, while structures are depicted on physical drawings.
Electrical and I&C components of in scope electrical and in scope mechanical systems are placed into commodity groups and are screened as commodities.
Scoping boundaries for mechanical systems, structures, and electrical systems are, therefore, described separately.
Mechanical Systems For mechanical systems, the mechanical components that support the system intended functions are included within the scope of license renewal and are depicted on the applicable system piping and instrumentation diagram.Mechanical system piping and instrumentation diagrams are marked up to create license renewal boundary drawings showing the in scope components.
Components that are required to perform or support a safety-related function, or a function that demonstrates compliance with one of the license renewal regulated events, are identified on the system piping and instrumentation diagrams by green highlighting.
Nonsafety-related components that are connected to safety-related components and are required to provide structural LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-26 Section 2 -Scoping and Screening Methodology and Results support at the safety/nonsafety interface, or components whose failure could prevent satisfactory accomplishment of a safety-related function due to spatial interaction with safety-related SSCs, are identified by red highlighting.
A computer sort and download of associated system components from the Passport equipment database confirms the scope of components in the system. Plant walkdowns were performed when required for additional confirmation.
Structures For structures, the structural components that support the intended functions are included in the scope of license renewal. The structural components are identified from a review of applicable plant design drawings of the structure, applicable UFSAR sections, and design basis documentation.
Plant walkdowns were performed when required for additional confirmation.
Structural bolting required to support the structure proper is evaluated with the structure.
Structural bolting supporting the intended function of a component support or a structural commodity component is evaluated with the component support or structural commodity component.
A site plan layout drawing is marked up to create a license renewal boundary drawing showing the structures within the scope of license renewal.Electrical Systems Electrical and I&C systems, and electrical components within mechanical systems, did not require further system evaluations to determine which components were required to perform or support the identified intended functions.
A bounding scoping approach is used for electrical equipment.
All electrical components within in scope systems were included within the scope of license renewal. In scope electrical components were placed into commodity groups and were evaluated as commodities during the screening process as described in Section 2.1.6.2.1.6 SCREENING PROCEDURE Once the SSCs within the scope of license renewal have been determined, the next step is to determine which structures and components are subject to an aging management review.2.1.6.1 Identification of Structures and Components Subject to AMR The requirement to identify structures and components subject to an aging management review is specified in 10 CFR 54.21(a)(1), which states: Each license renewal application must contain the following information: (a) An integrated plant assessment (IPA). The IPA must -(1) For those systems, structures, and components within the scope of this part, as delineated in §54.4, identify and list those structures and components subject to an aging management review.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-27 Section 2 -Scoping and Screening Methodology and Results Structures and components subject to an aging management review shall encompass those structures and components-(i) That perform an intended function, as described in §54.4, without moving parts or without a change in configuration or properties.
These structures and components include, but are not limited to, the reactor vessel, the reactor coolant system pressure boundary, steam generators, the pressurizer, piping, pump casings, valve bodies, the core shroud, component supports, pressure retaining boundaries, heat exchangers, ventilation ducts, the containment, the containment liner, electrical and mechanical penetrations, equipment hatches, seismic Category I structures, electrical cables and connections, cable trays, and electrical cabinets, excluding, but not limited to, pumps (except casing), valves (except body), motors, diesel generators, air compressors, snubbers, the control rod drive, ventilation dampers, pressure transmitters, pressure indicators, water level indicators, switchgears, cooling fans, transistors, batteries, breakers, relays, switches, power inverters, circuit boards, battery chargers, and power supplies;and (ii) That are not subject to replacement based on a qualified life or specified time period.Structures and components that perform an intended function without moving parts or without a change in configuration or properties are defined as passive for license renewal. Passive structures and components that are not subject to replacement based on a qualified life or specified time period are defined as long-lived for license renewal. The screening procedure is the process used to identify the passive, long-lived structures and components within the scope of license renewal that are subject to aging management review.NUREG-1 800, "Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants" and NEI 95-10, Appendix B, were used as the basis for the identification of passive structures and components.
Most passive structures and components are long-lived.
In the few cases where a passive component is determined not to be long-lived, such determination is documented in the screening evaluation and, if applicable, on the associated license renewal boundary drawing.The LSCS structures and components subject to aging management review have been identified in accordance with the requirements of 10 CFR 54.21 (a)(1) described above. The process implemented to meet these requirements for mechanical systems, structures, and electrical commodities is described as follows: Mechanical Systems The mechanical system screening process began with the results from the scoping process. For in scope mechanical systems, the completed scoping packages include written descriptions and marked up system piping and LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-28 Section 2 -Scoping and Screening Methodology and Results instrumentation diagrams that clearly identify the in scope system boundary for license renewal. The marked up system piping and instrumentation diagrams are called license renewal boundary drawings.
These system boundary drawings were reviewed to identify the passive, long-lived components, and the identified components were then entered into the license renewal database.
Component listings from the Passport equipment database were also reviewed to confirm that all system components were considered.
In cases where the system piping and instrumentation diagram did not provide sufficient detail, such as for some large vendor supplied components (e.g., compressors, emergency diesel generators), the associated component drawings or vendor manuals were also reviewed.
Plant walkdowns were performed when required for confirmation.
Some mechanical components, when combined, are considered a complex assembly.
A complex assembly is a predominantly active assembly where the performance of its components is closely linked to that of the intended function of the entire assembly, such that testing and monitoring of the assembly is sufficient to identify degradation of these components.
Examples of complex assemblies include diesel generators and chiller units. Complex assemblies are considered active and can be excluded from the requirements of AMR.However, to the extent that complex assemblies include piping or components that interface with external equipment, or components that cannot be adequately tested or monitored as part of the complex assembly, those components are identified and subject to aging management review. This follows the screening methodology for complex assemblies as described in Table 2.1-2 of NUREG-1800, "Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants," Revision 2 (reference 1.7.4).Mechanical components are screened with the system in which they were scoped. For heat exchangers, the process side of the heat exchanger is evaluated with the process side system for aging management review.Likewise, the cooling water side of the heat exchanger is evaluated with the cooling water side system for aging management review.Structures The structure screening process also began with the results from the scoping process. For in scope structures, the completed scoping packages include written descriptions of the structure.
If only selected portions of the structure are in scope, the in scope portions are described in the scoping evaluation.
The associated structure drawings were reviewed to identify the passive, long-lived structures and components, and the identified structures and components were then entered into the license renewal database.
Plant walkdowns were performed when required for confirmation.
Electrical Commodities Screening of electrical and I&C components within the in scope electrical, I&C, and mechanical systems used a bounding approach as described in NEI 95-10. Electrical and I&C components for the in scope systems were assigned to commodity groups. The commodities subject to an aging management LaSalle County Station, Units 1 and 2 Page 2.1-29 License Renewal Application Section 2 -Scoping and Screening Methodology and Results review are identified by applying the criteria of 10 CFR 54.21 (a)(1). This method provides the most efficient means for determining the electrical commodities subject to an aging management review since many electrical and I&C components and commodities are active.Electrical and I&C components such as elements, resistance temperature detectors (RTDs), sensors, thermocouples, and transducers as well as electric heaters primarily serve an electrical function; however, they can also serve a mechanical pressure boundary function.
According to Appendix B of NEI 95-10, the electrical portions of these components are active per 10 CFR 54.21 (a)(1)(i) and are therefore not subject to aging management review. Only the pressure boundary of such an in scope component is subject to aging management review, and the pressure boundary function for these electrical and I&C components is addressed in the mechanical review.The sequence of steps and special considerations for identification of electrical commodities that require an aging management review is as follows: 1. Electrical and I&C components and commodities in systems within the scope of license renewal at LSCS were identified and listed. The listing provided by NEI 95-10, Appendix B, is the basis for this list. Electrical and I&C components and commodities were organized into groups such as circuit breakers, switches, and cables. Individual specific components were not identified.
The electrical commodities were identified from a review of plant documents, controlled drawings, the Passport equipment database, and interface with the parallel mechanical screening efforts.2. Following the identification of the electrical commodities, the criterion of 10 CFR 54.21(a)(1)(i) was applied to identify commodities that perform their functions without moving parts or without a change in configuration or properties (referred to as "passive" components).
These commodities were identified utilizing the guidance of NEI 95-10.3. Electrical and I&C components and commodities were not evaluated to determine if they perform a license renewal intended function during the scoping of systems. At this point in the screening process, the remaining passive electrical commodities are reviewed to determine if the commodity performs a license renewal intended function.
If an electrical commodity does not perform a license renewal intended function, it is not considered further and, therefore, is not subject to an aging management review.4. The screening criterion found in 10 CFR 54.21 (a)(1)(ii) excludes those commodities that are subject to replacement based on a qualified life or specific time period from the requirements of an aging management review. The 10 CFR 54.21(a)(1)(ii) screening criterion was applied to those commodities that were not previously eliminated by the application of the 10 CFR 54.21(a)(1)(i) screening criterion.
Components and commodities included in the plant environmental qualification (EQ) program are replaced on a specified interval based on a qualified life. Components and commodities in the EQ program do not meet the "long-lived" criterion of 10 CFR 54.21 (a)(1)(ii) and are considered "short-lived" per the LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-30 Section 2 -Scoping and Screening Methodology and Results regulatory definition and are, therefore, not subject to an aging management review.5. Components and commodities which support or interface with electrical components and commodities, for example, cable trays, conduits, instrument racks, panels and enclosures, are evaluated as structural components in Section 2.4.The electrical commodities that require an aging management review are the separate electrical commodities that are not part of a larger active component.
The passive commodities that are not subject to replacement based on a qualified life or specified time period are subject to an aging management review. For LSCS, the electrical commodities that require an aging management review are identified in Section 2.5.2.1.6.2 Intended Function Definitions The intended functions that the components and structures must fulfill are those functions that are the bases for including them within the scope of license renewal. A component intended function is defined as a passive component function that must be performed in order for the system or structure to be able to perform the system or structure intended function(s).
For example, pressure boundary failure of a component would cause loss of inventory from the system, and the system would subsequently be unable to perform its intended function(s).
Structures and components may have multiple intended functions.
LSCS has considered multiple intended functions where applicable, consistent with the staff guidance provided in Table 2.1-3 of NUREG-1 800, "Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants" (reference 1.7.4).Table 2.1-1 provides expanded definitions of structure and component passive intended functions identified in this application.
LaSalle County Station, Units 1 and 2 Page 2.1-31 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.1-1 Passive Structure and Component Intended Function Definitions Intended Function Definition Absorb Neutrons Absorb neutrons.Provide post-accident containment, plateout of iodine and holdup (for Containment, Holdup and radioactive decay) of iodine and non-condensable gases before release.Direct Flow Provide spray shield or curbs for directing flow. Also applies to diffuser credited for fluid diffusion/dissipation.
Provide electrical connections to specified sections of an electrical Electrical Continuity circuit to deliver voltage, current, or signals.Filter Provide filtration or foreign material exclusion.
Provide rated fire barrier to confine or retard fire from spreading to or from adjacent areas of the plant.Flood Barrier Provide flood protection barrier (internal and external flood event).Gaseous Release Path Provide path for release of filtered and unfiltered gaseous discharge.
Heat Transfer Provide heat transfer.HELB/MELB Shielding Provide shielding against high energy line breaks (HELB), and protective features for medium energy line breaks (MELB).Insulate (Electrical)
Insulate and support an electric conductor.
Nonsafety-related component that maintains mechanical and structural integrity to prevent spatial interactions that could cause failure of Leakage Boundary safety-related SSCs. This function includes the required structural integrity when the nonsafety-related leakage boundary piping is also attached to safety-related piping.Maintain Adhesion Provides adhesion to the substrate.
Mechanical Closure Provide closure of components.
Typically used with bolting.Missile Barrier Provide missile barrier (internal or external missiles).
Pipe Whip Restraint Provide pipe whip restraint.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-32 Section 2 -Scoping and Screening Methodology and Results Table 2.1-1 Passive Structure and Component Intended Function Definitions Intended Function Definition Provide pressure-retaining boundary so that sufficient flow at adequate pressure is delivered, or provide fission product barrier for containment Pressure Boundary pressure boundary, or provide containment isolation for fission product retention, or provide the containment, holdup and plateout function (for Main Steam system).Pressure Relief Provide overpressure protection.
Shelter, Protection Provide shelter/protection to safety-related components.
Shielding Provide shielding against radiation.
Spray Convert fluid into spray.Nonsafety-related component that maintains mechanical and structural Structural Integrity integrity to provide structural support to attached safety-related piping.Provide pressure boundary or essentially leak tight barrier to protect Barrier public health and safety in the event of any postulated design basis events.Provide structural support for structures and components within the Structural Support scope for 10 CFR 54.4(a)(1), (a)(2), or (a)(3) or provide structural integrity to preclude nonsafety-related component interactions that could prevent satisfactory accomplishment of a safety-related function.Structural Support to Provide structural support of fuel assemblies, control rods, and incore maintain core instrumentation, to maintain core configuration and flow distribution.
configuration and flow distribution Control of heat loss to preclude overheating of nearby safety-related Thermal InsulationSSs SSCs.Thermal Insulation Jacket Provide jacket integrity for jacketed thermal insulation.
Integrity Throttle Provide flow restriction.
Water retaining boundary Provide an essentially leak-tight boundary.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-33 Section 2 -Scoping and Screening Methodology and Results 2.1.6.3 Stored Equipment For several fire zones, credit is taken for making repairs to equipment in order to perform safe shutdown functions.
In all cases, such credit is taken only to accomplish a function required for cold shutdown.
Equipment that is stored on site for installation or use in achieving cold shutdown is considered to be within the scope of license renewal. Specific repairs credited for individual fire zones are discussed in the LSCS Fire Protection Report (FPR) subsection H.4.5. For each repair credited in the FPR, a procedure has been written and is available to cover the repair, and, the quantity and specific type of materials required by the analysis and the procedure are reserved onsite. Periodic surveillances are performed to inventory and check the availability of equipment necessary to support the repairs. Tools and supplies used to place the stored equipment in service are not within the scope of license renewal.2.1.6.4 Consumables The evaluation process for consumables is consistent with the guidance provided in NUREG-1800, Table 2.1-3. Consumables have been divided into the following four (4) groups for the purpose of license renewal: (a) packing, gaskets, component seals, and O-rings; (b) structural sealants; (c) oil, grease, and component filters; and (d) system filters, fire extinguishers, fire hoses, and air packs.* Group (a) subcomponents (packing, gaskets, component seals, and 0-rings): Based on ANSI B31.1 and the ASME B&PV Code Section III, these subcomponents of pressure retaining components are not pressure-retaining parts. Therefore, these subcomponents are not relied on to form a pressure-retaining function and are not subject to an AMR.* Group (b) structural sealants:
AMRs were required for structural sealants in structures within the scope of license renewal. A summary of the AMR results is presented in Section 3.5.* Group (c) subcomponents (oil, grease, and component filters):
These subcomponents are short-lived and are periodically replaced.
Various plant procedures are used in the replacement of oil, grease, and filters in components that are in scope for license renewal. Therefore, these subcomponents are not subject to an AMR." Group (d) consumables (system filters, fire extinguishers, fire hoses, and air packs): System ventilation filters are replaced in accordance with plant procedures based on vendor manufacturers' requirements and system testing. Fire extinguishers, self-contained breathing air packs and fire hoses are within the scope of license renewal, but are not subject to aging management because they are replaced based on condition.
These components are periodically inspected in accordance with NFPA 10 for portable fire extinguishers, 29 CFR 1910.134 for self-contained breathing air packs, and NFPA 1962 for fire hoses (with exceptions to NFPA standards as identified in the LSCS FPR). These require replacement of equipment based on their condition or performance during LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.1-34 Section 2 -Scoping and Screening Methodology and Results testing and inspection.
The periodic inspections are implemented by controlled LSCS procedures.
These components are subject to replacement based on requirements implemented by controlled procedures, and are therefore not long-lived and not subject to an aging management review.2.1.7 GENERIC SAFETY ISSUES In accordance with the guidance in NEI 95-10 and Appendix A.3 of NUREG-1800, "Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants," review of NRC generic safety issues (GSIs) as part of the license renewal process is required to satisfy 10 CFR 54.29. This guidance suggests that GSIs involving issues related to license renewal aging management reviews or TLAAs should be addressed in the license renewal application.
Based on Nuclear Energy Institute (NEI) and NRC guidance, NUREG-0933 "Resolution of Generic Safety Issues," Supplement 34 (reference 1.7.14) and previous license renewal applicants, the following GSIs are addressed for LSCS license renewal:* GSI 186, Potential Risk and Consequences of Heavy Load Drops in Nuclear Power Plants -This GSI addresses heavy load issues related to crane design and operation.
Aging effects are not central to these issues. The issue does not involve time-limited aging evaluations, including typical crane-related TLAAs such as cyclic loading analyses." GSI 190, Fatigue Evaluation of Metal Components for 60-year Plant Life -This GSI addresses fatigue life of metal components and was closed by the NRC. In the closure letter, however, the NRC concluded that licensees should address the effects of reactor coolant environment on component fatigue life as aging management programs are formulated in support of license renewal. Accordingly, the issue of environmental effects on component fatigue life is addressed in Section 4.3.* GSI-1 93, BWR ECCS Suction Concerns -This GSI addresses the possible failure of low pressure emergency core cooling systems due to unanticipated, large quantities of entrained gas in the suction piping from the pressure suppression chamber (torus) in BWR Mark I containments.
This issue is not applicable to LSCS which is Mark II containment.
NUREG-0933 was reviewed and there are no new generic issues that involve issues related to license renewal aging management reviews or TLAAs.2.
 
==1.8 CONCLUSION==
 
The scoping and screening methodology described above was used for the LSCS IPA to identify the systems, structures, and components that are within the scope of license renewal and that are subject to an aging management review.The methodology is consistent with and satisfies the requirements of 10 CFR 54.4 and 10 CFR 54.21(a)(1).
LaSalle County Station, Units 1 and 2 Page 2.1-35 License Renewal Application This Page Intentionally Left Blank Section 2 -Scoping and Screening Methodology and Results 2.2 PLANT LEVEL SCOPING RESULTS Table 2.2-1 lists the LaSalle County Station systems, structures and commodity groups that were evaluated to determine if they were within the scope of license renewal, using the methodology described in Section 2.1. A reference to the section of the application that contains the scoping and screening results is provided for each in scope system, structure and commodity group in the Table.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.2-1 Section 2 -Scoping and Screening Methodology and Results Table 2.2-1 Plant Level Scoping Results In Scope for System, Structure or Commodity Group License Reference Renewal?Reactor Vessel, Internals, and Reactor Coolant System Reactor Coolant Pressure Boundary System Yes 2.3.1.1 Reactor Vessel Yes 2.3.1.2 Reactor Vessel Internals Yes 2.3.1.3 Engineered Safety Features High Pressure Core Spray System Yes 2.3.2.1 Low Pressure Core Spray System Yes 2.3.2.2 Reactor Core Isolation Cooling System Yes 2.3.2.3 Residual Heat Removal System Yes 2.3.2.4 Standby Gas Treatment System Yes 2.3.2.5 Auxiliary Systems ,AuxiiarySý*
te*ISytm No, ,, UF Closed Cycle Cooling Water System Yes 2.3.3.1 Combustible Gas Control System Yes 2.3.3.2 Compressed Air System Yes 2.3.3.3 Control Rod Drive System Yes 2.3.3.4 Control Room Ventilation System Yes 2.3.3.5 Cranes, Hoists, and Refueling Equipment System Yes 2.3.3.6 Demineralized Water Makeup System Yes 2.3.3.7 Diesel Generator and Auxiliaries System Yes 2.3.3.8 Drywell Pneumatic System Yes 2.3.3.9 Electrical Penetration Pressurization System Yes 2.3.3.10 LaSalle County Station, Units 1 and 2 Page 2.2-2 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.2-2 Section 2 -Scoping and Screening Methodology and Results Table 2.2-1 Plant Level Scoping Results In Scope for System, Structure or Commodity Group License Reference Renewal?Essential Cooling Water System Yes 2.3.3.11 Fire Protection System Yes 2.3.3.12 Fuel Pool Cooling and Storage System Yes 2.3.3.13 Nonessential Cooling Water System Yes 2.3.3.14 Nonsafety-Related Ventilation System Yes 2.3.3.15 Plant Drainage System Yes 2.3.3.16 Primary Containment Ventilation System Yes 2.3.3.17 Process Radiation Monitoring System Yes 2.3.3.18 Process Sampling and Post Accident Monitoring System Yes 2.3.3.19 Radwaste System Yes 2.3.3.20 Reactor Water Cleanup System Yes 2.3.3.21 Safety-Related Ventilation System Yes 2.3.3.22 Standby Liquid Control System Yes 2.3.3.23 Suppression Pool Cleanup System Yes 2.3.3.24 Traversing Incore Probe System Yes 2.3.3.25 Steam and Power Conversion System Condensate System Condenser and Air Removal System tracionSteaSystem
.Feedwater System..
...,. ... 3 ,,. ;; ...... .....: ~ !% :............=7:I' Main Sratorland ASuxlary Systemj:tem Main Steam System 2.3.4.1 2.3.4.2 ,UJFSAR 10.4.8 2.3.4.3 3UFSAR10 10,2 2.3.4.4 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.2-3 Section 2 -Scoping and Screening Methodology and Results Table 2.2-1 Plant Level Scoping Results In Scope for System, Structure or Commodity Group License Reference Renewal?Main Turbine and Auxiliaries System _Yes 2.3.4.5 Structures and Component Supports Auxiliary Building Yes 2.4.1 Component Supports Commodity Group Yes 2.4.2 Cooling Lake Yes 2.4.3 Diesel Generator Building Yes 2.4.4 Lake Screen House Yes 2.4.5 see aneus ot n epeStrutures N Offgas Building Yes 2.4.6 Primary Containment Yes 2.4.7 Radwaste Building Yes 2.4.8 Reactor Building Yes 2.4.9 Service Building.
No Comment.2 Structural Commodity Group Yes 2.4.10 Switchyard Structures Yes 2.4.11 Tank Foundation and Dikes Yes 2.4.12 Turbine Building Yes 2.4.13 Yard Structures Yes 2.4.14 Electrical Components Area Radiation Monitoring System Yes UFSAR 7.7.9 Automatic Depressurization System Yes UFSAR 7.3.1.2.2 Auxiliary Power System Yes UFSAR 8.3.1 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.2-4 Section 2 -Scoping and Screening Methodology and Results Table 2.2-1 Plant Level Scoping Results In Scope for System, Structure or Commodity Group License Reference Renewal?C~athodiic Prot~etonrSystern.
No IPS-AR Table 3.21 Communication System Yes UFSAR 9.5.2 DC Power System Yes UFSAR 8.3.2 Electrical Commodities Yes 2.5.2.5 Heat Trace System Yes UFSAR 7.5.2.2, 7.4.2 Leak Detection System Yes UFSAR 7.6.2.2, 7.7.15 MIt s~eilarneous Instr~umentationSystemn
-, No :l :2o3.3, 3.7.4,77,7.8 Neutron Monitoring System Yes UFSAR 7.6.3, 7.7.6 Offsite Power System Yes UFSAR 8.2 Plant Computer System Yes UFSAR 7.7.7 Plant Lighting System Yes UFSAR 9.5.3.Plant'Sectfrit Syte .No-- I1J~S~i Primary Containment Isolation System Yes UFSAR 7.3.2 Reactivity Control System Yes UFSAR 7.6.5, 7.7.2 Reactor Protection System Yes UFSAR 7.2 Reactor Vessel Instrumentation, Controls and Display Yes UFSAR 7.5, 7.7.1, 7.7.4 System Remote Shutdown System Yes UFSAR 7.4.4 Comments: 1. The Miscellaneous Not In Scope Structures are nonsafety-related and provide support, shelter, and protection for personnel, stored materials, or nonsafety-related systems, structures, and components (SSC's) that do not perform an intended function for license renewal. These nonsafety-related structures are also separated from safety-related systems, structures, and components such that the structures' failure would not impact a safety-related function.
Therefore, the following structures are not within the scope of LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.2-5 Section 2 -Scoping and Screening Methodology and Results license renewal: Administration Building (also known as the South Service Building or New Service Building), Building #30 (Records Storage Vault or Records Storage Building), IDNS (Illinois Department of Nuclear Safety) Building, Project Management Field Office, Training Building, Maintenance Shop, Building #1 (contractor fab shop, radiological outage, equip storage), Road Maintenance Building, Weld Shop, Warehouse (Stores Warehouse), Warehouses 3 -6, Contractor PreFab Shop, Shad Net Maintenance Building, In-Processing Facility, MAF (Main Access Facility), Security Checkpoint, Building #11 (TSC and Security Diesels), NAF (Old Permanent Gatehouse or Gatehouse), Sewage Treatment Plant, Water Softener Building (Building
#41), MUDS (Makeup Demineralizer System)Trailers, Pump Houses: (Building
#40), River Screen House, Lake Blowdown Outfall Structure, Transporter Building, Hazardous/Mixed Waste Storage Facility (Building
#20), Radwaste Storage, Building #33, Filling Station, Station Heat Chiller Pad, and Fish Hatchery.2. The Service Building is a nonsafety-related multi-story steel framed and reinforced concrete structure enclosed with metal siding above grade. The purpose of the Service Building is to provide structural support, shelter, and protection for machine and electric shops, storage, and administrative and maintenance personnel office areas. The Service Building reinforced concrete substructure is supported by a reinforced concrete mat foundation on soil. The service building roof is galvanized metal decking and built-up roofing. The Service Building is located adjacent to and northwest of the nonsafety-related Turbine Building.
The Service Building is classified nonsafety-related and is separated from safety-related structures such that its failure would not impact a safety-related function.
The external PMP flood elevation is below plant grade adjacent to the Service Building, and the Service Building is not relied upon to resist exterior flooding below grade.Evaluation of the Service Building determined that it does not perform an intended function delineated in 10 CFR 54.4 (a) and is not in scope for license renewal.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.2-6 Section 2 -Scoping and Screening Methodology and Results 2.3 2.3.1 SCOPING AND SCREENING RESULTS: MECHANICAL REACTOR VESSEL, INTERNALS, AND REACTOR COOLANT SYSTEM The following systems are addressed in this section: " Reactor Coolant Pressure Boundary System (2.3.1.1)" Reactor Vessel (2.3.1.2)" Reactor Vessel Internals (2.3.1.3)LaSalle County Station, Units I and 2 License Renewal Application 2.3-1 Section 2 -Scoping and Screening Methodology and Results 2.3.1.1 Reactor Coolant Pressure Boundary System 0 Description The Reactor Coolant Pressure Boundary System (RCPB) is a normally operating system designed to provide the source of forced circulation of reactor coolant through the reactor core to remove the heat generated by fission. The RCPB also provides a flowpath to the reactor vessel for feedwater, high pressure core spray (HPCS), low pressure core spray (LPCS), standby liquid control (SLC), shutdown cooling, low pressure coolant injection, and reactor core isolation cooling (RCIC). The RCPB also includes piping within the flowpath for steam from the reactor to the main turbine, RCIC turbine, supply and return reactor coolant for the shutdown cooling and reactor water cleanup system (RWCU) functions, and provides pressure relief for the reactor vessel and reactor coolant pressure boundary piping and components.
The RCPB includes all pressure containing components which are part of the plant reactor recirculation system or are connected to the reactor recirculation system, up to and including the outermost containment isolation valve in system piping which penetrates primary reactor containment, and the reactor coolant system safety relief valves.The RCPB includes the ASME Section Xl Class 1 portions of the following plant systems: reactor recirculation, HPCS, LPCS, SLC, residual heat removal (shutdown cooling and low pressure coolant injection), RCIC, RWCU, feedwater, main steam, and nuclear boiler instrumentation.
The RCPB also includes the ASME Section Xl Class 2 portions of the nuclear boiler instrumentation system from the ASME Class 1 interface to pressure-retaining instruments, the control rod drive (CRD) system seal purge supply to the reactor recirculation pumps and makeup to the reactor level indication condensing chambers, and the reactor recirculation system sample piping.The RCPB also includes subsystems that support the reactor recirculation system including the electro-hydraulic control (EHC) system associated with the reactor recirculation pump discharge flow control valves, the piping and instrumentation that supports the pump motor winding and bearing coolers, and oil reservoirs.
For more detailed information see UFSAR Chapter 5.0 and Appendix G.Boundary The RCPB license renewal scoping boundary begins at the piping attached to the reactor pressure vessel (RPV) nozzle safe end to piping welds. The RPV nozzles, safe-ends, and welds are included with the license renewal Reactor Vessel system. The RCPB boundary includes the piping connected to the 10 recirculation inlet nozzles, two recirculation outlet nozzles, four main steam nozzles, six feedwater nozzles, three low pressure coolant injection nozzles, 10 instrumentation nozzles, two jet pump instrument nozzles, one high pressure core spray nozzle, one low pressure core spray nozzle, one standby liquid control nozzle, one bottom head drain nozzle, one reactor head vent nozzle, one reactor head spray (RCIC)nozzle, and the reactor vessel head seal leak detection nozzle. The RCPB includes the main reactor recirculation flowpath, which begins at the pump suction piping attached to the reactor vessel nozzles, continues through the suction piping, suction valves, recirculation pump casings, discharge valves and discharge piping back to the RPV nozzles. Also included is the LaSalle County Station, Units 1 and 2 2.3-2 License Renewal Application Section 2 -Scoping and Screening Methodology and Results process sample line from the "B" recirculation pump discharge header to the sample cooler inlet valve, and the purge supply to the reactor recirculation pump seals from the CRD System from the outboard containment isolation check valves to the pump seals. Also included is the hydraulic control oil system and piping components from the hydraulic control power units in the Reactor Building to the hydraulic actuators on the recirculation pump discharge flow control valves. Also included are piping and instrumentation associated with lubrication and cooling of the recirculation pumps and motors. The scoping boundary to the Closed Cooling Water System is at the flanges that connect the plant reactor building closed cooling water system supply and return piping to the pumps and motors.The RCPB boundary continues at the 20-inch branch connection off the reactor recirculation pump "A" suction line to the outermost Residual Heat Removal System (RHR) shutdown cooling suction containment isolation valve. The boundary includes the 12-inch RHR shutdown cooling return piping from the outermost containment valves to the branch connections off the 24-inch recirculation pump "A" and "B" discharge piping. The RCPB also includes the 4-inch RWCU System branch connections off the 24-inch recirculation pump "A" and "B" suction piping and the 2-inch reactor vessel bottom head drain from the RPV nozzle, which combine to a single 6-inch pipe to the RWCU System, and extends to the outboard containment isolation valve.The RCPB includes the RHR piping that provides low pressure coolant injection and the LPCS and HPCS injection piping from the outboard containment isolation valves to the RPV nozzles.Also included is piping from the RPV and jet pump instrument nozzles through excess flow check valves outside of containment and to pressure-retaining instrumentation, and from the SLC RPV nozzle to the explosive injection valves that are outside primary containment.
The RCPB includes the main steam piping from the RPV nozzles, including the main steam line drains, to the outboard containment isolation valves. Also included is the inlet piping to the main steam relief valves and the main steam relief valve bodies. The main steam relief discharge piping is included with the license renewal Main Steam System. The RCPB includes the 10-inch branch connection off the "B" main steam line to the 4-inch RCIC System turbine steam supply piping up to the outboard containment isolation valve and the 10-inch blank flange connection to the RHR System. The RCPB also includes Feedwater System piping and components from the RPV nozzles to the outboard containment isolation check valves.The RCPB includes the RCIC System pump discharge piping from the 6-inch flanged nozzle on the RPV head to outboard containment isolation valves and extends to the branch connection to RHR System piping to the outboard containment isolation valve. The RCPB includes the vent piping from the flanged 4-inch nozzle on the RPV head to the 2-inch branch connection off of the "A" main steam line, ending at the second isolation valve to the gland seal leak-off reservoir, and a 1-inch connection to the high point on the RCIC pump discharge piping to the RPV head. The RCPB also includes the %-inch seal leak detection line from the RPV head flange ending at the normally closed valve to the gland seal leak-off reservoir.
All associated piping, components and instrumentation within the flowpaths described above are included in the license renewal RCPB System. Included is instrumentation piping and components attached to the RCPB piping sections from the branch connections off the piping to pressure-retaining instrumentation.
Instrumentation downstream of the excess flow check valves is included as shown on License Renewal Boundary Drawings.LaSalle County Station, Units 1 and 2 2.3-3 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Also included in the RCPB System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located in the Reactor Building and Primary Containment.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the scope of license renewal are RCPB System components located inside the EHC system reservoirs associated with the reactor recirculation pump discharge flow control valves, as these components do not have the potential for spatial interaction with safety-related equipment.
Reason for Scope Determination The Reactor Coolant Pressure Boundary System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Reactor Coolant Pressure Boundary System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Reactor Coolant Pressure Boundary System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provide reactor coolant pressure boundary.
The Reactor Coolant Pressure Boundary System forms a barrier to minimize the release of reactor coolant and radioactive material to the Reactor Buildings.
The Reactor Coolant Pressure Boundary System, in conjunction with the Reactor Protection System, provides overpressure protection for the reactor coolant pressure boundary.
10 CFR 54.4(a)(1)
: 2. Provide primary containment boundary.
The Reactor Coolant Pressure Boundary System includes containment isolation valves. 10 CFR 54.4(a)(1)
: 3. Sense process conditions and generate signals for reactor trip or engineered safety features actuations.
The Reactor Coolant Pressure Boundary System includes instrumentation and process controls that provide input signals to the Primary Containment Isolation System, Reactor Protection System, and ECCS systems. 10 CFR 54.4(a)(1)
: 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Reactor Coolant Pressure Boundary System includes nonsafety-related fluid filled lines within the Reactor Building and Primary Containment which have the potential for spatial interaction with safety-related SSCs. 10 CFR 54.4(a)(2)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Reactor Coolant Pressure Boundary System provides the flow path for reactor coolant make-LaSalle County Station, Units 1 and 2 2.3-4 License Renewal Application Section 2 -Scoping and Screening Methodology and Results up and decay heat removal, and maintains the reactor coolant pressure boundary in support of reactor safe shutdown.
10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The Reactor Coolant Pressure Boundary System includes safety-related components located within areas of the plant that may have harsh environments, and therefore have environmental qualifications.
10 CFR 54.4(a)(3)
: 7. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62). Reactor Coolant Pressure Boundary System components receive the recirculation pump trip signal from the Reactor Protection System and provides the flow path and maintains the pressure boundary for standby liquid control injection.
10 CFR 54.4(a)(3)
: 8. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The Reactor Coolant Pressure Boundary System provides the flow path for reactor coolant make-up and decay heat removal, and maintains the reactor coolant pressure boundary in support of reactor safe shutdown.
10 CFR 54.4(a)(3)
UFSAR References 1.2.2.3.3 Table 3.2-1 5.0 7.7.3 Appendix G License Renewal Boundary Drawinqgs LR-LAS-M-93, Sheets 1, 2, 3, 4, 5, 6, 7, 8 LR-LAS-M-2095, Sheet 1 LR-LAS-M-2097, Sheet 1 LR-LAS-M-2100, Sheet 2 LR-LAS-M-55, Sheets 1, 2, 7 LR-LAS-M-57, Sheet 1 LR-LAS-M-90, Sheet 2 LR-LAS-M-91, Sheet 4 LR-LAS-M-94, Sheet 1 LR-LAS-M-95, Sheet 1 LR-LAS-M-96, Sheets 1, 2, 3 LR-LAS-M-97, Sheet 1 LR-LAS-M-99, Sheet 1 LR-LAS-M-100, Sheet 5 LR-LAS-M-101, Sheets 1, 2 LR-LAS-M-115, Sheets 1, 12 LR-LAS-M-139, Sheets 1,2, 3, 4, 5, 8, 9 LR-LAS-M-2146, Sheet 2 LR-LAS-M-2141, Sheet 1 LR-LAS-M-2143, Sheet 1 LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-5 Section 2 -Scoping and Screening Methodology and Results LR-LAS-M-116, Sheets 1, 2, 7 LR-LAS-M-118, Sheet 1 LR-LAS-M-1 36, Sheet 2 LR-LAS-M-1 37, Sheet 4 LR-LAS-M-140, Sheet 1 LR-LAS-M-141, Sheet 1 LR-LAS-M-142, Sheets 1, 2, 3 LR-LAS-M-143, Sheet 1 LR-LAS-M-145, Sheet 1 LR-LAS-M-146, Sheet 6 LR-LAS-M-147, Sheets 1, 2 LR-LAS-M-159, Sheet 1 Table 2.3.1-1 Reactor Coolant Pressure Boundary System Components Subject to Aging Management Review Component Type Intended Function Accumulator Leakage Boundary Bolting Mechanical Closure Class 1 Piping, Fittings and Branch Pressure Boundary Connections
< NPS 4" Flow Device (Instrumentation Orifices)
Pressure Boundary Throttle Flow Device (Main Steam Line Flow Throttle Restrictors)
Heat Exchanger
-(EHC Fluid) Tube Side Leakage Boundary Components Heat Exchanger
-(Motor Oil Coolers) Leakage Boundary Shell Side Components Heat Exchanger
-(Motor Winding Leakage Boundary Coolers) Tube Side Components Heat Exchanger
-(Motor Winding Leakage Boundary Coolers) Tubes Hoses Leakage Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (EHC Skid) Leakage Boundary Pump Casing (RRP) Pressure Boundary RPV Flange Leak Detection Line Pressure Boundary Tanks (EHC Reservoir)
Leakage Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.1.2-1 Reactor Coolant Pressure Boundary System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-6 Section 2 -Scoping and Screening Methodology and Results 2.3.1.2 Reactor Vessel Description The Reactor Vessel system is a normally operating system designed to contain pressure and heat in the core and transfer this heat to the reactor coolant. The Reactor Vessel consists of the cylindrical vessel shell, lower vessel head, vessel support skirt, closure head, nozzles and safe ends, and closure studs and nuts.The Reactor Vessel is in scope for license renewal and consists of the following plant system: nuclear boiler. The Reactor Vessel has interfaces with several other license renewal systems and components that are not within the license renewal boundary of the Reactor Vessel but are evaluated separately.
These include the Control Rod Drive System, Neutron Monitoring System, Primary Containment, Reactor Coolant Pressure Boundary System, Reactor Vessel Internals, and Component Supports Commodity Group.The purpose of the Reactor Vessel is to maintain the reactor vessel pressure boundary, provide structural support for the reactor vessel internals and core and, along with the Reactor Vessel Internals, provide a floodable volume. The Reactor Vessel provides a boundary to separate fission products from the environment.
The system is required for plant start-up, normal plant operations and normal shutdown.For more detailed information see UFSAR Section 5.3.Boundary The components within the Reactor Vessel license renewal scoping boundary are those that comprise the reactor vessel, including nozzles (with integral safe ends and thermal sleeves), closure studs and nuts, and the vessel support skirt. The vessel top head includes one head vent nozzle, one head spray / reactor core isolation cooling nozzle, one spare nozzle and four lifting lugs. The cylindrical portion of the vessel includes one flange seal leak detection line nozzle, four steam outlet nozzles, six feedwater inlet nozzles, one high pressure core spray nozzle, one low pressure core spray nozzle, one control rod drive hydraulic system return nozzle, 10 water level instrumentation nozzles, three residual heat removal / low pressure coolant injection nozzles, 10 recirculation inlet nozzles, two recirculation outlet nozzles, and two jet pump instrument nozzles. The bottom head includes one core differential pressure /standby liquid control nozzle, one drain nozzle, 185 control rod drive penetrations, and 55 in-core flux monitor penetrations.
The piping and components attached to these nozzles are included within other license renewal systems, as described below. The boundary between the Reactor Vessel and the Reactor Coolant Pressure Boundary System is at the weld between each reactor vessel nozzle safe-end and the attached piping and components.
The boundary between the Reactor Vessel and the Control Rod Drive (CRD) System is at the flange attached to the CRD housing. The boundary between the Reactor Vessel and the Neutron Monitoring System is at the flange attached to the in-core monitor housing. The boundary between the Reactor Vessel and the Reactor Vessel Internals is at the CRD housing-to-guide tube weld and at the in-core monitor housing-to-guide tube weld.There are multiple attachments to the reactor vessel for supporting various internal components.
These internal attachments include guide rod brackets, steam dryer support LaSalle County Station, Units 1 and 2 2.3-7 License Renewal Application Section 2 -Scoping and Screening Methodology and Results brackets, dryer hold-down brackets, feedwater sparger brackets, jet pump riser support pads, core spray brackets, and surveillance specimen holder brackets.
The boundary between the Reactor Vessel and the Reactor Vessel Internals is between the brackets and the attached components.
The brackets are included within the Reactor Vessel scoping boundary and the attached components are included within the Reactor Vessel Internals scoping boundary.There are also external attachments to the reactor vessel within the scope of the Reactor Vessel. The Unit 1 reactor vessel skirt is connected to a ring girder adapter via 60 bolts, all within the Reactor Vessel scoping boundary.
The ring girder adapter is connected to the reactor vessel support pedestal via 120 anchor bolts, which are within the Component Supports Commodity Group. The Unit 2 reactor vessel skirt is connected directly to the reactor vessel support pedestal via 120 anchor bolts which are also within the Component Supports Commodity Group. The reactor vessel support skirt, ring girder adaptor and bolts, stabilizer bracket lugs and refueling bellows support bracket are within the Reactor Vessel scoping boundary.
The refueling bellows and stabilizer bracket assembly are within the Primary Containment.
The reactor vessel top head lifting lugs are within the scope of the Reactor Vessel.Reason for Scope Determination The Reactor Vessel meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Reactor Vessel is not in scope under 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system would not prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Reactor Vessel also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63). The Reactor Vessel is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).Intended Functions 1. Provide reactor coolant pressure boundary.
The Reactor Vessel forms a barrier against the release of reactor coolant and radioactive material to the Reactor Building.
10 CFR 54.4(a)(1)
: 2. Maintain reactor core assembly geometry.
The Reactor Vessel provides support to the Reactor Vessel Internals.
The Reactor Vessel, along with the Reactor Vessel Internals, maintains a floodable volume within the reactor. 10 CFR 54.4(a)(1)
: 3. Provides structural support or restraint to SSCs in the scope of license renewal. The reactor pressure vessel support skirt and stabilizer brackets provide structural support for the reactor vessel. The refueling bellows bracket provides support for the refueling bellows. 10 CFR 54.4(a)(1)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Reactor Vessel provides the flow path and maintains the pressure boundary for reactor safe shutdown.
10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 2.3-8 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62). The Reactor Vessel provides the flow path and maintains the pressure boundary for standby liquid control injection.
10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The Reactor Vessel provides the flow path and maintains the pressure boundary for reactor safe shutdown.
10 CFR 54.4(a)(3)
UFSAR References 3.9.5 5.1 5.3 License Renewal Boundary Drawings None.LaSalle County Station, Units 1 and 2 2.3-9 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.1-2 Reactor Vessel Components Subject to Aging Management Review Component Type Intended Function Bolting (Closure Studs -RPV) Mechanical Closure Bolting (Head Spray, CRD Housing, Head Mechanical Closure Vent, Spare Nozzle)N-1 Nozzle (Recirculation Outlet) Pressure Boundary N-1 Nozzle Safe Ends and Welds Pressure Boundary N-2 Nozzle (Recirculation Inlet) Pressure Boundary N-2 Nozzle Safe Ends and Welds Pressure Boundary N-2 Nozzle Thermal Sleeve Direct Flow N-3 Nozzle (Steam Outlet) Pressure Boundary N-3 Nozzle Safe Ends and Welds Pressure Boundary N-4 Nozzle (Feedwater)
Pressure Boundary N-4 Nozzle Safe Ends and Welds Pressure Boundary N-4 Nozzle Thermal Sleeve Direct Flow N-5 Nozzle (Low Pressure Core Spray) Pressure Boundary N-5 Nozzle Safe End Extension Pressure Boundary N-5 Nozzle Safe Ends and Welds Pressure Boundary N-5 Nozzle Thermal Sleeve Direct Flow N-5 Thermal Sleeve Extension Direct Flow N-6 Nozzle (RHR / LPCI) Pressure Boundary N-6 Nozzle Safe End Extensions Pressure Boundary N-6 Nozzle Safe Ends and Welds Pressure Boundary N-6 Nozzle Thermal Sleeve Extension Pressure Boundary (Unit 2 Only)N-6 Thermal Sleeve Direct Flow N-7 Nozzle (Top Head Spray / RCIC -Pressure Boundary Flanged)N-7 Nozzle Flange Pressure Boundary N-7 Nozzle Welds Pressure Boundary N-8 Nozzle (Top Head Vent -Flanged) Pressure Boundary N-8 Nozzle Flange Pressure Boundary N-8 Nozzle Welds Pressure Boundary N-9 Nozzle (Jet Pump Instrumentation)
Pressure Boundary N-9 Nozzle Safe End and Welds Pressure Boundary N10 Nozzle (CRD Hydraulic System Pressure Boundary Return Line -Capped)N10 Nozzle Cap and Welds Pressure Boundary N 11 Nozzle (Core Differential Pressure Pressure Boundary and Liquid Control)N1i1 Nozzle Welds Pressure Boundary N12 Nozzle (Water Level Instrumentation Pressure Boundary-366" Elevation)
N12 Nozzle Extension and Welds Pressure Boundary N13 Nozzle (Water Level Instrumentation Pressure Boundary-517" Elevation)
N13 Nozzle Extension Pressure Boundary LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-10 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function N13 Nozzle Welds Pressure Boundary N14 Nozzle (Water Level Instrumentation Pressure Boundary-599" Elevation)
N14 Nozzle Extension Pressure Boundary N14 Nozzle Extension Welds Pressure Boundary N15 Nozzle (Bottom Head Drain) Pressure Boundary N16 Nozzle (High Pressure Core Spray) Pressure Boundary N16 Nozzle Safe End Extensions Pressure Boundary N16 Nozzle Safe Ends and Welds Pressure Boundary N16 Thermal Sleeve Direct Flow N16 Thermal Sleeve Extension (Unit 2 Direct Flow Only)N17 Nozzle (Seal Leak Detection)
Pressure Boundary N18 (Top Head Spare -Flanged) Pressure Boundary N18 Nozzle Flange Pressure Boundary N19 CRD Nozzle (Housing and Flange) Pressure Boundary N19 CRD Nozzle (Welds) Pressure Boundary N19 CRD Nozzles (Stub Tubes) Pressure Boundary N20 Incore Monitor Nozzles (Housing and Pressure Boundary Flange)Reactor Vessel (Bottom Head and Welds) Pressure Boundary Reactor Vessel (Shell, Lower Flange, and Pressure Boundary Welds)Reactor Vessel (Top Head, Upper Pressure Boundary Flange, and Welds)Reactor Vessel External Attachments Pressure Boundary (Refueling Bellows Support) Structural Support Reactor Vessel External Attachments Structural Support (Support Skirt and Stabilizer Bracket)Reactor Vessel Internal Attachments Structural Support to maintain core I_ configuration and flow distribution The aging management review results for these components are provided in: Table 3.1.2-2 Reactor Vessel Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-11 Section 2 -Scoping and Screening Methodology and Results 2.3.1.3 Reactor Vessel Internals Description The Reactor Vessel Internals is a normally operating system within the Reactor Vessel that is designed to control the generation of heat in the reactor core, to transfer this heat to the reactor coolant, and to supply dry steam to the Main Steam System. The Reactor Vessel Internals include fuel assemblies that generate the heat in the core, control rods and control rod drive (CRD) assemblies that control reactivity in the core, and neutron flux detector assemblies that monitor core reactivity.
The Reactor Vessel Internals also includes the core shroud, shroud support and access hole covers, shroud head and steam separator, core plate and holddown bolts, top guide, fuel supports, core spray piping and spargers, low pressure coolant injection (LPCI) couplings, jet pump assemblies, feedwater spargers, control rod guide tubes, incore instrumentation guide tubes and dry tubes, core plate differential pressure and standby liquid control injection line, jet pump differential pressure sensing lines, surveillance sample holders, and the steam dryer assembly.The purpose of the Reactor Vessel Internals is to maintain reactor core assembly geometry, to achieve and maintain the reactor core subcritical for any mode of normal operation or event, to control reactivity in the nuclear reactor core, and to maintain core thermal and hydraulic limits.The purpose of the fuel assemblies is to allow efficient heat transfer from the nuclear fuel to the reactor coolant, to maintain structural integrity, and to provide a fission product barrier.The purpose of the control rods and CRD assemblies is to absorb neutrons in the reactor core to control reactivity.
The core shroud, shroud support, core plate, top guide, fuel supports, and control rod guide tubes provide structural support for the reactor core, control rod assemblies, and the incore instrumentation.
The configuration of the core shroud, core plate, and jet pump assemblies directs coolant flow through the core and maintains a floodable volume of coolant around the fuel. The core spray piping and spargers and LPCI couplings supply and distribute coolant within the shroud during accident conditions.
The core plate differential pressure and standby liquid control injection line provides a flowpath for injecting a neutron absorber into the reactor core when the normal method of controlling core reactivity with control rods is unavailable.
The steam dryer assembly removes moisture from the wet steam leaving the steam separators.
The Reactor Vessel Internals system is required for plant start-up, normal plant operations, normal shutdown, transient, and accident conditions.
For more detailed information see UFSAR Sections 3.9.5 and 4.1.2.Boundary The Reactor Vessel Internals license renewal scoping boundary includes components that are inside the Reactor Vessel. The following Reactor Vessel Internals components perform a safety-related function and are therefore within the scope of license renewal: the core shroud, shroud support and access hole covers, core spray piping and spargers, LPCI couplings, core plate and core plate bolts, fuel supports, top guide, jet pump assemblies, core plate differential pressure and standby liquid control injection line, control rod guide tubes, and incore instrumentation guide tubes and dry tubes. Also within the scope of license renewal is all repair hardware installed on reactor internal components.
The steam dryer does not perform a safety-related function; however, it is included in the license renewal scope because failure of steam dryer components could result in loose parts that could potentially prevent satisfactory accomplishment of safety-related functions.
LaSalle County Station, Units 1 and 2 2.3-12 License Renewal Application Section 2 -Scoping and Screening Methodology and Results The fuel assemblies, control rods, and neutron flux detection assemblies are in scope for license renewal; however they are short-lived components and are therefore not subject to aging management review. The CRD assemblies are also in scope; however they are active assemblies and are therefore not subject to aging management review. The following Reactor Vessel Internals components are not safety-related and are not required to support intended functions; therefore they are not included within the scope of license renewal: The feedwater spargers, the shroud head and steam separator assembly including the guide rods and guide pins, incore guide tube stabilizers, jet pump differential pressure sensing lines, and the surveillance sample holders. A safety assessment for these components is documented in BWRVIP-06 Revision 1-A. The evaluation concluded that these components do not perform a safety-related function.
This report also concluded that failure of these components does not result in consequential failure of safety-related components.
The reactor vessel nozzles and penetrations, including associated housings and stub tubes for the CRD assemblies, incore instrumentation, and core plate differential pressure and standby liquid control injection line penetrations are evaluated with the license renewal Reactor Vessel system.Reason for Scope Determination The Reactor Vessel Internals meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Reactor Vessel Internals meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Reactor Vessel Internals also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63). The Reactor Vessel Internals is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).Intended Functions 1. Maintain reactor core assembly geometry.
The reactor internal components, in conjunction with the reactor pressure vessel, are designed to provide physical support to maintain fuel configuration and clearances to ensure core reactivity control and core cooling capability during normal and accident conditions.
10 CFR 54.4(a)(1)
: 2. Introduce negative reactivity to achieve and maintain subcritical reactor condition.
The control rods and CRD assemblies adjust the concentration of the neutron absorber in the core during normal operations and shutdown conditions.
10 CFR 54.4(a)(1)
: 3. Introduce emergency negative reactivity to make the reactor subcritical.
When a Reactor Protection System scram signal is received, high pressure water is applied to the CRD assemblies to rapidly insert each control rod into the core. The core plate differential pressure and standby liquid control line provides a flowpath for injecting a neutron absorber into the reactor core when control rods are unavailable.
10 CFR 54.4(a)(1)
: 4. Sense process conditions and generate signals for reactor trip or engineered safety features actuation.
Neutron flux detectors within the reactor core initiate a Reactor Protection LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-13 Section 2 -Scoping and Screening Methodology and Results System scram signal to shutdown the reactor upon a high flux condition.
10 CFR 54.4(a)(1)
: 5. Provide emergency core cooling where the equipment provides coolant directly to the core.The low pressure coolant injection couplings and core spray piping and spargers distribute emergency core cooling flow within the shroud to the reactor core. 10 CFR 54.4(a)(1)
: 6. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The nonsafety-related steam dryer could interact with safety-related components.
10 CFR 54.4(a)(2)
: 7. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transients Without Scram (10 CFR 50.62). The Standby Liquid Control System injects through the core plate differential pressure and standby liquid control line. 10 CFR 54.4(a)(3)
: 8. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The Reactor Vessel Internals system includes CRD assemblies and control rod blades that are required to achieve and maintain safe shutdown of the reactor. 10 CFR 54.4(a)(3)
: 9. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Reactor Vessel Internals system includes CRD assemblies and control rod blades that are required to achieve and maintain safe shutdown of the reactor. 10 CFR 54.4(a)(3)
UFSAR References 1.2.2.3.2 Table 3.2-1 3.9.5 4.1.2 5.2.2 License Renewal Boundary Drawings None.LaSalle County Station, Units 1 and 2 2.3-14 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.1-3 Reactor Vessel Internals Components Subject to Aging Management Review Component Type Intended Function Core Shroud (Including Repairs) and Structural Support to maintain core Core Plate: Core Shroud (Upper, Central, configuration and flow distribution Lower)Core Shroud (Including Repairs) and Structural Support to maintain core Core Plate: Shroud Support Structure configuration and flow distribution (Shroud Support Cylinder, Shroud Support Plate, Shroud Support Legs and Gussets)Core Shroud and Core Plate: Access Direct Flow Hole Cover (Welded Covers)Core Shroud and Core Plate: Core Plate, Structural Support to maintain core Core Plate Bolts configuration and flow distribution Core Shroud and Core Plate: LPCI Direct Flow Coupling Core Spray Lines and Spargers:
Core Direct Flow Spray Lines (Headers), Spray Rings, Spray Nozzles Fuel Supports and Control Rod Drive Structural Support to maintain core Assemblies:
Orificed Fuel Support configuration and flow distribution Throttle Instrumentation:
Intermediate Range Structural Support to maintain core Monitor (IRM) Dry Tubes, Source Range configuration and flow distribution Monitor (SRM) Dry Tubes, Incore Neutron Flux Monitor Guide Tubes Jet Pump Assemblies:
Castings Direct Flow Jet Pump Assemblies:
Inlet Riser and Direct Flow Brace, Holddown Beam, Diffuser, Tailpipe, Wedges, and Repair Components Reactor Vessel Internals Components:
Structural Support to maintain core Control Rod Drive Guide Tube configuration and flow distribution Reactor Vessel Internals Components:
Direct Flow Core Plate DP/SLC Line Steam Dryers Structural Integrity Top Guide Structural Support to maintain core configuration and flow distribution The aging management review results for these components are provided in: Table 3.1.2-3 Reactor Vessel Internals Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-15 Section 2 -Scoping and Screening Methodology and Results 2.3.2 ENGINEERED SAFETY FEATURES SYSTEMS The following systems are addressed in this section:* High Pressure Core Spray System (2.3.2.1)* Low Pressure Core Spray System (2.3.2.2)* Reactor Core Isolation Cooling System (2.3.2.3)" Residual Heat Removal System (2.3.2.4)* Standby Gas Treatment System (2.3.2.5)LaSalle County Station, Units 1 and 2 2.3-16 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 2.3.2.1 High Pressure Core Spray System Description The High Pressure Core Spray (HPCS) System is a standby high pressure emergency core cooling system (ECCS) designed to prevent excessive fuel cladding temperatures following any break in the nuclear system piping. The HPCS System accomplishes this by delivering water into the reactor pressure vessel (RPV) over a wide range of pressures.
The HPCS system provides and maintains an adequate coolant inventory inside the reactor vessel to maintain fuel cladding temperatures below fragmentation temperature in the event of breaks in the reactor coolant pressure boundary.
For small breaks that do not result in rapid reactor depressurization, the HPCS system spray maintains reactor water level and depressurizes the vessel. For large breaks, the HPCS system sprays the top surface of the core to cool the core until sufficient water accumulates in the vessel to reflood the core.The HPCS System consists of a single, motor-driven pump and associated piping, valves, controls and instrumentation.
The principal HPCS System equipment is located outside the primary containment.
Suction piping is provided from the suppression pool. The suppression pool water source assures a closed cooling water supply for extended operation of the HPCS System. After entering the vessel, HPCS flow divides and enters the shroud at two points near the top of the shroud. A semicircular sparger is attached to each outlet. Nozzles are spaced around the spargers to spray the water radially over the core and into the fuel assemblies.
The HPCS System injection piping is provided with an isolation valve on each side of the containment barrier. Remote controls for operating the valves and diesel generator are provided in the plant control room.HPCS System operation is initiated automatically by either a reactor low water level or primary containment (drywell) high pressure signal, or can be initiated manually.
The HPCS System is independent of electrical connections to any other system except the normal a-c power supply.The HPCS System is designed to operate from normal offsite auxiliary power sources or from a diesel generator if offsite power is not available.
For more detailed information, see UFSAR Sections 7.3.1.2.1 and 6.3.2.2.1.
Boundary The HPCS scoping boundary begins at the HPCS suction strainer in the suppression pool and continues through suction piping and a primary containment isolation valve, through the HPCS pump, and terminates at the upstream side of the HPCS discharge outboard primary containment isolation valve (evaluated with the Reactor Coolant Pressure Boundary System).The HPCS scoping boundary includes a minimum flow and a full flow test line which begins at the discharge of the HPCS pump and continues through primary containment isolation valves prior to terminating inside the suppression pool.The water leg fill portion of the HPCS begins at the suction of the HPCS pump and continues through the water leg pump suction piping, through the water leg pump, and terminates at the discharge piping of the HPCS pump.All associated piping, components and instrumentation contained within the boundary described above are also included in the HPCS scoping boundary.LaSalle County Station, Units 1 and 2 2.3-17 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Also included in the HPCS System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the HPCS System scoping boundary are the piping and components associated with the discharge portion of the system from the HPCS discharge outboard primary containment isolation valve to the reactor vessel. These components are evaluated with the Reactor Coolant Pressure Boundary license renewal system.Not included in the HPCS System scoping boundary is the circular sparger located above and around the core periphery.
This is evaluated with the Reactor Vessel Internals license renewal system.Not included in the HPCS System scoping boundary are the HPCS Diesel Generators.
The HPCS Diesel Generators are evaluated with the Diesel Generator and Auxiliaries license renewal system.Not included in the scope of license renewal are the nonsafety-related portions of the HPCS supply and return pipes from the cycled condensate storage tank to the Reactor Building as these pipes do not have the potential for spatial interaction with safety-related equipment.
Reason for Scope Determination The High Pressure Core Spray System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The High Pressure Core Spray System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The High Pressure Core Spray System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63). The High Pressure Core Spray System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provide primary containment boundary.
The HPCS System includes safety-related primary containment isolation valves on the HPCS suction from the suppression pool, HPCS relief valve discharge piping, and the HPCS full flow test and minimum flow lines. 10 CFR 54.4(a)(1)
: 2. Provide emergency core cooling where the equipment provides coolant directly to the core.The HPCS System provides core cooling following a break in the reactor coolant pressure boundary by delivering water from the suppression pool through nozzles in a circular sparger LaSalle County Station, Units 1 and 2 2.3-18 License Renewal Application Section 2 -Scoping and Screening Methodology and Results located above and around the core periphery.
10 CFR 54.4(a)(1)
: 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The HPCS System contains nonsafety-related water filled lines in the Reactor Building which have potential spatial and structural interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The HPCS System is credited for Fire Safe Shutdown by supporting the basic safe-shutdown method system. 10 CFR 54.4(a)(3)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The HPCS System contains components that are environmentally qualified.
10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The HPCS System is credited for reactor cooling and make-up for Station Blackout coping. 10 CFR 54.4(a)(3)
UFSAR References 1.2.2.5.1 Table 3.2-1 Table 6.1-1 Table 6.2-21 Table 6.2-28 6.3.2.2.1 7.3.1.2.1 License Renewal Boundary Drawingqs LR-LAS-M-95, Sheet 1 LR-LAS-M-141, Sheet 1 LR-LAS-M-91, Sheet 5 LR-LAS-M-1 37, Sheet 5 LR-LAS-M-2095, Sheet 1 LR-LAS-M-2141, Sheet 1 LaSalle County Station, Units 1 and 2 2.3-19 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.2-1 High Pressure Core Spray System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Flow Device Pressure Boundary Throttle Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (HPCS Pump) Pressure Boundary Pump Casing (Water Leg Pump) Pressure Boundary Strainer Element Filter Pressure Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.2.2-1 High Pressure Core Spray System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-20 Section 2 -Scoping and Screening Methodology and Results 2.3.2.2 Low Pressure Core Spray System Description The Low Pressure Core Spray System (LPCS) is a standby system designed to provide core cooling following a break in the reactor coolant pressure boundary which would rapidly depressurize the reactor vessel. The LPCS is also designed to provide core cooling following a small break in which the automatic depressurization system (ADS) or high-pressure core spray system (HPCS) has operated to lower the reactor vessel pressure to the operating range of the LPCS.The purpose of the LPCS is to provide core cooling following a break in the reactor coolant pressure boundary.
The LPCS accomplishes this by delivering water from the suppression pool through nozzles in a circular sparger located above and around the core periphery.
The LPCS also includes a water leg pump which functions to keep the ECCS discharge lines filled to avoid hydrodynamic effects on ECCS pump initiation.
The LPCS water leg pump services the LPCS and the "A" loop of the residual heat removal system (RHR).The LPCS is automatically actuated by reactor vessel low water level or drywell high pressure, or, can be manually actuated from the control room. The ADS is interlocked with the LPCS by means of pressure switches located in the pump discharge piping upstream of the pump discharge check valves. The pump discharge pressure is used as a permissive for automatic initiation of ADS. This ensures that the LPCS pump has received electrical power, started, and is capable of delivering water into the vessel prior to vessel depressurization.
The LPCS includes primary containment isolation valves on the LPCS suction, minimum flow, and full flow test lines. To assure continuity of core cooling, signals to isolate the primary containment do not operate any LPCS valves which could affect flow to the reactor pressure vessel. The LPCS also includes relief valves for overpressure protection of the LPCS pump suction and discharge piping. These relief valves discharge into the suppression pool and are also primary containment isolation valves.The LPCS contains components that are environmentally qualified.
The LPCS primary containment isolation valves are credited for Station Blackout coping. The LPCS water leg pump is credited for Fire Safe Shutdown by supporting the "A" loop of RHR which is a basic method system.For more detailed information see UFSAR Section 6.3.2.2.3.
Boundary The LPCS scoping boundary begins at the LPCS suction strainer in the suppression pool and continues through suction piping and a primary containment isolation valve, through the LPCS pump, and terminates at the upstream side of the LPCS discharge outboard primary containment isolation valve (evaluated with the Reactor Coolant Pressure Boundary System).The LPCS scoping boundary includes a minimum flow and a full flow test line which begin at the discharge of the LPCS pump and continue through primary containment isolation valves prior to terminating inside the suppression pool.The water leg fill portion of the LPCS begins at the suction of the LPCS pump and continues through the water leg pump suction piping, through the water leg pump, and terminates at the LaSalle County Station, Units 1 and 2 2.3-21 License Renewal Application Section 2 -Scoping and Screening Methodology and Results discharge piping of the LPCS pump and discharge piping of the "A" RHR pump.All associated piping, components and instrumentation contained within the boundary described above are also included in the LPCS scoping boundary.Also included in the LPCS System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the LPCS System scoping boundary are the piping and components associated with the discharge portion of the system from the pump discharge valve to the reactor vessel. These components are evaluated with the Reactor Coolant Pressure Boundary license renewal system.Not included in the LPCS scoping boundary is the circular sparger located above and around the core periphery.
This is evaluated with the Reactor Vessel Internals license renewal system.Reason for Scope Determination The Low Pressure Core Spray System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Low Pressure Core Spray System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Low Pressure Core Spray System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63). The Low Pressure Core Spray System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provide primary containment boundary.
The LPCS includes safety-related primary containment isolation valves on the LPCS suction from the suppression pool, LPCS relief valve discharge piping, and the LPCS full flow test and minimum flow lines. 10 CFR 54.4(a)(1)
: 2. Provide emergency core cooling where the equipment provides coolant directly to the core.The LPCS provides core cooling following a break in the reactor coolant pressure boundary by delivering water from the suppression pool through nozzles in a circular sparger located above and around the core periphery.
10 CFR 54.4(a)(1)
: 3. Sense process conditions and generate signals for reactor trip or engineered safety features actuation.
LPCS pump discharge pressure is used as a permissive for automatic initiation of ADS. 10 CFR 54.4(a)(1)
LaSalle County Station, Units 1 and 2 2.3-22 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The LPCS contains nonsafety-related water filled lines in the Reactor Building which have potential spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The LPCS water leg pump is credited for Fire Safe Shutdown by supporting the "A" loop of RHR which is a basic method system. 10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The LPCS contains components that are environmentally qualified.
10 CFR 54.4(a)(3)
: 7. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The LPCS primary containment isolation valves are credited for Station Blackout coping. 10 CFR 54.4(a)(3)
UFSAR References 1.2.2.5.3 Table 3.2-1 Table 6.1-1 Table 6.2-21 Table 6.2-28 6.3.2.2.3 7.3.1.2.2 7.3.1.2.3 Chapter 15 Table 15.9-4 License Renewal Boundary Drawings LR-LAS-M-94, Sheet 1 LR-LAS-M-140, Sheet 1 LR-LAS-M-91, Sheet 5 LR-LAS-M-96, Sheet 1 LR-LAS-M-1 37, Sheet 5 LR-LAS-M-142, Sheet 1 LaSalle County Station, Units 1 and 2 2.3-23 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.2-2 Low Pressure Core Spray System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Flow Device Pressure Boundary Throttle Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (LPCS Pump) Pressure Boundary Pump Casing (Water Leg Pump) Pressure Boundary Strainer Element Filter Pressure Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.2.2-2 Low Pressure Core Spray System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-24 Section 2 -Scoping and Screening Methodology and Results 2.3.2.3 Reactor Core Isolation Cooling System Description The Reactor Core Isolation Cooling (RCIC) System is a standby system designed to ensure that sufficient reactor water inventory is maintained in the reactor pressure vessel (RPV) to allow for adequate core cooling. The RCIC System is in scope for license renewal. However, portions of the RCIC System are not required to perform system intended functions and are not in scope.Although not a safety system, the purpose of the RCIC System is to provide makeup water to the RPV when the vessel is isolated.
The RCIC System accomplishes this by pumping water from the cycled condensate storage tank or directly from the suppression pool or from the suppression pool via the RHR heat exchangers, depending on reactor conditions, and discharges it through the head spray nozzle of the RPV to maintain reactor water level. This capability prevents reactor fuel from overheating when (1) the reactor vessel is isolated and maintained in the hot standby condition, (2) the reactor vessel is isolated and accompanied by loss of the coolant flow from the reactor feedwater system, or (3) the reactor vessel is shutdown under condition of loss of the normal feedwater system and prior to operation of the shutdown cooling system.The RCIC System utilizes a steam-driven turbine-pump unit which operates automatically to maintain adequate water level in the RPV. The RCIC System steam supply is from the RPV upstream of the main steam isolation valves. The RCIC System supports RPV depressurization to a shutdown condition with the reactor coolant pressure boundary isolated by maintaining sufficient RPV water inventory.
The RCIC System continues to operate until the RPV is depressurized to the point at which low pressure coolant injection and low pressure core spray system operation can maintain core cooling.The RCIC System operation is initiated automatically by reactor vessel low water level or can be initiated manually.
The RCIC System can be operated on DC emergency power without the need for AC emergency power.For more detailed information, see UFSAR Sections 5.4.6 and 7.4.1.Boundary The RCIC System license renewal scoping boundary for water injection begins at the RCIC pump suction piping from the cycled condensate storage tank at the flange directly upstream of the outer manual shutoff valve, and also from the suppression pool at the suction strainer.The scoping boundary continues through to the RCIC pump to the discharge flow path. The discharge flow path continues through the discharge of the RCIC pump, and terminates at the RCIC injection valve outside of primary containment.
The discharge path also includes a minimum flow line to the suppression pool and a test return line to the cycled condensate storage tank.The RCIC System license renewal scoping boundary for the steam supply begins at the outboard RCIC containment isolation valve and continues through the RCIC turbine, and the RCIC turbine exhaust to the suppression pool. Auxiliary systems include gland seal, drain pots, and turbine lubricating and control oil.LaSalle County Station, Units 1 and 2 2.3-25 License Renewal Application Section 2 -Scoping and Screening Methodology and Results All associated piping, components and instrumentation, contained within flow paths and subsystems described above are included in the RCIC System scoping boundary.Also included in the RCIC System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the RCIC System scoping boundary are the piping and components associated with the water injection portion of the system from the RCIC injection valve outside of containment to the reactor vessel. These components are evaluated with the Reactor Coolant Pressure Boundary license renewal system.Not included in the RCIC System scoping boundary are the piping and components associated with the main steam supply portion of the system up to and including the outboard RCIC steam isolation valve. These components are evaluated with the Reactor Coolant Pressure Boundary license renewal system.Not included in the scope of license renewal are the abandoned RCIC System lines located in the Off Gas Filter Building.
These lines are verified to be isolated, drained, and vented and therefore do not present a spatial interaction hazard to safety-related equipment.
Also not included in the scope of license renewal are the RCIC System water return lines to the cycled condensate storage tanks. These lines are nonsafety-related and are not located in areas where there are potential spatial interactions with components performing safety-related functions, and therefore are not relied upon to perform or support any system intended function.Not included in the RCIC System scoping boundary are the piping and components associated with the main steam supply portion of the system up to and including the outboard steam isolation valve. These components are evaluated with the Reactor Coolant Pressure Boundary license renewal system.Reason for Scope Determination The Reactor Core Isolation Cooling System meets 10 CFR 54.4(a)(1) because it has safety-related components that are relied upon to remain functional during and following design basis events. The Reactor Core Isolation Cooling System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Reactor Core Isolation Cooling System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63). The Reactor Core Isolation Cooling System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).LaSalle County Station, Units 1 and 2 2.3-26 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Intended Functions 1. Remove residual heat from the reactor coolant system. The RCIC System is capable of maintaining sufficient coolant inventory in the reactor vessel in case of an isolation with a loss of main feedwater flow. 10 CFR 54.4(a)(1)
: 2. Provide primary containment boundary.
The RCIC System includes safety-related primary containment isolation valves on the RCIC suction from the suppression pool, HPCS relief valve discharge piping, and the RCIC full flow test and minimum flow lines. 10 CFR 54.4(a)(1)
: 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The RCIC System includes nonsafety-related water filled lines in the Reactor Buildings that have the potential for spatial interactions (spray or leakage) or structurally interact with safety-related SSCs. 10 CFR 54.4(a)(2)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection.
(10 CFR 50.48) The RCIC System supports Safe Shutdown.
10 CFR 54.4(a)(3)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The RCIC System includes environmentally qualified electrical components.
10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The RCIC System can be operated without AC power during a station blackout event to provide coolant to the reactor vessel. 10 CFR 54.4(a)(3)
UFSAR References 1.2.2.3 5.4.6 7.4.1 License Renewal Boundary Drawings LR-LAS-M-74, Sheet 1 LR-LAS-M-91, Sheet 5 LR-LAS-M-94, Sheet 1 LR-LAS-M-96, Sheet 4 LR-LAS-M-101, Sheets 1, 2 LR-LAS-M-127, Sheet 1 LR-LAS-M-137, Sheet 5 LR-LAS-M-140, Sheet 1 LR-LAS-M-142, Sheet 4 LR-LAS-M-147, Sheets 1, 2 LaSalle County Station, Units 1 and 2 2.3-27 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.2-3 Reactor Core Isolation Cooling System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Flow Device Pressure Boundary Throttle Heat Exchanger
-(Lube Oil Cooler) Shell Pressure Boundary Side Components Heat Exchanger
-(Lube Oil Cooler) Tube Pressure Boundary Sheet Heat Exchanger
-(Lube Oil Cooler) Heat Transfer Tubes Pressure Boundary Hoses Leakage Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (Condenser Condensate Leakage Boundary Pump)Pump Casing (Condenser Vacuum Leakage Boundary Pump)Pump Casing (RCIC Pump) Pressure Boundary Pump Casing (Turbine Main Oil Pump) Pressure Boundary Pump Casing (Water Leg Pump) Pressure Boundary Rupture Disks Pressure Boundary Strainer Element Filter Pressure Boundary Tanks (Turbine Lube Oil Reservoirs)
Pressure Boundary Tanks (Vacuum Tank) Leakage Boundary Turbine Casings (RCIC Turbine) Pressure Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.2.2-3 Reactor Core Isolation Cooling System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-28 Section 2 -Scoping and Screening Methodology and Results 2.3.2.4 Residual Heat Removal System Description The Residual Heat Removal (RHR) System is a standby heat removal system that also provides a low pressure emergency core cooling system (ECCS) function to supply cooling water for removal of fission product heat from the reactor core and primary containment following a postulated design basis event or normal operation.
The low pressure coolant injection (LPCI) function of the RHR System is designed to provide cooling to the reactor core when the reactor vessel pressure is low, as is the case for large LOCA break sizes. However, when LPCI operates in conjunction with the Automatic Depressurization System (ADS) and High Pressure Core Spray System (HPCS), the effective core cooling capability of LPCI is extended to small breaks. The RHR System has multiple purposes, listed below. It accomplishes these purposes through circulation of water through the various available system flow paths.The low pressure coolant injection (LPCI) mode is credited as an emergency core cooling system. The function of LPCI is to cool the reactor core by flooding the reactor pressure vessel (RPV) following a loss of coolant accident (LOCA). LPCI is automatically actuated by low reactor water level or high drywell pressure.
LPCI takes water from the suppression pool and injects water directly into the core shroud. Reactor pressure must be reduced below normal operating pressure before LPCI can begin to flood the RPV. LPCI provides protection to the core for a large break, including a design basis accident (DBA) when the RPV rapidly depressurizes.
It also provides protection during a small break after ADS has reduced pressure to the operating range of RHR. Using the suppression pool as a source of water, LPCI provides a closed loop for recirculation of water escaping from the break. The pumps, piping, and control systems are physically and electrically separated so that any single event will not render all of the loops inoperable.
The suppression pool cooling mode is used to cool the suppression pool during normal and emergency situations.
The purpose of this mode is to remove the heat that gets transferred to the suppression pool during a LOCA or during operations that add heat to the suppression pool. Heat is rejected from the suppression pool through a pair of heat exchangers cooled by the Essential Cooling Water System.The shutdown cooling and RPV head spray mode maintains the reactor core in a cold shutdown condition and meets the requirements for long-term heat removal. This mode is used to remove decay heat, prevent thermal stratification, and cool the reactor for maintenance and refueling.
It also provides a flowpath for core cooling during emergency situations when the normal injection flow path is unavailable.
Shutdown cooling takes water from the RPV, cools it in a heat exchanger cooled by the Essential Cooling Water System and then returns the water to the RPV where it is forced through the reactor core. Head spray is used to condense steam and cool the RPV head during RPV flooding operations and to prevent thermal stratification during shutdown cooling. Head spray diverts some of the shutdown cooling flow and sprays that water into the RPV head area.The alternate shutdown cooling mode is used for decay heat removal when the normal mode of heat removal is unavailable.
The full flow test mode allows testing of certain RHR System components for system operability during all modes of reactor operation without having to inject water directly into the LaSalle County Station, Units 1 and 2 2.3-29 License Renewal Application Section 2 -Scoping and Screening Methodology and Results RPV. The difference between the suppression pool cooling and full flow test modes is that in the test mode the heat exchanger bypass valve remains open.The suppression chamber/drywell spray mode is used to condense any steam that may not have completely condensed in the suppression pool and drywell following a LOCA. It also provides an additional method of containment cooling that can be used in an emergency.
The suppression pool is sprayed from a spray header installed in the inner circumference of the upper air space of the chamber and fed from either RHR A or B loops. The drywell is sprayed from either of two ring spray headers inside the drywell. One drywell spray header is supplied by RHR Loop A and the other is supplied by RHR Loop B. RHR pumps do not have sufficient capacity to simultaneously spray the drywell and supply the LPCI mode.The fuel pool cooling assist mode uses the RHR loop B heat exchanger to assist in cooling the fuel pool during times of heavy heat load. This could occur when the entire reactor core is off-loaded shortly following reactor shutdown.
The fuel pool cooling assist mode requires that spool pieces be installed to connect the RHR and Fuel Pool Cooling and Storage (FPC)Systems. Discharge from the RHR System to the FPC System terminates in a diffuser located in the fuel pool.The RHR keep fill system uses a small pump (water leg pump) to keep the RHR discharge piping full downstream of the RHR pump discharge check valve. The RHR System may be used to remove water from the reactor while in shutdown cooling. Instead of returning all the water to the reactor, some water may be diverted to Radwaste System, the main condenser, or suppression pool. The RHR System can be used to control suppression pool water level and to drain water from the suppression pool during maintenance.
The RHR 'B' loop can take water from the Fuel Pool Cooling and Storage System to flood the RPV if required.For more detailed information see UFSAR Sections 5.4.7, 6.3.1 and 6.3.2.Boundary The RHR System license renewal scoping boundary begins with the strainers in the suppression pool and continues through individual suction headers and suction isolation valves to each of the three residual heat removal pumps. It continues from the pumps through discharge piping and valves to the reactor containment where it interfaces with the LPCI portion of the Reactor Coolant Pressure Boundary (RCPB) System at the outboard containment isolation valve for each LPCI injection line. The boundary also includes the piping and valves in the suction flowpath from the reactor recirculation suction line, which begins at the outboard containment isolation valve (part of the RCPB System) and continues to the RHR System pump suction headers. Also included are the RHR heat exchangers (RHR flowpath is through the shell side), including piping and valves in the lines to the heat exchangers and from them to the shutdown cooling injection outboard isolation valves (part of the RCPB System), and to the drywell spray, head spray and suppression pool spray and return flowpaths described below. The Essential Cooling Water System provides cooling water to the RHR heat exchanger tube side components.
The RHR pump discharge flowpath includes the piping and valves to the containment spray piping (drywell and suppression pool), terminating at the spray rings and nozzles inside containment.
The system scoping boundary also includes piping and valves in the full-flow test lines and minimum flow recirculation lines from the pump discharge to the suppression pool. The water leg fill portion of the RHR System begins at the suction of the RHR pump and continues through the water leg pump suction piping, through the water leg pump, and terminates at the discharge piping of the RHR pump.LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-30 Section 2 -Scoping and Screening Methodology and Results All associated piping, components and instrumentation contained within the boundary described above are also included in the RHR System scoping boundary.Also included in the RHR System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the RHR System scoping boundary are the piping and components associated with discharge portions of the system. These components are evaluated with the Reactor Coolant Pressure Boundary license renewal system.Reason for Scope Determination The Residual Heat Removal System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Residual Heat Removal System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Residual Heat Removal System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63).The Residual Heat Removal System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provide primary containment boundary.
The RHR System provides safety-related primary containment isolation capability on containment spray discharge, suppression pool suction, and test return lines penetrating the primary containment.
10 CFR 54.4(a)(1)
: 2. Remove residual heat from the reactor coolant system. The RHR System removes decay and sensible heat from the reactor primary system. 10 CFR 54.4(a)(1)
: 3. Provide emergency core cooling where the equipment provides coolant directly to the core.The RHR System provides water from the suppression pool to be injected directly into the core region of the reactor vessel following a LOCA. 10 CFR 54.4(a)(1)
: 4. Provide emergency heat removal from primary containment and provide containment pressure control. The RHR System provides for maintaining the suppression pool temperature below required limits following a reactor blowdown.
The RHR System also provides for spraying the drywell and suppression pool vapor spaces to maintain internal pressure below design limits. 10 CFR 54.4(a)(1)
: 5. Sense process conditions and generate signals for reactor trip or engineered safety LaSalle County Station, Units 1 and 2 2.3-31 License Renewal Application Section 2 -Scoping and Screening Methodology and Results features actuation.
The RHR System provides for associated actuation and system protection logic for engineered safety features operation.
10 CFR 54.4(a)(1)
: 6. Ensure adequate cooling in the spent fuel pool to maintain stored fuel within acceptable temperature limits. The RHR System provides additional cooling capacity for fuel pool cooling.10 CFR 54.4(a)(1)
: 7. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The RHR System contains nonsafety-related fluid filled lines within the Reactor Buildings which have the potential for spatial interaction with safety-related SSCs. 10 CFR 54.4(a)(2)
: 8. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The RHR System is credited for reactor makeup and heat removal for Fire Safe Shutdown.
10 CFR 54.4(a)(3)
: 9. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The RHR System has components credited in the Environmental Qualification program. 10 CFR 54.4(a)(3)
: 10. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The primary containment isolation and decay heat removal functions of the RHR System are credited for Station Blackout coping. 10 CFR 54.4(a)(3)
UFSAR References 5.4.7 6.2.1.1 6.2.2 6.3.1 6.3.2 7.4.3 License Renewal Boundary Drawings LR-LAS-M-96, Sheets 1, 2, 3, 4, 5 LR-LAS-M-142, Sheets 1, 2, 3, 4, 5 LR-LAS-M-91, Sheet 5 LR-LAS-M-94, Sheet 1 LR-LAS-M-95, Sheet 1 LR-LAS-M-101, Sheet 1 LR-LAS-M-115, Sheets 1, 12 LR-LAS-M-1 37, Sheet 5 LR-LAS-M-140, Sheet 1 LR-LAS-M-141, Sheet 1 LR-LAS-M-147, Sheet 1 LR-LAS-M-159, Sheet 1 LaSalle County Station, Units 1 and 2 2.3-32 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.2-4 Residual Heat Removal System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Flow Device Pressure Boundary Throttle Heat Exchanger
-(RHR Heat Exchanger)
Pressure Boundary Shell Side Components Heat Exchanger
-(RHR Heat Exchanger)
Pressure Boundary Tube Sheet Heat Exchanger
-(RHR Heat Exchanger)
Heat Transfer Tubes Pressure Boundary Hoses Pressure Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (RHR Pump) Pressure Boundary Pump Casing (Water Leg Pump) Pressure Boundary Spray Nozzles Spray Strainer Element Filter Pressure Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.2.2-4 Residual Heat Removal System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-33 Section 2 -Scoping and Screening Methodology and Results 2.3.2.5 Standby Gas Treatment
 
===System Description===
The Standby Gas Treatment (SGT) System is a standby system designed to reduce halogen and particulate concentrations in gases leaking from the Primary Containment and which are potentially present in the secondary containment following an accident.
The system also provides an alternate means of purging the Primary Containment.
The SGT System is in scope for license renewal.The SGT System is part of secondary containment.
When initiated, the system takes suction on the secondary containment, treats the air flowing through the system, and then releases that air to the environment via an elevated release point. The SGT System maintains a slightly negative internal secondary containment pressure to prevent any untreated air leakage from being released to the environment.
The SGT System is designed to function during a design basis LOCA with a simultaneous loss of off-site power. During movement of irradiated fuel, the system controls releases from postulated fuel handling accidents.
The system is normally in standby, and automatically starts and operates during design basis accidents.
The SGT System is a safety-related system. SGT System equipment is powered from the essential buses and is started either automatically or manually from the control room.For more detailed information, see UFSAR Sections 6.5.1 and 7.3.8.Boundary The SGT System consists of two independent subsystems that are shared between Unit 1 and Unit 2, each with its own set of ductwork, dampers, charcoal filter train, and isolation and control dampers, interconnecting pipes, and associated instrumentation.
Each charcoal filter train consists of a filter unit fan and cooling fan, a demister, an electric heater, a prefilter bank, two HEPA filter banks, and a charcoal adsorber.
The SGT trains discharge to an exhaust stack located within the plant vent stack. The plant vent stack is evaluated with the Auxiliary Building.All associated piping, components and instrumentation contained within the boundary described above are also included in the SGT System scoping boundary.Also included in the SGT System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system, specifically the filter plenum moisture collection and drain pans. Also included in the license renewal scoping boundary of the SGT System are those portions of nonsafety-related piping components relied upon to preserve the structural integrity intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the SGT System scoping boundary are the carbon adsorber filter water deluge spray piping, headers, valves, and temperature detectors.
These components perform a fire LaSalle County Station, Units 1 and 2 2.3-34 License Renewal Application Section 2 -Scoping and Screening Methodology and Results protection function, and are evaluated with the Fire Protection System.Reason for Scope Determination The Standby Gas Treatment System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Standby Gas Treatment System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Standby Gas Treatment System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49). The Standby Gas Treatment System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Control and treat radioactive materials released to the secondary containment.
The SGT System maintains a negative pressure within secondary containment, and reduces halogen and particulate concentrations in gases potentially present in the secondary containment following an accident prior to release to the environment.
10 CFR 54.4(a)(1)
: 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The SGT System includes nonsafety-related piping that structurally interacts with safety-related SSCs, and water filled components that have the potential for spatial interactions (spray or leakage) with safety-related SSCs. 10 CFR 54.4(a)(2)
: 3. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The SGT System contains components that are environmentally qualified.
10 CFR 54.4(a)(3)
UFSAR References 6.5.1 7.3.8 License Renewal Boundary Drawinqis LR-LAS-M-89, Sheet 1 LR-LAS-M-92, Sheet 1 LR-LAS-M-105, Sheet 1 LR-LAS-M-138, Sheet 1 LR-LAS-M-153, Sheet 1 LaSalle County Station, Units 1 and 2 2.3-35 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.2-5 Standby Gas Treatment System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Ducting and Components Leakage Boundary Pressure Boundary Flexible Connection Pressure Boundary Piping, piping components, and piping Pressure Boundary elements Structural Integrity Valve Body Pressure Boundary The aging management review results for these components are provided in: Table 3.2.2-5 Standby Gas Treatment System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 23-36 Section 2 -Scoping and Screening Methodology and Results 2.3.3 AUXILIARY SYSTEMS The following systems are addressed in this section:* Closed Cycle Cooling Water System (2.3.3.1)* Combustible Gas Control System (2.3.3.2)* Compressed Air System (2.3.3.3)* Control Rod Drive System (2.3.3.4)* Control Room Ventilation System (2.3.3.5)* Cranes, Hoists, and Refueling Equipment System (2.3.3.6)* Demineralized Water Makeup System (2.3.3.7)* Diesel Generator and Auxiliaries System (2.3.3.8)* Drywell Pneumatic System (2.3.3.9)* Electrical Penetration Pressurization System (2.3.3.10)
* Essential Cooling Water System (2.3.3.11)
* Fire Protection System (2.3.3.12)
* Fuel Pool Cooling and Storage System (2.3.3.13)" Nonessential Cooling Water System (2.3.3.14)
* Nonsafety-Related Ventilation System (2.3.3.15)
* Plant Drainage System (2.3.3.16)
* Primary Containment Ventilation System (2.3.3.17)" Process Radiation Monitoring System (2.3.3.18)
* Process Sampling and Post Accident Monitoring System (2.3.3.19)" Radwaste System (2.3.3.20)" Reactor Water Cleanup System (2.3.3.21)
* Safety-Related Ventilation System (2.3.3.22)
* Standby Liquid Control System (2.3.3.23)
* Suppression Pool Cleanup System (2.3.3.24)" Traversing Incore Probe System (2.3.3.25)
LaSalle County Station, Units 1 and 2 2.3-37 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 2.3.3.1 Closed Cycle Cooling Water System Description The Closed Cycle Cooling Water System (CCW) is a normally operating closed cooling water system designed to provide cooling water to various plant components.
The CCW consists of the reactor building closed cooling water system and turbine building closed cooling water system. The CCW is in scope for license renewal. However, portions of the CCW are not required to perform intended functions and are not in scope.The purpose of the reactor building closed cooling water portion of the CCW is to provide cooling water to various components in the Reactor Building, Primary Containment and Off-gas Building.
The system accomplishes this by circulating demineralized and chemically treated cooling water through these components and transferring the heat to the plant service water system through the reactor building closed cooling water heat exchangers.
The reactor building closed cooling water lines to and from the reactor recirculation pump motor coolers, pump seals, and pump bearings, and drywell penetration cooling coils penetrate the primary containment and are provided with safety-related and environmentally qualified motor operated primary containment isolation valves. The primary containment isolation boundary also includes pressure relief valves to protect the containment penetration piping from overpressurization when it is isolated during a LOCA. The pressure relief valves also function as primary containment isolation valves.The purpose of the turbine building closed cooling water system portion of the CCW is to provide cooling water to various components in the Turbine Building.
The system accomplishes this by circulating demineralized and chemically treated cooling water through these components and transferring the heat to the plants service water system through the turbine building closed cooling water heat exchangers.
The turbine building closed cooling water system portion of the CCW does not perform an intended function and is not in scope for license renewal.For more detailed information see UFSAR Sections 9.2.3 and 9.2.8.Boundary The reactor building closed cooling water portion of the CCW license renewal scoping boundary begins at the reactor building closed cooling water pumps and continues through the following Reactor Building heat loads: reactor building equipment drain tank heat exchangers, reactor building process sampling system (evaluated with the Process Sampling System), control rod drive feed pumps, reactor water cleanup non-regenerative heat exchangers, reactor water cleanup pump heat exchangers, reactor building instrument storage room air conditioning unit, drywell pneumatic system compressors and aftercoolers, drywell equipment drain sump heat exchanger, and drywell sump sample pump. The boundary continues from these heat loads through the reactor building closed cooling water heat exchangers prior to returning to the reactor building closed cooling water system pumps. The boundary includes the reactor building closed cooling water expansion tank and reactor building closed cooling water chemical feeder.The reactor building closed cooling water portion of the CCW license renewal scoping LaSalle County Station, Units 1 and 2 2.3-38 License Renewal Application Section 2 -Scoping and Screening Methodology and Results boundary also includes the following primary containment heat loads: reactor recirculation system pump motor coolers, pump seals, and pump bearings (evaluated with the Reactor Coolant Pressure Boundary), and drywell penetration cooling coils. Each primary containment influent and effluent line includes two motor operated containment isolation valves and a pressure relief valve for overpressure protection.
All associated piping, components and instrumentation contained within the boundary described above are also included in the CCW scoping boundary.Also included in the reactor building closed cooling water portion of the CCW System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Building, Primary Containment, and Auxiliary Building.Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the scope of license renewal is the turbine building closed cooling water portion of the CCW System since the turbine building closed cooling water system does not perform or support system intended functions.
The turbine building closed cooling water system portion of the CCW does not include pressure-retaining components located in areas where there are potential spatial interactions with components performing safety-related functions, and is not required to maintain leakage boundary integrity to preclude system interaction.
Therefore, the turbine building closed cooling water system portion of the CCW is not within the scope of license renewal.Reason for Scope Determination The Closed Cycle Cooling Water System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Closed Cycle Cooling Water System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Closed Cycle Cooling Water System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49). The Closed Cycle Cooling Water System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provide primary containment boundary.
The CCW includes safety-related primary containment isolation valves. 10 CFR 54.4(a)(1)
: 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The CCW contains nonsafety-related water filled lines in the Reactor Building, Primary Containment, and Auxiliary Building which provide structural support or have potential spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
LaSalle County Station, Units 1 and 2 2.3-39 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 3. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The CCW contains components that are environmentally qualified.
10 CFR 54.4(a)(3)
UFSAR References 1.2.2.6.1 Table 3.2-1 6.2.4.2.2 Table 6.2-21 Table 6.2-28 9.2.3 9.2.8 11.5.2.3.5 License Renewal Boundary Drawings LR-LAS-M-90, Sheets 1, 2, 3 LR-LAS-M-136, Sheets 1,2, 3 LR-LAS-M-66, Sheets 5, 9, 10, 11 LR-LAS-M-91, Sheets 2, 3, 4, 5 LR-LAS-M-104, Sheet 1 LR-LAS-M-1 15, Sheets 1, 2 LR-LAS-M-1 37, Sheets 2, 3, 4, 5 LR-LAS-M-149, Sheet 1 LR-LAS-M-1 53, Sheets 4, 6 LR-LAS-M-159, Sheets 1, 2 LaSalle County Station, Units 1 and 2 2.3-40 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.3-1 Closed Cycle Coolinq Water System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Heat Exchanger
-(CRD Feed Pump Leakage Boundary Bearing and Gear Oil Coolers) Tube Side Components Heat Exchanger
-(Clean-up Non- Leakage Boundary Regenerative Heat Exchanger)
Shell Side Components Heat Exchanger
-(Drywell Equipment Leakage.Boundary Drain Sump Heat Exchanger)
Shell Side Components Heat Exchanger
-(Drywell Penetration Leakage Boundary Cooling Coils) Tube Side Components Heat Exchanger
-(Nitrogen Compressor Leakage Boundary Aftercooler)
Shell Side Components Heat Exchanger
-(Nitrogen Compressor Leakage Boundary Inter-Cooler)
Tube Side Components Heat Exchanger
-(RWCU Pump Heat Leakage Boundary Exchanger)
Tube Side Components Heat Exchanger
-(Reactor Building Leakage Boundary Closed Cooling Water Heat Exchanger)
Shell Side Components Heat Exchanger
-(Reactor Building Leakage Boundary Equipment Drain Tank Heat Exchanger)
Shell Side Components Heat Exchanger
-(Reactor Building Leakage Boundary Ventilation Instrument Room A/C Unit)Tube Side Components Hoses Leakage Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (Reactor Building Closed Leakage Boundary Cooling Water Pump)Tanks (Reactor Building Closed Cooling Leakage Boundary Water Chemical Feeder)Tanks (Reactor Building Closed Cooling Leakage Boundary Water Expansion Tank)Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-1 Closed Cycle Cooling Water System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-41 Section 2 -Scoping and Screening Methodology and Results 2.3.3.2 Combustible Gas Control System Description The Combustible Gas Control (CGC) System is a standby system designed to ensure that primary containment integrity is not threatened by the possibility of combustion of combustible gases following a LOCA. The CGC System is within the scope of license renewal. However, portions of the CGC System are not required to perform intended functions, and are not included in the scope of license renewal. The purpose of the CGC System includes:
inerting primary containment with nitrogen, purging containment with air to permit maintenance, controlling containment pressure, and controlling combustible gas concentrations after a LOCA. The CGC System includes a nitrogen supply system, containment vent and purge system, and a hydrogen recombiner system.The nitrogen supply system provides a supply of gaseous nitrogen to the primary containment on both units to maintain an inert atmosphere within primary containment.
Liquid nitrogen, stored in tanks, is vaporized and provided to either unit in high flow mode for inerting, and in low flow mode for normal makeup, to maintain an inert atmosphere at a slight positive pressure.
The nitrogen supply system is nonsafety-related and is not in scope for license renewal since it does not support any intended functions.
The containment vent and purge system can be aligned to supply nitrogen from the nitrogen supply system or air from the Reactor Building to Primary Containment, and to vent displaced containment atmosphere through a purge air filter train or the Standby Gas Treatment System (SGTS) prior to discharge to the environment.
During power operation, the containment vent and purge system is manually operated to supply makeup nitrogen to maintain a low oxygen concentration inside primary containment.
The containment atmosphere is contained by primary containment isolation valves, and is circulated and cooled by the Primary Containment Ventilation System. During post-accident conditions, the containment vent and purge system can be used to vent containment by manually over-riding isolation signals and aligning the vent flow path to the purge air filter train or the SGTS prior to discharge to the environment.
All containment vent and purge system piping connections to the Primary Containment include remotely operated valves that are automatically closed by the Primary Containment Isolation System upon indications of high drywell pressure, low-low reactor water level, or reactor building or spent fuel pool ventilation exhaust high radiation signals. The portions of the containment vent and purge system that maintain the primary or secondary containment boundary are safety-related, designed to seismic Category I requirements, and are in scope for license renewal.The hydrogen recombiner system is comprised of two redundant hydrogen recombiner packages located outside of primary containment that can service either unit. During post-accident conditions, when hydrogen levels in containment are elevated, flow is established from the drywell air space through a blower that is part of the recombiner package to the suppression chamber air space. This operation provides mixing that prevents combustible concentrations of hydrogen from accumulating in low flow areas within the drywell. The hydrogen recombining function of the hydrogen recombiners is abandoned in place and not credited for reducing hydrogen concentration inside containment.
The hydrogen recombiner system includes piping that is part of the primary containment boundary and valves that automatically close upon receipt of signals from the primary containment isolation system.During normal plant operation, the hydrogen recombiners are isolated from containment.
The hydrogen recombiner system is safety-related, designed to seismic Category I requirements, LaSalle County Station, Units 1 and 2 2.3-42 License Renewal Application Section 2 -Scoping and Screening Methodology and Results and is in scope for license renewal.For more detailed information, see UFSAR Sections 6.2.5, 7.3.5, 9.4.10, and 9.5.9.Boundary The CGC System license renewal scoping boundary begins at the liquid nitrogen storage tanks and includes an electric water bath vaporizer, ambient air vaporizer, high flow and low flow pressure/temperature control stations, and associated piping instrumentation and controls that are located outdoors.
The CGC System boundary continues to piping that passes through the Offgas Building to the Reactor Buildings to connections to the drywell and suppression chamber air space. Included in the scoping boundary is the pressure sensing line from the drywell air space to the pressure controller used for nitrogen makeup. The portion of the nitrogen supply system that is outside of the primary containment isolation valves does not support intended functions and is not in scope for license renewal.The CGC System boundary also includes the drywell and suppression chamber purge air supply piping that is open to the Reactor Building air space, continuing through the primary containment isolation valves to the drywell and suppression chamber air space. Also included is the vent piping from the drywell and suppression chamber air spaces through containment isolation valves to the piping interface with the SGTS and continuing through secondary containment isolation valves to the purge air filter package outlet damper. The portion of the CGC System downstream of the secondary containment isolation valves, including the purge air filter package does not support intended functions and is not in scope for license renewal.The CGC System boundary also includes the piping from inside the drywell to the hydrogen recombiner packages and back to the suppression chamber air space. Also included is the piping from the Residual Heat Removal System to the hydrogen recombiner packages and loop seals on the discharge of the hydrogen recombiners, including fill connections from the Condensate System and drain connections to the Plant Drainage System.All associated piping, components and instrumentation contained within the boundary described above are also included in the CGC System scoping boundary.Also included in the CGC System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the CGC System scoping boundary are the primary containment hydrogen and oxygen analyzers and pressure monitoring instrumentation, including piping connected to CGC System piping, which are evaluated with the Process Sampling and Post Accident Monitoring System. The fire suppression deluge valves for the charcoal filters in the purge air filter train are evaluated with the Fire Protection System. The four vacuum relief valves and associated piping that connects the drywell and suppression chamber air space and all drywell and suppression chamber penetrations with connections to CGC System piping and components are evaluated with the Primary Containment structure.
LaSalle County Station, Units 1 and 2 2.3-43 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Reason for Scope Determination The Combustible Gas Control System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Combustible Gas Control System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Combustible Gas Control System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49) and Station Blackout (10 CFR 50.63). The Combustible Gas Control System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48) and Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provide primary containment boundary.
The Combustible Gas Control System includes piping and isolation valves that form the primary containment boundary.
10 CFR 54.4(a)(1)
: 2. Provide secondary containment boundary.
The Combustible Gas Control System includes piping and isolation valves in the primary containment vent and purge flowpaths that form the secondary containment boundary.
10 CFR 54.4(a)(1)
: 3. Provide emergency heat removal from primary containment and provide containment pressure control. The Combustible Gas Control System includes flow paths from primary containment that are used to vent primary containment for pressure control. 10 CFR 54.4(a)( 1)4. Control combustible gas mixtures in the primary containment atmosphere.
The Combustible Gas Control System is credited with establishing, and maintaining an inert atmosphere within primary containment during power operation.
The Combustible Gas Control System also includes equipment that provides mixing of the containment atmosphere to prevent combustible mixtures of hydrogen and oxygen from forming following an accident.10 CFR 54.4(a)(1)
: 5. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
Some portions of nonsafety-related piping are relied upon to preserve the structural support intended function of the safety-related piping used for purging, inerting and containment isolation.
Some portions of the discharge and drain piping from the hydrogen recombiners may be liquid filled and have a potential for spatial interaction with safety-related equipment within the Reactor Building.
10 CFR 54.4(a)(2)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The Combustible Gas Control System includes equipment that is environmentally qualified to remain functional during post-accident conditions.
10 CFR 54.4(a)(3)
: 7. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The Combustible Gas Control System includes primary containment isolation valves that are LaSalle County Station, Units 1 and 2 2.3-44 License Renewal Application Section 2 -Scoping and Screening Methodology and Results required to close to mitigate a Station Blackout event. 10 CFR 54.4(a)(3)
UFSAR References 6.2.5 7.3.5 9.4.10 9.5.9 License Renewal Boundary Drawings LR-LAS-M-92, Sheets 1, 2 LR-LAS-M-1 30, Sheets 1, 2 LR-LAS-M-138, Sheets 1, 2 LR-LAS-M-96, Sheets 1, 2 LR-LAS-M-142, Sheets 1, 2 Table 2.3.3-2 Combustible Gas Control System Components Subject to Aging Management Review Component Type Intended Function Blower Housing Pressure Boundary Bolting Mechanical Closure Hoses Pressure Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Structural Integrity Recombiners Pressure Boundary Valve Body Leakage Boundary Pressure Boundary Structural Integrity The aging management review results for these components are provided in: Table 3.3.2-2 Combustible Gas Control System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-45 Section 2 -Scoping and Screening Methodology and Results 2.3.3.3 Compressed Air System Description The Compressed Air System (CAS) is a normally operating system designed to provide compressed air for station use. The CAS is in scope for license renewal. However, portions of the CAS are not required to perform intended functions and are not in scope.The CAS is primarily a nonsafety-related system that is designed for continuous operation.
The CAS is composed of two subsystems, the service air plant system and the instrument air plant system. The service air subsystem supplies compressed air for operating pneumatic equipment, air operated controls, maintenance services, and interruptible equipment such as tank mixing air spargers.
The instrument air subsystem supplies compressed air for air operated control devices and instruments outside the drywell.A portion of the CAS system performs a safety-related function.
The portion of the service air piping that penetrates Primary Containment and the associated primary containment isolation valves are safety-related components that are relied upon to provide the primary containment boundary.For more detailed information, see UFSAR Section 9.3.1.Boundary The CAS boundary begins at the intake outside the Turbine Building, proceeds through three compressor trains which include intake filters and coolers, and discharges to a common header which supplies the station air receivers.
Compressed air from the receivers is directed to one of three filter and dryer trains, and is then discharged to the instrument air and service air headers where it is distributed throughout the plant for various station uses.The portion of the CAS which is in scope for license renewal is the portion that penetrates Primary Containment and the associated primary containment isolation valves and piping.All associated piping, components, and instrumentation contained within the boundary described above are also included in the CAS System scoping boundary.Also included in the CAS System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor. Included in this boundary are those portions of nonsafety-related piping and equipment relied upon to preserve the structural integrity intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the CAS System scoping boundary are the containment penetrations which are evaluated with the Primary Containment structure.
Not included in the scope of license renewal is the portion of the CAS that is nonsafety-related and is not located in areas where there are potential spatial interactions with components performing safety-related functions, and therefore is not relied upon to perform or support any system intended function.LaSalle County Station, Units 1 and 2 2.3-46 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Reason for Scope Determination The Compressed Air System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Compressed Air System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Compressed Air System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provide primary containment boundary.
The CAS contains safety-related primary containment isolation valves and piping which penetrates the primary containment.
10 CFR 54.4(a)(1)
: 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The CAS includes nonsafety-related piping and components that have the potential for structural interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References 9.3.1.2.1 License Renewal Boundary Drawings LR-LAS-M-82, Sheets 3, 5 Table 2.3.3-3 Compressed Air System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Piping, piping components, and piping Pressure Boundary elements Structural Integrity Valve Body Pressure Boundary Structural Integrity The aging management review results for these components are provided in: Table 3.3.2-3 Compressed Air System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 23-47 Section 2 -Scoping and Screening Methodology and Results 2.3.3.4 Control Rod Drive System Description The Control Rod Drive (CRD) System is a normally operating, high pressure hydraulic system designed to rapidly insert all control rods into the core in response to manual or automatic signals from the Reactor Protection System or the plant alternate rod insertion (ARI) system which is included with the license renewal Reactivity Control System. The CRD System also incrementally positions control rods in response to signals from the plant rod control management system which is included with the license renewal Reactivity Control System.The CRD System is in scope for license renewal. However, portions of the system are not required to perform intended functions and are not in scope.The primary safety-related purpose of the CRD System is to support rapid insertion of negative reactivity into the reactor core to shut down the reactor under accident or transient conditions by simultaneously inserting all control rods. The CRD System is also used to manage core reactivity and control reactor power during normal reactor operation by inserting or withdrawing control rods at a controlled rate, one rod at a time. The CRD System accomplishes these functions by providing water at the required operating pressures to the control rod drive mechanisms in response to inputs from the Reactor Protection System, and the license renewal Reactivity Control System. The CRD System also supplies makeup to the reactor vessel water level reference leg condensing chambers and a low flow rate of cool, clean, high pressure purge water to reactor recirculation pump seals and reactor water cleanup pumps.The CRD System is comprised of the control rod drive hydraulic system including hydraulic control units HCUs), scram discharge volume, and the scram air header.The control rod drive hydraulic system includes two control rod drive water pumps, filters, valves, piping components, and associated instrumentation.
The pumps provide cool clean high pressure water to a flow control station, to the HCUs via the charging water header, the drive water header, and the cooling water header, each at a different pressure.
The control rod drive hydraulic system is arranged so that the equipment supporting each control rod drive mechanism is packaged into modular HCUs, one for each control rod drive mechanism.
The HCUs receive electrical control signals from the Reactivity Control System or Reactor Protection System and direct water to and from the control rod drive mechanisms to move the control rods accordingly.
The charging water header maintains the HCU accumulators charged and ready to support rapid control rod insertion in the event of a scram signal. Stored energy available from the nitrogen charged accumulators and from reactor pressure provide hydraulic energy for rapid simultaneous insertion of control rods. The drive water header provides the control rod drive mechanisms with motive force for positioning the control rods individually to manage core reactivity.
The cooling water header provides a constant flow of water to cool the control rod drive mechanisms to maximize the life of internal seals and maintain acceptable scram insertion times. An exhaust water header interconnects the HCUs to provide a flowpath from the HCU associated with an individual control rod drive mechanism being operated to other HCUs back to the reactor vessel via other control rod drive mechanisms.
The scram air header provides a filtered pneumatic supply to scram inlet and outlet valve actuators via the scram solenoid pilot valves and the scram discharge volume vent and drain valve actuators.
The scram air header is supplied with instrument air from the Compressed Air LaSalle County Station, Units 1 and 2 2.3-48 License Renewal Application Section 2 -Scoping and Screening Methodology and Results System. During a scram, scram solenoid pilot valves de-energize to open scram inlet and outlet valves on each HCU to permit stored energy in the hydraulic control unit accumulators and reactor pressure to supply high pressure water to the drive mechanisms causing the control rods to rapidly insert. Also, solenoid valves on the scram air header energize to isolate it from the instrument air supply system and vent it to atmosphere upon receipt of a scram signal from the Reactor Protection System or via actuation from the plant ARI system.During a scram, each HCU discharges water from the control rod drive mechanisms via the scram outlet valves into the scram discharge volume. The scram discharge volume consists of a header that drains to an instrument volume consisting of a vertical pipe with water level instrumentation.
The scram discharge volume vent and drain valves automatically isolate during a scram to contain potentially contaminated water from the reactor vessel and to maintain vessel inventory.
The scram discharge volume is maintained vented and drained during normal plant operation and following reset of the scram signal.For more detailed information, see UFSAR Section 4.6.Boundary The CRD System scoping boundary includes piping to and from the control rod drive mechanism flanges at the reactor vessel penetrations to the HCUs and back through the scram outlet valves to the scram discharge volume, including the scram instrument volume, level instruments and vent and drain valves. The CRD System scoping boundary also includes the scram air header beginning at the air supply filter and continuing to the back-up scram solenoid valves, solenoid valves actuated by the ARI system, scram solenoid pilot valves located on each HCU, and scram discharge volume vent and drain solenoid valves.Also included within the CRD System is a nitrogen bottle station and piping network that routes pressurized nitrogen to the HCUs that is manually connected to charge the accumulators.
The solenoid valves that operate the scram inlet and outlet valves, scram discharge volume vent and drain valves and vent the scram air header upon actuation from the Reactor Protection System or the plant ARI system have an active safety-related function and are within the scope of license renewal. However, these solenoid valves do not have pressure-retaining or other passive intended function; and therefore are not subject to aging management review.All associated piping, components, and instrumentation contained within the boundary described above are included in the CRD System scoping boundary.Also included in the CRD System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Building and Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the CRD System scoping boundary are the control rod drive housings and stub tubes that are evaluated with the Reactor Vessel System, and the control rod drive LaSalle County Station, Units 1 and 2 2.3-49 License Renewal Application Section 2 -Scoping and Screening Methodology and Results mechanisms and control rod blades that are evaluated with the Reactor Vessel Internals System.Not included in the scope of license renewal is the scram air header which is nonsafety-related, and does not perform or support an intended function.
Not included in the scope of license renewal is the nitrogen bottle station and piping network that routes pressurized nitrogen to the HCUs to charge accumulators which is nonsafety-related, and does not perform or support an intended function.Reason for Scope Determination The Control Rod Drive System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Control Rod Drive System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Control Rod Drive System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Introduce negative reactivity to achieve or maintain subcritical reactor condition.
The HCUs provide the motive force to the control rod drive mechanisms to rapidly insert control rods during a scram event. The scram discharge volume provides a low pressure sink for water discharged from the above piston area of control rod drive mechanisms during a scram event.10 CFR 54.4(a)(1)
: 2. Provide primary containment boundary.
The directional control valves on the HCUs provide containment isolation function from the CRD insert and withdrawal lines. 10 CFR 54.4(a)(1)
: 3. Sense process conditions and generate signals for reactor trip or engineered safety features actuation.
The scram discharge volume includes level instrumentation that causes actuation of the Reactor Protection System upon a high water level condition.
Pressure switches on the charging water header cause actuation of the Reactor Protection System upon a low pressure signal when reactor pressure is low and control rods are withdrawn.
10 CFR 54.4(a)(1)
: 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The CRD System includes nonsafety-related water filled, pressure-retaining piping and equipment within the Reactor Building and Auxiliary Building that have the potential for spatial and structural interaction with safety-related equipment.
10 CFR 54.4(a)(2)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The CRD System includes equipment that is credited by Fire Safe Shutdown analysis to shutdown the reactor via the scram function.
10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 2.3-50 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The CRD System includes instrumentation and equipment that is required to be environmentally qualified.
10 CFR 54.4(a)(3)
: 7. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without SCRAM (10 CFR 50.62). The CRD System includes solenoid valves that receive signals from the plant ARI system to provide an alternate means of venting the scram air header and cause insertion of control rods. 10 CFR 54.4(a)(3)
: 8. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The station blackout analysis credits the CRD System with successfully inserting all control rods upon receipt of scram initiation signals from the Reactor Protection System. 10 CFR 54.4(a)(3)
UFSAR References Table 3.2-1 3.9.4 4.6.1 4.6.2 Table .6.2-21 7.7.2.2 License Renewal Boundary Drawings LR-LAS-M-90, Sheet 3 LR-LAS-M-91, Sheets 5, 6 LR-LAS-M-93, Sheets 1, 2 LR-LAS-M-1 00, Sheets 1, 2, 3, 4, 5 LR-LAS-M-104, Sheet 1 LR-LAS-M-136, Sheet 3 LR-LAS-M-137, Sheets 5, 6 LR-LAS-M-139, Sheets 1, 2 LR-LAS-M-146, Sheets 1, 2, 3, 4, 6 LR-LAS-M-149, Sheet 1 LR-LAS-M-2100, Sheet 2 LR-LAS-M-2146, Sheet 2 LaSalle County Station, Units 1 and 2 2.3-51 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.3-4 Control Rod Drive System Components Subject to Aging Management Review Component Type Intended Function Accumulator Pressure Boundary Bolting Mechanical Closure Drip Pan Leakage Boundary Gearbox (CRD Pump) Leakage Boundary Heat Exchanger
-(CRD Feed Pump Leakage Boundary Bearing and Gear Oil Cooler) Shell Side Components Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (CRD Pump) Leakage Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-4 Control Rod Drive System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-52 Section 2 -Scoping and Screening Methodology and Results 2.3.3.5 Control Room Ventilation
 
===System Description===
The Control Room Ventilation (CRV) system is a normally operating system designed to ensure habitability inside the control rooms and auxiliary electrical equipment rooms during all normal and abnormal station operating conditions.
The CRV ensures that the control room operators are safe against postulated releases of radioactive materials, noxious gases, smoke, and steam. In addition the environment in the control rooms and auxiliary electrical equipment rooms is maintained in order to ensure the integrity of the contained safety-related controls and equipment during all station operating conditions.
The CRV license renewal system consists of the control room area ventilation plant system, the auxiliary electric equipment room ventilation plant system, the refrigeration plant system, and the breathing air plant system. The CRV system is in scope for License Renewal.Control Room Area Ventilation subsystem The purpose of the control room area ventilation plant system is to maintain a habitable environment and to ensure the operability of the safety-related components in the control room, main security control center, control room east area and control room toilet under all station normal and abnormal operating conditions.
These abnormal conditions are ammonia and high radiation detection at outside air intakes, and smoke detection in return air ducts and outside air intake. The system accomplishes this using emergency makeup air filter units and recirculating air filter units, which provide and recirculate clean filtered makeup air in cases where the outside air is contaminated.
The system is designed to Seismic Category I requirements with the exception of heating equipment which is not Seismic Category I, but is seismically supported.
The heating equipment is not essential to the safety of operating personnel or the function of safety-related equipment.
The control room area ventilation plant system is normally provided with filtered outdoor air, at a quantity sufficient to maintain positive pressure compared to surrounding areas at all times except in the recirculation mode. The positive pressure inside the control room precludes infiltration of potentially contaminated air into the conditioned space.Auxiliary Electric Equipment Room Ventilation subsystem The purpose of the auxiliary electric equipment room ventilation plant system is to provide habitability in the auxiliary electric equipment rooms during both normal and abnormal station conditions.
The system accomplishes this by aligning to the same emergency makeup filter units utilized by the control room area ventilation plant system, to provide and recirculate clean filtered makeup air in cases where outside air is contaminated.
The auxiliary electric equipment room ventilation subsystem contains its own recirculating filter units.The system is designed to Seismic Category I requirements with the exception of heating equipment which is not Seismic Category I, but is seismically supported.
The heating equipment is not essential to the safety of operating personnel or the function of safety-related equipment.
The auxiliary electric equipment room ventilation plant system is normally provided with filtered LaSalle County Station, Units 1 and 2 2.3-53 License Renewal Application Section 2 -Scoping and Screening Methodology and Results outdoor air, at a quantity sufficient to maintain positive pressure compared to surrounding areas at all times except in the recirculation mode. The positive pressure inside the equipment rooms precludes infiltration of potentially contaminated air into the conditioned space.Refrigeration subsystems The purpose of the control room and auxiliary electric equipment room refrigeration plant subsystems is to provide cooling for each of the control room area and auxiliary electric equipment room ventilation air handling systems. The systems accomplish this through the use of cooling coils mounted in an air handling unit, a compressor unit, an air cooled condenser, a refrigerant receiver, and interconnected piping and associated equipment.
Breathing Air subsystem The purpose of the breathing air plant system is to provide emergency breathing air to control room personnel.
The system accomplishes this through cylinders with appropriate pressure regulators, low pressure alarms and face masks.For more detailed information, see UFSAR Sections 6.4, 6.5.1, 9.4.1.1, and 9.4.1.2.Boundary The CRV license renewal system boundary begins at the outside air intakes, proceeds through the supply air fan and filter trains to the control and auxiliary equipment rooms, discharges through the return fans back into the supply fan inlet or to the discharge in the Auxiliary Building, and includes the associated ductwork, piping, instrumentation and controls.
The system includes the emergency makeup fan and filter train, the refrigeration system components, and associated ductwork, instrumentation and controls.All associated piping, components, and instrumentation contained within the boundary described above are also included in the CRV System scoping boundary.Also included in the CRV System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the CRV System scoping boundary is the charcoal filter bank fire detection instrumentation and associated deluge valve sprinkler systems support. These components perform a fire protection function, and are evaluated with the Fire Protection license renewal system. Additionally, the fire protection function of fire dampers is evaluated with the Fire Protection System. Also not included in the CRV System scoping boundary is the ventilation intake radiation monitoring instrumentation which is evaluated with the Process Radiation Monitoring license renewal system.LaSalle County Station, Units 1 and 2 2.3-54 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Reason for Scope Determination The Control Room Ventilation System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Control Room Ventilation System is not in scope under 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system would not prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Control Room Ventilation System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63). The Control Room Ventilation System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provide centralized area for control and monitoring of nuclear safety-related equipment.
The primary purpose of the CRV system is to maintain environmental conditions and ensure the safety and comfort of operating personnel in the control room. The system also monitors for the presence of ammonia, radioactive contamination, and smoke; and provides a filtered fresh air supply as necessary in response to these conditions.
10 CFR 54.4(a)(1)
: 2. Maintain emergency temperature limits within areas containing safety-related components.
The CRV system maintains environmental conditions to ensure that the operability of safety-related equipment in the control rooms and auxiliary electric equipment rooms. 10 CFR 54.4(a)(1)
: 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Control Room Ventilation System contains nonsafety-related liquid-filled components, specifically the cooling coil drip pans, which have the potential for spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The CRV system is relied upon to maintain a habitable environment and ensure the operability of safety-related components in the control rooms and auxiliary equipment rooms during a Fire Safe Shutdown event. 10 CFR 54.4(a)(3)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The CRV system contains components that are environmentally qualified.
10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The CRV system is relied upon to maintain a habitable environment and ensure the operability of safety-related components in the control rooms and auxiliary electrical equipment rooms during SBO recovery.
10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 2.3-55 License Renewal Application Section 2 -Scoping and Screening Methodology and Results UFSAR References 1.2.3.6.6 6.4 6.5.1 9.4.1.1 9.4.1.2 7.3.4 6.4.1 .c License Renewal Boundary Drawiniqs LR-LAS-M-1443, Sheets 1, 2, 3, 4 LR-LAS-M-1455, Sheet 1 LR-LAS-M-1468, Sheets 3, 4, 5, 6 LR-LAS-M-1470, Sheet 1 LR-LAS-M-129, Sheets 2, 3 LR-LAS-M-1 51, Sheet 4 LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-56 Section 2 -Scoping and Screening Methodology and Results Table 2.3.3-5 Control Room Ventilation System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Ducting and Components Leakage Boundary Pressure Boundary Flexible Connection Pressure Boundary Heat Exchanger
-(Control Room and Aux Heat Transfer Elec Equip Room HVAC Air-Cooled Condenser)
Fins Heat Exchanger
-(Control Room and Aux Pressure Boundary Elec Equip Room HVAC Air-Cooled Condenser)
Shell Side Components Heat Exchanger
-(Control Room and Aux Heat Transfer Elec Equip Room HVAC Air-Cooled Pressure Boundary Condenser)
Tubes Heat Exchanger
-(Control Room and Aux Heat Transfer Elec Equip Room HVAC Supply Coolers)Fins Heat Exchanger
-(Control Room and Aux Pressure Boundary Elec Equip Room HVAC Supply Coolers)Shell Side Components Heat Exchanger
-(Control Room and Aux Heat Transfer Elec Equip Room HVAC Supply Coolers) Pressure Boundary Tubes Heat Exchanger
-(Control Room and Aux Pressure Boundary Equip Room HVAC Refrigerant Compressor Oil Cooler) Shell Side Components Heat Exchanger
-(Control Room and Aux Heat Transfer Equip Room HVAC Refrigerant Pressure Boundary Compressor Oil Cooler) Tubes Piping, piping components, and piping Pressure Boundary elements Tanks (Control Room and Aux Elec Equip Pressure Boundary Room HVAC Refrigerant Receiver)Valve Body Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-5 Control Room Ventilation System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-57 Section 2 -Scoping and Screening Methodology and Results 2.3.3.6 Cranes, Hoists and Refueling Equipment
 
===System Description===
The Cranes, Hoists and Refueling Equipment System is a standby system comprised of load handling bridge cranes, jib cranes, lifting devices, monorails, and hoists provided throughout the facility designed to support operation and maintenance activities.
Also included are equipment that handles fuel and other light loads above fuel and other safety-related components in support of reactor refueling.
The Cranes, Hoists and Refueling Equipment System is in scope for license renewal. However, portions of the Cranes, Hoists and Refueling Equipment System are not required to perform intended functions and are not in scope.The purpose of the Cranes, Hoists and Refueling Equipment System is to safely move material and equipment to support operations and maintenance activities.
The Cranes, Hoists and Refueling Equipment System accomplishes this through compliance with NUREG-0612 and administrative controls such that damage from a postulated heavy load drop does not prevent safe shutdown of the reactor.The reactor building crane services the common refueling floor for both units, and is used to lift heavy loads including the drywell head, the reactor vessel head, vessel internals, and spent fuel casks. The reactor building crane is safety-related, designed to be single failure proof in conformance with NUREG-0554 and NUREG-0612, and is designed as Seismic Category 1.Included in the Cranes, Hoists and Refueling Equipment System are load handling systems throughout the facility.
Cranes and hoists that handle loads over safety-related systems, structures and components are in scope for license renewal. Postulated failure of these cranes and hoists could impact a safety-related function.
As a result, the reactor building crane, approximately 60 cranes and hoists, and numerous rigging beams are in scope for license renewal.The refueling platform for each unit; including the fuel grapple hoist, frame mounted hoist, and trolley mounted hoist that are mounted on each refueling platform which are used to handle fuel and other light loads over the spent fuel pool and over the reactor vessel during refueling are in scope for license renewal. The scorpion work platform with installed jib cranes is also used to support refueling operations, handle light loads over the reactor cavity, and is therefore in scope. Also included in scope for license renewal are the fuel preparation machines that are mounted on the wall of each spent fuel pool. The fuel preparation machines are used to handle new and irradiated fuel bundles and remove and install fuel channels.For more detailed information, refer to UFSAR Section 9.1.4 and Appendix 0.Boundary The Cranes, Hoists and Refueling Equipment System scoping boundary includes all the cranes, hoists, rigging beams on the LaSalle County Station site. Also included is equipment used to move fuel, service the reactor vessel and internal components, and tools associated with refueling operations.
The cranes, hoists, rigging beams and refueling equipment that have the potential to handle loads above safety-related components or fuel, as described in the system description, are within the scope of license renewal.The concrete and steel structures that provide structural support for crane and hoist LaSalle County Station, Units 1 and 2 2.3-58 License Renewal Application Section 2 -Scoping and Screening Methodology and Results components are evaluated with the structure that supports the crane or hoist.The scoping boundary for in scope cranes, hoists and refueling equipment is limited to load bearing structural components such as the bridge, trolley, rail system (rails and rail fasteners), structural bolts, monorail beams, and jib crane structural members. Cranes, hoists, and refueling equipment that do not have the potential to handle loads over safety-related components or fuel are not included in the scope of license renewal. Equipment used to service and inspect fuel and reactor vessel and internal components, including engineered tools that are suspended from cranes or hoists is not included in the scope of license renewal.Reason for Scope Determination The Cranes, Hoists and Refueling Equipment System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Cranes, Hoists and Refueling Equipment System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Cranes, Hoists and Refueling Equipment System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provides physical support, shelter and protection for safety-related systems, structures, and components.
The reactor building crane is safety-related, seismically qualified, and is used to transport heavy loads over irradiated fuel and above or near safety-related components.
10 CFR 54.4(a)(1)
: 2. Provides a safe means for handling safety-related components and loads above or near safety-related components.
The Cranes, Hoists and Refueling Equipment System components within the scope of license renewal handle equipment or fuel above or near safety-related components or spent fuel. 10 CFR 54.4(a)(2)
: 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The nonsafety-related cranes, hoists and refueling equipment that are in scope provide a safe means for handling loads above or near safety-related components.
10 CFR 54.4(a)(2)
UFSAR References
 
====9.1.4 Appendix====
0 Table 3.2-1 License Renewal Boundary Drawings None.LaSalle County Station, Units 1 and 2 2.3-59 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.3-6 Cranes, Hoists and Refueling Equipment System Components Subject to Aging Management Review Component Type Intended Function Bolting Structural Integrity Crane/Hoist Structural Integrity (BridgelG irderslT rolle y Beaml Jib Boom)Crane/Hoist (Fuel Prep Machine) Structural Integrity Crane/Hoist (Rail Systems) Structural Integrity Crane/Hoist (Refueling Platform)
Structural Integrity Crane/Hoist (Scorpion Work Platform)
Structural Integrity The aging management review results for these components are provided in: Table 3.3.2-6 Cranes, Hoists and Refueling Equipment System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-60 Section 2 -Scoping and Screening Methodology and Results 2.3.3.7 Demineralized Water Makeup System Description The intended function of the Demineralized Water Makeup System for license renewal is to maintain leakage boundary integrity to preclude system interactions.
For this reason, this system's pressure-retaining components located in areas where there is potential spatial interaction with components performing safety-related functions have been included in the scope of license renewal. This system is not required to operate to support license renewal intended functions, and is in scope only for potential spatial interaction.
The Demineralized Water Makeup System is a normally operating system designed to provide water from on-site wells, purify the stored well water, and provide it for various uses throughout the plant, including potable and domestic use and high purity reactor grade water for makeup to the clean and cycled condensate storage tanks and various plant systems. The Demineralized Water Makeup System consists of the following plant systems: domestic water, makeup demineralizer, and well water. The Demineralized Water Makeup System is in scope for license renewal. However, portions of the Demineralized Water Makeup system are not required to perform or support intended functions and are not included in the scope of license renewal.Well Water System The purpose of the well water system is to provide a source of ground water to supply plant needs. The well water system accomplishes this by pumping water from two on-site deep wells, filtering the water through trailer mounted sand filters to remove iron, manganese, and suspended matter, for storage in the 350,000 gallon well water storage tank.Makeup Demineralizer System The purpose of the makeup demineralizer system is to purify the water stored in the well water storage tank and make it suitable for use for makeup to the clean and cycled condensate storage tanks. The makeup demineralizer system accomplishes this by using trailer mounted demineralizers and filters to purify water to meet reactor grade water quality requirements.
A portion of the original demineralized water makeup system is abandoned in place and the regeneration capability of the makeup demineralizers has been removed.Domestic Water System The purpose of the domestic water system is to provide potable water for domestic use on site. The domestic water system accomplishes this by processing water from the well water storage tank. Water for domestic consumption is chlorinated and filtered to meet drinking water standards.
For more detailed information see UFSAR Sections 1.2.3.6.4, 2.4.13.1.3, 9.2.4, and 9.2.5.Boundary The license renewal scoping boundary of the Demineralized Water Makeup System encompasses the liquid filled portions of nonsafety-related piping and equipment located in areas where there is potential spatial interaction with safety-related equipment.
This includes LaSalle County Station, Units 1 and 2 2.3-61 License Renewal Application Section 2 -Scoping and Screening Methodology and Results the nonsafety-related portions of the system located within the Reactor Buildings and the Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this system. This includes the demineralized water supply line to the Nonessential Cooling Water System clean gland water storage tank and HVAC evaporative coolers and humidifiers in the Auxiliary Building and the domestic water distribution piping in the Reactor Buildings and Auxiliary Building.
For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.The cycled condensate storage tanks are evaluated with the Condensate license renewal system. The inactive portions of the system that do not perform or support an intended function and are not located in areas where there are potential spatial interactions with components performing safety-related functions, are not included in the scope of license renewal.Reason for Scope Determination The Demineralized Water Makeup System is not in scope under 10 CFR 54.4(a)(1) because no portions of the system are safety-related or relied upon to remain functional during and following design basis events. The Demineralized Water Makeup System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Demineralized Water Makeup System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), or Station Blackout (10 CFR 50.63).Intended Functions 1. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Demineralized Water Makeup System contains nonsafety-related liquid-filled lines in the Reactor Building and Auxiliary Building which have potential spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References 1.2.3.6.4 2.4.13.1.3 9.2.4 9.2.5 9.4.3.4.2 9.4.4.2 10.4.7.2 LaSalle County Station, Units 1 and 2 2.3-62 License Renewal Application Section 2 -Scoping and Screening Methodology and Results License Renewal Boundary Drawinas LR-LAS-M-76, Sheet 4 LR-LAS-M-77, Sheet 1 LR-LAS-A-615, Sheet 1 LR-LAS-A-616, Sheet 1 LR-LAS-A-617, Sheet 1 LR-LAS-A-595, Sheet 1 LR-LAS-M-1455, Sheet 1 LR-LAS-M-1456, Sheet 1 LR-LAS-M-1459, Sheet 1 LR-LAS-M-1460, Sheet 1 Table 2.3.3-7 Demineralized Water Makeup System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Heat Exchanger
-(Electric Hot Water) Leakage Boundary Shell Side Components Heat Exchanger- (Steam Generator)
Shell Leakage Boundary Side Components Piping, piping components, and piping Leakage Boundary elements Pump Casing (Evaporative Cooler) Leakage Boundary Valve Body Leakage Boundary The aging management review results for these components are provided in: Table 3.3.2-7 Demineralized Water Makeup System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-63 Section 2 -Scoping and Screening Methodology and Results 2.3.3.8 Diesel Generator and Auxiliaries
 
===System Description===
The Diesel Generator and Auxiliaries System is a standby system designed to provide sufficient electrical power to important plant equipment when normal offsite power sources are not available.
The Diesel Generator and Auxiliaries System consists of the following plant systems: diesel generator system, diesel oil transfer system, fire seals and fuel storage, and the technical support center diesel. The Diesel Generator and Auxiliaries System also includes the security diesel. The Diesel Generator and Auxiliaries System is in scope for license renewal. However, portions of the Diesel Generator and Auxiliaries System are not required to perform intended functions and are not included in the scope of license renewal.The purpose of the Diesel Generator and Auxiliaries System is to provide a source of electrical power which is not dependent on off-site sources and which is capable of supplying sufficient power to those electrical loads which are required to support the simultaneous safe shutdown of both units, coincident with a loss-of-coolant accident on one unit. The Diesel Generator and Auxiliaries System is designed for physical separation and redundancy such that no single active failure can prevent the system from performing its safety-related function, and to remain functional during and following a SSE seismic event. The Diesel Generator and Auxiliaries System utilizes five diesel engines to power electric generators.
The system includes two diesel generators for each LaSalle unit, and a diesel generator that can be aligned to busses that supply power to loads on both units. One of the diesel generators for each unit has the primary purpose to supply emergency power to the high pressure core spray (HPCS) pump motor.Each diesel generator is located in a separate room that is equipped with an independent ventilation system that provides combustion air and removes heat from equipment in the room to assure reliable operation of the diesel generator and associated equipment.
The ventilation system is evaluated for license renewal under the Safety-Related Ventilation System. The design of the rooms prevents the possibility of a missile or explosion, or a fire affecting one diesel generator, from affecting another diesel generator.
Each diesel generator includes self-contained auxiliary support systems that include starting air, closed cooling water, engine lubricating oil, combustion air intake and exhaust, and diesel fuel oil storage and transfer.The starting air system consisting of two independent starting air subsystems that supply pressurized air to pneumatic starting motors that roll the engine until it starts. The safety function of the starting air auxiliary system is to provide for reliable starting of the diesel generators.
The combustion air intake system provides combustion air that is adequately filtered and at the proper temperature and pressure.
The exhaust system discharges exhaust gases outside of the diesel room to support continuous engine operation at full load. The auxiliary closed cooling water system provides cooling to the engine cylinder jackets, lube oil, and combustion air to support continuous engine operation under all loading conditions.
Heat is rejected from the closed cooling water system by the diesel generator cooling water pumps that circulate water from the cooling lake through the closed cooling water heat exchangers.
The lubrication oil system provides a continuous flow of filtered lube oil to diesel engine components at a controlled pressure and temperature to support all engine functions.
The lube oil system consists of four subsystems; the main lube oil system, scavenging oil system, piston cooling system, and oil circulating and soak-back system. The main lube oil system supplies pressurized oil to various moving parts within the engine, including the turbocharger.
LaSalle County Station, Units 1 and 2 2.3-64 License Renewal Application Section 2 -Scoping and Screening Methodology and Results The scavenging oil system provides cooled and filtered oil to the main lube oil and piston cooling systems. The piston cooling system supplies pressurized oil to the piston pin bearings and cylinders.
The oil circulating and soak-back system supplies warm oil during standby conditions to engine components in support of rapid engine start and loading.The fuel oil storage, transfer and delivery system provides a sufficient volume of clean, high quality fuel to support seven days of continuous operation following all design bases accidents.
The fuel oil system also includes the fuel storage, transfer and delivery system for the two diesel-driven fire pumps that is interconnected to the HPCS diesel storage tanks. The fuel oil system for the fire pumps is nonsafety-related but supports compliance with regulations for Fire Protection by supporting the distribution of water used for suppression of fires.The fuel oil system also includes the fuel storage, transfer, and delivery system for the security diesel generator and Technical Support Center diesel generator.
These fuel oil systems are independent of the fuel oil systems that supply fuel to the five emergency diesel generators and the diesel-driven fire pumps.For more detailed information, see UFSAR Sections 7.3.6, 8.3.1 and 9.5.4 through 9.5.8.Boundary The Diesel Generator and Auxiliaries System license renewal scoping boundary encompasses the five diesel engines that provide a source of electrical power which is not dependent on off-site sources and are required to support the simultaneous safe shutdown of both units, including components within the following auxiliary system flow paths for each engine: starting air, combustion air intake and exhaust, cooling water, engine lubricating oil, and diesel fuel oil storage and transfer.There are two redundant starting air systems for each diesel engine. Each redundant starting air system scoping boundary begins at the air compressor and continues through the moisture separator, air dryer and check valve to two air receiver tanks. The air compressors, moisture separators and air dryers are nonsafety-related.
The check valve and flow path through the air receivers to the engine are safety-related.
The scoping boundary continues from the air receivers through a pressure regulator valve, strainer, air start solenoid valve, to two pneumatic starting motors. The pneumatic starting motors are part of the complex active diesel engine assembly, and are therefore not subject to aging management review. All associated piping, components, and instrumentation contained within the described flow path are included in the system evaluation boundary.The combustion air intake system scoping boundary begins at the air intake filter located downstream of the inlet louver bank associated with the diesel room ventilation system. The scoping boundary continues to a flexible hose to the diesel engine. The diesel exhaust system scoping boundary begins at the diesel engine and continues through an expansion bellows, exhaust silencer, and exhaust pipe to a screen grating above the diesel room roof.The closed cooling water system scoping boundary begins at the engine cooling water heat exchanger and continues through the lube oil cooler through the engine-driven cooling water pumps to the engine water inlet manifolds and turbocharger aftercoolers.
The scoping boundary continues from the engine to a temperature regulating valve back to the engine cooling water heat exchanger.
An expansion tank, immersion heater, and all associated piping, components, and instrumentation contained within the described flow path are included LaSalle County Station, Units 1 and 2 2.3-65 License Renewal Application Section 2 -Scoping and Screening Methodology and Results in the system evaluation boundary.
The engine-driven cooling water pumps, engine water inlet manifolds, and aftercoolers are part of the complex active diesel engine assembly, and are therefore not subject to aging management review.The lubricating oil system consists of four subsystems; the main lube oil system, scavenging oil system, piston cooling system, and oil circulating and soak-back system. The main oil lubrication system scoping boundary begins at the lube oil strainer tank and continues through a strainer, to the engine-driven main oil pump to the main lube oil manifold and through the turbocharger filter assembly to the turbocharger, and to the engine sump. The scavenging oil system scoping boundary begins at the engine sump and continues through a strainer to the engine-driven scavenging oil pump, through a filter, the lube oil cooler and to the lube oil strainer tank. The piston cooling system scoping boundary begins at the suction piping to the main oil pump and continues to the engine-driven piston cooling oil pump and to the engine.The oil circulating and soak-back system scoping boundary begins at the engine sump and continues to the AC motor- powered circulating oil pump, soak-back oil pump, and DC motor-powered backup soak-back oil pump. The scoping boundary continues downstream of the circulating oil pump to the discharge of the scavenging oil pump filter, and to a common header with the soak-back pumps, through the soak-back filter, and to the turbocharger bearings.
The engine-driven main, scavenging and piston cooling oil pumps, lube oil manifold, turbocharger filter assembly, turbocharger, and engine sump are part of the complex active diesel engine assembly, and are therefore not subject to aging management review. All associated piping, components, and instrumentation contained within the described flow path are included in the system evaluation boundary.The diesel fuel oil storage and transfer system scoping boundary begins at the fill line to the diesel fuel storage tank for each engine and continues through a strainer to the fuel oil storage tank. The scoping boundary continues from the fuel oil storage tank through a strainer to a fuel transfer pump to the diesel generator day tank. The scoping boundary continues from day tank through a strainer to the fuel pump and through a duplex filter to the fuel injectors associated with the diesel engine. The strainer in the suction to the fuel pump, fuel pump, duplex filter, and fuel injectors are part of the complex active diesel engine assembly, and are therefore not subject to aging management review. All associated piping, components, and instrumentation contained within the described flow path are included in the system evaluation boundary.The diesel fuel oil storage and transfer system scoping boundary for the diesel-driven fire pumps begins at the HPCS diesel fuel storage tank and continues through a strainer to a fuel transfer pump to the diesel fire pump day tank. The scoping boundary continues from day tank to the diesel engine. All associated piping, components, and instrumentation contained within the described flow path are included in the system evaluation boundary.The diesel fuel oil storage and transfer system scoping boundary for the security diesel and Technical Support Center diesel begins at the common fuel storage tank fill connection and continues to the fuel storage tank, security diesel day tank, Technical Support Center diesel day tank, and to the security diesel engine and the Technical Support Center diesel engine.All associated piping, components, and instrumentation contained within the described flow path are included in the system evaluation boundary.Also included in the Diesel Generator and Auxiliaries System license renewal scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related to nonsafety-related interface up to the location of the first seismic anchor. This LaSalle County Station, Units 1 and 2 2.3-66 License Renewal Application Section 2 -Scoping and Screening Methodology and Results includes the nonsafety-related portions of the system located in the diesel rooms. Also included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the Diesel Generator and Auxiliaries System scoping boundary is the diesel room ventilation system which is evaluated with the Safety-Related Ventilation System.Not included in the Diesel Generator and Auxiliaries System scoping boundary are the diesel generator cooling water pumps and the tube side of the engine cooling water heat exchanger which are evaluated with the Essential Cooling Water System.Not included in the Diesel Generator and Auxiliaries System scoping boundary are the diesel-driven fire pump engines and components not associated with the fuel oil supply system which are evaluated with the Fire Protection System.Not included in the scope of license renewal are the components associated with the security and Technical Support Center diesels and fuel oil systems since they do not perform or support an (a)(1) or (a)(3) intended function, and are not connected to or located in areas where there are potential spatial interactions with safety-related components.
Reason for Scope Determination The Diesel Generator and Auxiliaries System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Diesel Generator and Auxiliaries System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Diesel Generator and Auxiliaries System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63). The Diesel Generator and Auxiliaries System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provide motive power to safety-related components.
The Diesel Generator and Auxiliaries System is required to power safety-related equipment in the event normal offsite power sources are not available.
10 CFR 54.4(a)(1)
: 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Diesel Generator and Auxiliaries System includes nonsafety-related fluid filled lines in the diesel rooms that have the potential for spatial interactions with safety-related SSCs. The starting air system includes nonsafety-related piping that is in scope to provide a seismic anchor credited for structural support of safety-related piping. 10 CFR 54.4(a)(2)
: 3. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The LaSalle County Station, Units 1 and 2 2.3-67 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Diesel Generator and Auxiliaries System provides an alternate power source required to cope with a station blackout event to support safe shutdown and decay heat removal for the blacked out unit for the required coping duration.
10 CFR 54.4(a)(3)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Diesel Generator and Auxiliaries System provides power to safe shutdown equipment in the event of a loss of offsite power coincident with the postulated fire for several analyzed Fire Safe Shutdown methods. The Diesel Generator and Auxiliaries System also provides the fuel oil supply to the diesel-driven fire water pumps that support the distribution of water used for fire suppression.
10 CFR 54.4(a)(3)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The Diesel Generator and Auxiliaries System includes safety-related components located within areas of the plant that may have harsh environments, and therefore have environmental qualifications.
10 CFR 54.4(a)(3)
UFSAR References Table 3.2-1 7.3.6 8.3.1 9.5.4 through 9.5.8 License Renewal Boundary Drawings LR-LAS-M-83, Sheets 1, 2, 3, 4 LR-LAS-M-85, Sheet 1 LR-LAS-M-132, Sheet 1 LR-LAS-M-1 05, Sheet 3 LR-LAS-M-1 50, Sheet 2 LR-LAS-M-EDGECW, Sheet 1 LaSalle County Station, Units 1 and 2 2.3-68 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.3-8 Diesel Generator and Auxiliaries System Components Subject to Aging Management Review Component Type Intended Function Air Dryer (Housing)
Structural Integrity Bird Screen Filter Bolting Mechanical Closure Electric Heaters (Housing)
Pressure Boundary Expansion Joints Pressure Boundary Flame Arrestor Pressure Boundary Flow Device Pressure Boundary Throttle Heat Exchanger
-(DIG Cooler) Shell Side Pressure Boundary Components Heat Exchanger
-(D/G Cooler) Tube Pressure Boundary Sheet Heat Exchanger
-(D/G Cooler) Tubes Heat Transfer Pressure Boundary Heat Exchanger
-(Lube Oil Cooler) Shell Pressure Boundary Side Components Heat Exchanger
-(Lube Oil Cooler) Tube Pressure Boundary Sheet Heat Exchanger
-(Lube Oil Cooler) Tube Pressure Boundary Side Components Heat Exchanger
-(Lube Oil Cooler) Heat Transfer Tubes Pressure Boundary Hoses Pressure Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Structural Integrity Pump Casing (Fuel Oil Transfer)
Pressure Boundary Pump Casing (Lube Oil) Pressure Boundary Silencer/Muffler Pressure Boundary Strainer Element Filter Tanks (Air Receivers)
Pressure Boundary Tanks (Closed Cooling Water Expansion Pressure Boundary Tanks)Tanks (Fuel Oil Storage and Day Tanks) Pressure Boundary Tanks (Lube Oil Strainer Tank) Pressure Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-8 Diesel Generator and Auxiliaries System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-69 Section 2 -Scoping and Screening Methodology and Results 2.3.3.9 Drywell Pneumatic
 
===System Description===
The Drywell Pneumatic System (DPS) is a normally operating system designed to provide a safety-related supply of gas to pneumatic devices that are essential for safe plant shutdown following a design basis accident.
The DPS also is designed to provide a nonsafety-related supply of gas of suitable quality and pressure for operation of pneumatic devices and for purging of the traversing incore probe (TIP) indexing mechanisms located inside the primary containment during normal operation.
The DPS is in scope for license renewal. However, portions of the DPS do not perform intended functions and are not in the scope of license renewal.The purpose of the DPS is to provide a supply of gas for operation of pneumatic devices and for purging of the TIP indexing mechanisms located inside the primary containment.
The DPS accomplishes this by drawing gas from inside the primary containment and processing it through filters, compressors, coolers, separators, dryers, and receivers prior to distributing the gas to users inside the primary containment.
The DPS includes individual safety-related accumulators of sufficient capacity to provide for the operation of the main steam isolation valves, main steam safety/relief valves, and ADS valves in the event of a loss of the normal nonsafety-related gas supply. The DPS also includes a safety-related backup compressed gas system for the ADS accumulators consisting of two compressed nitrogen bottle banks and an emergency pressurization station which provide a long term pneumatic supply to the ADS valves to support post-accident reactor decay heat removal.The DPS lines that penetrate the primary containment are provided with safety-related containment isolation valves. All lines penetrating the primary containment, with the exception of the bottled nitrogen to the ADS valve accumulators, are isolated upon a containment isolation signal.The DPS contains components that are environmentally qualified.
The function of providing gas for ADS valve operation is credited for Fire Safe Shutdown and Station Blackout coping.For more detailed information see UFSAR Section 9.3.1.Boundary The DPS license renewal scoping boundary begins at the gas intake inside primary containment and continues through primary containment isolation valves, filters, an inter-cooler, compressor, after-cooler, separator, dryer, and receivers.
The boundary continues through primary containment isolation valves to various users in the primary containment including the TIP indexing mechanisms, main steam isolation valve accumulators, main steam safety/relief valve accumulators, ADS valve accumulators, sample valves and pump seal water valves associated with the reactor recirculation system, and testable check valves associated with the reactor core isolation cooling (RCIC) system.Included in the DPS license renewal scoping boundary is the ADS accumulator backup compressed gas supply. This boundary begins at the bottle banks and gas manifolds and continues through primary containment isolation valves to the ADS accumulators.
One bottle bank supplies four of the seven ADS accumulators while the other serves the remaining three ADS accumulators.
Each bottle bank includes a reserve bottle which is placed in service LaSalle County Station, Units 1 and 2 2.3-70 License Renewal Application Section 2 -Scoping and Screening Methodology and Results during bottle replacement and an emergency pressurization station so that each ADS gas line can be recharged indefinitely via nitrogen bottles brought to that point.All associated piping, components and instrumentation contained within the boundary described above are also included in the DPS scoping boundary.Also included in the DPS scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Buildings.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. Also included in the DPS scoping boundary are those gas filled portions of nonsafety-related piping and equipment that extend beyond the safety-related to nonsafety-related interface up to the location of the first seismic anchor.Included in this boundary are components relied upon to preserve the structural support intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the DPS scoping boundary are the TIP indexing mechanisms which are evaluated with the Traversing Incore Probe System.Not included in the scope of license renewal are non-liquid filled portions of the DPS. This includes portions of the system that have been abandoned in place and verified to not present a spatial interaction with safety-related SSCs.Reason for Scope Determination The Drywell Pneumatic System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Drywell Pneumatic System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Drywell Pneumatic System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63). The Drywell Pneumatic System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provide primary containment boundary.
The DPS includes safety-related containment isolation valves. 10 CFR 54.4(a)(1)
: 2. Provide motive power to safety-related components.
The DPS provides a supply of gas for operation of the main steam isolation valves, main steam safety/relief valves, and Automatic Depressurization System (ADS) valves following a design basis accident.
10 CFR 54.4(a)(1)
: 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The DPS contains nonsafety-related water filled lines in the Reactor LaSalle County Station, Units 1 and 2 2.3-71 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Building which have potential spatial interactions with safety-related SSCs. The DPS also contains nonsafety-related gas filled lines relied upon to preserve the structural support intended function of the system. 10 CFR 54.4(a)(2)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The function of providing gas for ADS valve operation is credited for Fire Safe Shutdown.
10 CFR 54.4(a)(3)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The DPS contains components that are environmentally qualified.
10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The function of providing gas for ADS valve operation is credited for Station Blackout coping. 10 CFR 54.4(a)(3)
UFSAR References Table 3.2-1 5.2.2.4.2.1.2 Table 6.2-21 Figure 6.2-31 Table 6.2-28 Table 7.5-1 7.7.6.4 9.3.1 License Renewal Boundary Drawinas LR-LAS-M-66, Sheets 1, 2, 3, 4, 5, 7, 8, 9, 10, 11 Table 2.3.3-9 Drywell Pneumatic System Components Subject to Aging Management Review Component Type Intended Function Accumulator Pressure Boundary Bolting Mechanical Closure Compressor Housing Leakage Boundary Hoses Leakage Boundary Pressure Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Structural Integrity Strainer Element Filter Valve Body Leakage Boundary Pressure Boundary Structural Integrity LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-72 Section 2 -Scoping and Screening Methodology and Results The aging management review results for these components are provided in: Table 3.3.2-9 Drywell Pneumatic System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 2.3-73 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 2.3.3.10 Electrical Penetration Pressurization
 
===System Description===
The Electrical Penetration Pressurization (EPP) System is a standby system designed to provide a means to manually supply nitrogen to electrical penetration assemblies for Unit 2.The EPP license renewal system is in scope for license renewal. However, portions of the EPP System are not required to perform intended functions and are not included in the scope of license renewal.The electrical penetration assemblies provide continuity of electric circuits through the containment building wall, while maintaining containment integrity.
The assemblies are pressurized internally with nitrogen, to minimize moisture intrusion and condensation.
This ensures that the connected electrical equipment performs as required, and ensures containment leak-tightness.
The EPP system consists of piping, valves and pressure instrumentation which connect to these penetrations to monitor the penetration internal pressure; and a permanently connected external pressurization source of nitrogen to allow for manual makeup nitrogen if needed. Portions of the EPP system connect to the penetrations and have been classified as safety-related.
However, nitrogen pressurization is not required to maintain the qualification of the penetration.
The EPP system is applicable to Unit 2 only. The Unit 1 electrical penetration design allows for nitrogen supply through local nitrogen bottles, and does not utilize a permanently connected external pressurization source of nitrogen.For more detailed information, see UFSAR Sections 6.2.6.2, 3.8.1.1, and Table 3.2-1.Boundary The EPP System license renewal scoping boundary starts at the branch connection off the low flow nitrogen makeup to the primary containment, and continues to the Unit 2 electrical penetrations.
The EPP System includes piping, valves and components which can supply supplemental nitrogen for penetration pressurization if required, and flexible connections between the safety-related and the nonsafety-related components.
The EPP System also contains pressure instruments at each electrical penetration to monitor penetration pressure, and a test connection for leak rate testing. The components within the scope of license renewal consist of the safety-related components in the system, specifically the pressure instrument and test connection at each penetration, and the nitrogen supply piping and valves between the electrical penetrations and the flexible connections.
Not included in the EPP System scoping boundary are the electrical penetrations which are part of the primary containment, and are evaluated with the Primary Containment structure for license renewal.Not included in the scope of license renewal are the nonsafety-related piping and components in the nitrogen supply portion of the system. These components do not perform or support an intended function, and are therefore not included in the scope of license renewal.LaSalle County Station, Units 1 and 2 2.3-74 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Reason for Scope Determination The Electrical Penetration Pressurization System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Electrical Penetration Pressurization System is not in scope under 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system would not prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Electrical Penetration Pressurization System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provide primary containment boundary.
The EPP System components connect directly to the Unit 2 electrical penetration assemblies and have the potential for structural interaction with them. 10 CFR 54.4(a)(1)
UFSAR References 6.2.6.2 3.8.1.1 Table 3.2-1 Figure 3.8-21 License Renewal Boundary Drawings LR-LAS-M-148, Sheet 1 Table 2.3.3-10 Electrical Penetration Pressurization System Components Subject to Aging Management Review Component Type Intended Function Piping, piping components, and piping Pressure Boundary elements Valve Body Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-10 Electrical Penetration Pressurization System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 2.3-75 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 2.3.3.11 Essential Cooling Water System Description The Essential Cooling Water (ECW) System is a standby system designed to circulate lake water from the ultimate heat sink to the Residual Heat Removal (RHR) System heat exchangers, diesel generator coolers, core standby cooling system area coolers, Low Pressure Core Spray (LPCS) System pump motor cooling coils, and RHR pump seal coolers.The purpose of the ECW System is to provide cooling water to the RHR heat exchangers, diesel generator coolers, core standby cooling system cubicle area coolers, RHR pump seal coolers, and LPCS pump motor coolers. The ECW System accomplishes this function by circulating cooling water from the ultimate heat sink to the component coolers and returning the heated water to the ultimate heat sink. Strainers are provided upstream of the component coolers to prevent plugging of the cooled component heat transfer passages.This system also provides a source of emergency makeup water for fuel pool cooling and also provides containment flooding water for post-accident recovery.
The ECW System accomplishes these functions by providing water from the ultimate heat sink to the spent fuel pool emergency makeup pumps and requires installation of a pipe spool piece which is normally installed on the emergency makeup pump test line. Flooding of the containment is accomplished by providing water from the ultimate heat sink to the containment through pipe spool sections that are normally disconnected and stored and only installed when needed.The ECW System is normally not in operation and is placed in service during operation of emergency core cooling systems and the emergency diesel generators.
The RHR service water portion of the system is required to operate during all unit shutdowns to remove core residual heat and following a LOCA to provide containment cooling. The diesel generator cooling water portions of the system are required any time the diesel generators are operated or when the LPCS System pumps are operated.
The core standby cooling system cubicle area coolers require cooling water only when the core standby cooling system pumps are operating and the normal Reactor Building ventilation systems are not functioning.
The ECW System pumps take suction from the service water tunnel located in the basement of the Lake Screen House. Traveling screens on the inlet to the service water tunnel prevent large pieces of debris from entering the system and blocking flow or damaging equipment.
A normally closed bypass around the travelling screens is installed to assure access to a continuous supply of water from the ultimate heat sink in the event that all travelling screens become blocked. A shad net is installed across the Lake Screen House intake flume to deter and prevent Gizzard Shad from intruding into plant components.
Radiation monitors are included downstream of cooled components that contain radioactive fluids to detect potential leakage of radiation to the environment.
ECW System discharge lines from these components are capable of remote manual isolation from the control room.For more detailed information see UFSAR Sections 2.5.5.2.5, 9.2.1, and 9.2.6.Boundary The ECW System license renewal scoping boundary begins with the ultimate heat sink portion of the Cooling Lake and continues through the service water tunnel located in the Lake Screen LaSalle County Station, Units 1 and 2 2.3-76 License Renewal Application Section 2 -Scoping and Screening Methodology and Results House, including the 54-inch travelling screen bypass line. The ECW system piping extends from the service water tunnel, through the ECW pumps and pump discharge strainers, to the components requiring cooling and return piping to the Cooling Lake for each reactor unit. The boundary includes the tube sides of the RHR heat exchangers, shell side of the RHR pump seal coolers, tube side of the diesel generator cooling water coolers, the tube side of the core standby cooling system equipment cubicle area coolers, and the connections to the LPCS pump motor housing. The LPCS pump motor is an active assembly and is not subject to aging management review.The ECW System includes the fuel pool emergency makeup pumps that interface with the containment flooding piping interface with the RHR System and provide capability for make-up to the spent fuel pool through a capped piping connection on the refueling floor.The ECW System includes the supply and return piping to the Process Radiation Monitoring System panel that contains the RHR service water effluent radiation monitors.The ECW System includes the shad net and cabling All associated piping, components and instrumentation contained within the boundary described above are also included in the ECW System scoping boundary.Also included in the ECW scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Diesel Generator Building.Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the ECW scoping boundary is the ultimate heat sink and the concrete anchors for the shad net which are evaluated with the Cooling Lake license renewal structure.
Not included in the ECW scoping boundary are the radiation monitors which are evaluated with the Process Radiation Monitoring license renewal system.Not included in the ECW scoping boundary is the service water tunnel which is evaluated with the Lake Screen House license renewal structure.
Reason for Scope Determination The Essential Cooling Water System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Essential Cooling Water System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Essential Cooling Water System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63).The Essential Cooling Water System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's LaSalle County Station, Units 1 and 2 2.3-77 License Renewal Application Section 2 -Scoping and Screening Methodology and Results regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Remove residual heat from the reactor coolant system. The Essential Cooling Water System provides cooling to equipment that removes decay heat from the reactor during normal operation and accident conditions.
10 CFR 54.4(a)(1)
: 2. Provide heat removal from safety-related heat exchangers.
The Essential Cooling Water System removes heat from the RHR heat exchangers and ECCS pump seal and motor coolers during normal operation and accident conditions.
10 CFR 54.4(a)(1)
: 3. Provide emergency heat removal from primary containment and provide containment pressure control. The Essential Cooling Water System removes heat from the RHR heat exchangers during transient and accident conditions.
The Essential Cooling Water System provides containment flooding water for post-accident recovery.
10 CFR 54.4(a)(1)
: 4. Maintain emergency temperature limits within areas containing safety-related components.
The Essential Cooling Water System removes heat from secondary containment equipment compartments that house ECCS and ECW components.
10 CFR 54.4(a)()1)
: 5. Ensure adequate cooling in the spent fuel pool to maintain stored fuel within acceptable temperature limits. The Essential Cooling Water System provides a source of emergency makeup water for fuel pool cooling. 10 CFR 54.4(a)(1)
: 6. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Essential Cooling Water System contains nonsafety-related fluid filled lines in the Auxiliary Building which provide structural support or have potential spatial interactions with safety-related SSC. 10 CFR 54.4(a)(2)
: 7. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Essential Cooling Water System provides cooling to equipment that is credited with maintaining reactor level and cooling the reactor and containment for Fire Safe Shutdown.
10 CFR 54.4(a)(3)
: 8. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The Essential Cooling Water System includes components that are environmentally qualified.
10 CFR 54.4(a)(3)
: 9. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The Essential Cooling Water System provides cooling for equipment that is credited with maintaining reactor water injection and for containment heat removal for Station Blackout coping. 10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 2.3-78 License Renewal Application Section 2 -Scoping and Screening Methodology and Results UFSAR References 1.2.2.6.2 2.5.5.2.5 3.1.2.4.15 3.1.2.4.16 3.1.2.4.17 7.3.3 9.1.3.2.3.6 9.2.1 9.2.6 License Renewal Boundary Drawinas LR-LAS-M-87, Sheets 1, 2, 3 LR-LAS-M-134, Sheets 1, 2, 3 LR-LAS-M-91, Sheet 3 LR-LAS-M-96, Sheet 4 LR-LAS-M-98, Sheet 1 LR-LAS-M-137, Sheet 3 LR-LAS-M-142, Sheet 4 LR-LAS-M-144, Sheet 1 LR-LAS-M-1 53, Sheets 4, 6 LR-LAS-M-EDGECW, Sheet 1 Table 2.3.3-11 Essential Cooling Water System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Fish Barrier Filter Flow Device Pressure Boundary Throttle Heat Exchanger
-(CSCS Equipment Area Heat Transfer Cubicle Coolers) Tubes Pressure Boundary Heat Exchanger
-(D/G Cooler) Tube Pressure Boundary Sheet Heat Exchanger
-(D/G Cooler) Tube Side Pressure Boundary Components Heat Exchanger
-(D/G Cooler) Tubes Heat Transfer Pressure Boundary Heat Exchanger
-(LPCS Pump Motor Pressure Boundary Cooler) Shell Side Components Heat Exchanger
-(LPCS Pump Motor Pressure Boundary Cooler) Tube Side Components Heat Exchanger
-(LPCS Pump Motor Heat Transfer Cooler) Tubes Pressure Boundary Heat Exchanger
-(RHR Heat Exchanger)
Pressure Boundary LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-79 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function Tube Sheet Heat Exchanger
-(RHR Heat Exchanger)
Pressure Boundary Tube Side Components Heat Exchanger
-(RHR Heat Exchanger)
Heat Transfer Tubes Pressure Boundary Heat Exchanger
-(RHR Pump Seal Pressure Boundary Cooler) Shell Side Components Heat Exchanger
-(RHR Pump Seal Pressure Boundary Cooler) Tube Side Components Heat Exchanger
-(RHR Pump Seal Heat Transfer Cooler) Tubes Pressure Boundary Hoses Pressure Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (DIG Cooling Water Pressure Boundary ODG01 P)Pump Casing (DIG Cooling Water Pressure Boundary 1 DG01 P/2DG01 P)Pump Casing (Fuel Pool Emergency Pressure Boundary Makeup)Pump Casing (HPCS DIG Cooling Water) Pressure Boundary Pump Casing (RHR Service Water) Pressure Boundary Strainer Body Pressure Boundary Strainer Element Filter Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-11 Essential Cooling Water System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-80 Section 2 -Scoping and Screening Methodology and Results 2.3.3.12 Fire Protection
 
===System Description===
The Fire Protection System is a standby system common to both Units 1 and 2 that is designed to provide detection and suppression of a fire at the plant. The Fire Protection System is nonsafety-related, but provides detection and suppression equipment and design features which support safe shutdown of the plant. The Fire Protection System is in scope for license renewal. However, portions of the system are not required to perform intended functions and are not in scope.The purpose of the Fire Protection System is to prevent fires from starting, quickly detect any fires, quickly suppress fires in hazard areas, prevent the spread of a fire by use of barriers, and provide firefighting capability for manual fire extinguishment.
The Fire Protection System includes water, carbon dioxide, and halon fire suppression systems. It also includes active and passive features such as fire doors, dampers, penetration seals, fire wraps, fire barrier walls and slabs, and flammable fluid retention curbs and walls to prevent the spread of a fire.The fire water system provides cooling lake water to the plant fire hydrants, the water sprinkler systems, spray systems, deluge systems, and the hose valve stations.
The system is normally kept pressurized by two fire protection jockey pumps. If a system demand occurs, the motor driven intermediate fire pump is automatically activated.
If the system demand exceeds the capacity of this pump, the pressure decreases in the fire water system, thereby, automatically starting a diesel driven fire pump. If demand is in excess of the capability of a single diesel fire pump or if there is a pump failure, the second diesel driven fire pump is started automatically.
If these pumps are unavailable, the plant service water system pumps may be used as a backup to provide the system demand. The fire pumps take suction from the service water tunnel in the Lake Screen House and supply water to the yard ring header. The fire hydrant system is supplied by separate header connections to each of the two diesel driven fire pumps. The yard loop is sectionalized, permitting independence of each unit if desired. Fire protection water is distributed to the hydrants, hose stations, and water suppression systems in the plant from the yard fire main loop, which encircles the power block.Multiple headers from the outside fire loop are brought into the building complex to feed the standpipes, hose stations and sprinkler, spray and deluge water systems. Wet standpipes for hose stations are located throughout the plant to allow use of fire hoses to support local fire brigade activity.
Wet pipe sprinkler operation is initiated automatically when ambient temperature exceeds the melting point of the fusible links of the sealed sprinklers, causing the spray heads to open. Preaction sprinkler system operation is actuated by area fire detectors that open deluge valves supplying fusible element sprinkler heads, which melt when local ambient temperatures rise due to a fire. System actuation transmits alarm signals to the control room.Deluge sprinkler system operation is initiated by heat detection.
Each system is automatically initiated by a high temperature signal from heat detectors.
The detection activates a tripping device which opens the deluge valve, thus supplying water under pressure to the open spray nozzles. Deluge valves can also be tripped open manually.
System actuation transmits alarm signals to the control room.LaSalle County Station, Units 1 and 2 2.3-81 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Deluge water application systems are also provided for the charcoal filters in the ventilation systems and water is supplied to the filters by a fixed pipe system. Valves are manually opened when a temperature detector actuates a local alarm system and registers an alarm condition in the control room.An automatic carbon dioxide flooding extended discharge system is provided for each of the five diesel generator rooms. Each system is activated by a fixed temperature rise detector system and may also be manually activated.
The carbon dioxide systems consist of a common refrigerated storage unit and associated piping, headers, and valves to the five diesel generator rooms. Hose reels are also provided for manually fighting fires. Audible and visual predischarge alarms warn that the carbon dioxide flooding system is about to actuate so that personnel may leave the area. Actuation of the carbon dioxide flooding system automatically shuts down the local fans and closes the local dampers in the ventilation system. The carbon dioxide storage unit also provides carbon dioxide for fire suppression in the main generator alterex housings and purge gas for the main generators.
Halon fire suppression systems are utilized in the plant computer room in the south service building, QA archives in the north service building, and the records storage building.
Audible and visual predischarge alarms warn that the halon system is about to actuate so that personnel may leave the area. Actuation of the halon system automatically shuts down the local fans and closes the local dampers in the ventilation system.The Fire Protection System includes features to isolate safety-related systems from unacceptable fire hazards. This is accomplished by the use of barriers such as walls, floors, ceilings, fire doors, fire dampers, cable and piping penetration seals and ventilation seals. In addition, curbs and walls are provided to minimize the spread of flammable fluids in the event of a spill.Fire detection instrumentation, consisting of ionization and heat detectors, is included in the scope of the Fire Protection System.For more detailed information, see UFSAR Section 9.5.1 and Appendix H, Fire Protection Report.Boundary The Fire Protection System license renewal boundary begins in the Lake Screen House where the fire pumps take suction from the service water tunnel and supply water to the fire main ring header and yard fire hydrants, and extends into the building fire distribution piping for hose station standpipes, water spray subsystems, water sprinkler subsystems, and water deluge subsystems throughout the plant. Included is the interface with the Nonessential Cooling Water System that provides a source of fire water in the event the fire water pumps are not available.
The diesel engines for the diesel driven fire pumps are a complex active assembly and are, therefore, not subject to aging management review.The carbon dioxide fire suppression subsystem begins at the carbon dioxide storage unit and extends via distribution piping to each of the five diesel generator rooms and hose reels.Also included in the system evaluation boundary are the physical plant design features that consist of fire barrier walls and slabs, fire barrier penetration seals, fire doors and dampers, fire wraps, and flammable fluid retention curbs and walls. This includes fire dampers in the LaSalle County Station, Units 1 and 2 2.3-82 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Reactor Buildings, Turbine Buildings, Auxiliary Building, Lake Screen House, Radwaste Building, and Diesel Generator Buildings.
The fire damper housings are subject to aging management review. The fire barrier function of all fire damper housings is evaluated with the Fire Protection System for license renewal aging management review. The pressure boundary function of the fire damper housings, if applicable, is evaluated with the appropriate ventilation system. However, the dampers are active components and are not subject to aging management review. The Fire Protection System includes fire rated doors in the Reactor Buildings, Turbine Buildings, Auxiliary Building, and Diesel Generator Buildings.
Air supervised preaction sprinkler systems are provided with individual air compressors to maintain air pressure.
These compressors are active components and are not subject to aging management review.The racks, reels, and supports that makeup the fire hose stations are included within the scoping boundary of the Fire Protection System. Hoses are considered consumables, and are therefore, not subject to aging management review.All associated piping, components, and instrumentation contained within the flowpaths described above are included in the Fire Protection System scoping boundary.Also included in the Fire Protection System scoping boundary are those water filled portions of nonsafety-related piping and equipment located in areas where there are potential spatial interactions with safety-related equipment.
This includes the nonsafety-related portions of the system located within the Reactor Buildings, Turbine Buildings, Auxiliary Building, Lake Screen House, Offgas Building, and Diesel Generator Buildings.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawings for identification of this boundary, shown in red.Not included in the Fire Protection System scoping boundary are the drains from fire water system components and areas protected by the fire water system which are evaluated with the Plant Drainage System.Not included in the Fire Protection System scoping boundary are the fire detection and signaling systems and associated circuitry which are evaluated with Electrical Commodities.
Not included in the Fire Protection System scoping boundary are the Lake Screen House traveling water screens. This equipment is evaluated with the Nonessential Cooling Water System.Not included in the Fire Protection System scoping boundary is the fuel oil supply piping and diesel fuel fire pump day tank for the fire pump diesel engines which are evaluated with the Diesel Generator and Auxiliaries System.Not included in the scope of license renewal is the carbon dioxide supply piping to the main generator alterex housings and purge gas for the main generators.
This equipment is provided for asset protection and does not perform or support an intended function in accordance with 10 CFR 54.4(a)(3).
Not included in the scope of license renewal is the halon fire suppression system that services the computer room in the south service building and records storage areas in the north service building and records storage building.
These areas do not contain any safety-related LaSalle County Station, Units 1 and 2 2.3-83 License Renewal Application Section 2 -Scoping and Screening Methodology and Results equipment, and the halon systems do not perform or support an intended function in accordance with 10 CFR 54.4(a)(3).
Not included in the scope of license renewal are fire rated dampers and fire rated doors that do not perform or support an intended function in accordance with 10 CFR 54.4(a)(3).
Reason for Scope Determination The Fire Protection System is not in scope under 10 CFR 54.4(a)(1) because no portions of the system are safety-related and relied upon to remain functional during and following design basis events. The Fire Protection System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Fire Protection System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Fire Protection System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Fire Protection System includes nonsafety-related SSCs with the potential for spatial and structural interaction with safety-related equipment in the Reactor Buildings, Auxiliary Building, Turbine Buildings, Diesel Generator Buildings, and Offgas Building.
10 CFR 54.4(a)(2)
: 2. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Fire Protection System provides the capability to control postulated fires in plant areas to maintain safe shutdown ability. 10 CFR 54.4(a)(3)
UFSAR References 9.5.1 5.9 Appendix H 3.2-1 License Renewal Boundary Drawinqgs LR-LAS-M-68, Sheet 1 LR-LAS-M-71, Sheets 1, 2, 3 LR-LAS-M-72, Sheets 1, 2, 5 LR-LAS-M-78, Sheet 1 LR-LAS-M-89, Sheet 1 LR-LAS-M-1 26, Sheets 1, 2, 3 LR-LAS-M-1 29, Sheets 3, 4, 7 LR-LAS-M-1442, Sheet 2 LaSalle County Station, Units 1 and 2 2.3-84 License Renewal Application Section 2 -Scoping and Screening Methodology and Results LR-LAS-M-1 443, LR-LAS-M-1449, LR-LAS-M-1451, LR-LAS-M-1455, LR-LAS-M-1456, LR-LAS-M-1459, LR-LAS-M-1 460, LR-LAS-M-1461, LR-LAS-M-1462, LR-LAS-M-1463, LR-LAS-M-1467, Sheet 2 Sheet 1 Sheets 2, 3 Sheet 2 Sheet 2 Sheets 2, 3 Sheet 2 Sheets 1, 2, 3, 4 Sheet 1 Sheet 1 Sheets 1, 3 Table 2.3.3-12 Fire Protection System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Fire Barriers (Damper Housing) Fire Barrier Fire Barriers (Doors) Fire Barrier Fire Barriers (For Steel Components)
Fire Barrier Fire Barriers (Penetration Seals and Fire Fire Barrier Stops)Fire Barriers (Walls and Slabs) Fire Barrier Fire Hydrant Pressure Boundary Hose Stations (Racks, Reels, and Structural Support Supports)Hoses (Diesel Fire Pump) Pressure Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (Diesel Fire Pump) Pressure Boundary Pump Casing (Fire Intermediate Pump) Pressure Boundary Pump Casing (Fire Jockey Pump) Pressure Boundary Spray Nozzles Spray Sprinkler Heads Pressure Boundary Spray Strainer Element Filter Tanks (Cardox Storage) Pressure Boundary Tanks (Retard Chamber) Pressure Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-12 Fire Protection System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-85 Section 2 -Scoping and Screening Methodology and Results 2.3.3.13 Fuel Pool Cooling and Storage System Description The Fuel Pool Cooling and Storage System is a normally operating system designed to provide an environment to safely and temporarily store new and used nuclear fuel and consumable reactor internal components including control rods and nuclear instrumentation.
The Fuel Pool Cooling and Storage System includes the spent fuel storage racks, defective fuel storage racks, and control rod blade storage racks within the spent fuel storage pools, and new fuel storage racks. The Fuel Pool Cooling and Storage System also includes skimmer surge tanks, heat exchangers, pumps, water purifying loops, discharge diffusers within the fuel pools, and associated valves, piping components and instrumentation.
The Fuel Pool Cooling and Storage System is in scope for license renewal. However, portions of the system are not required to perform intended functions and are not in scope.The purpose of the Fuel Pool Cooling and Storage System is to maintain the fuel stored in the spent fuel pools and new fuel storage vault in a safe subcritical configuration.
The system accomplishes this by removing decay heat from spent fuel assemblies stored in the spent fuel pools, maintaining fuel pool water temperature and level within required limits, purifying water in the spent fuel pools, and minimizing contamination and radiation exposure from fission and corrosion product buildup in the spent fuel pool water. The Fuel Pool Cooling and Storage System also supports filling and draining of the reactor wells and dryer/separator pits in support of refueling operations.
The fuel storage pools, are located in the refueling area within the Reactor Building.
Each LaSalle unit has a spent fuel pool and dryer/separator pit. The cask well and new fuel storage vault are common to both units. The spent fuel pools communicate with the reactor wells through fuel transfer canals. Removable gates are inserted in the canal openings to provide a watertight boundary except during refueling when the reactor well is also flooded for underwater transfer of nuclear fuel. The spent fuel pools, cask well, dryer/separator pits, transfer canals, and reactor wells are reinforced concrete structures that are an integral part of the Reactor Building.
They are lined with stainless steel plate to minimize leakage. The spent fuel pools contain high-density storage racks equipped with thermal neutron poison material for storage of new and spent fuel. The spent fuel pools also contain storage racks designed to store control rod blades, fuel channels, defective fuel storage containers and other core components that cannot be stored in a fuel storage rack. The spent fuel pools are maintained filled with sufficient level of demineralized water covering the spent fuel storage racks to provide radiation shielding for normal building occupancy by operating personnel.
The spent fuel storage racks, defective fuel storage racks, and control rod blade storage racks within the spent fuel storage pools and new fuel storage racks are safety-related and designed to Seismic Category 1 criteria.Heat is normally removed from the fuel pool cooling heat exchangers by the Nonessential Cooling Water System. Normal make-up to compensate for evaporation and leakage is provided by the Condensate System. A Seismic Category 1 emergency make-up source is provided by the Essential Cooling Water (ECW) System. A Seismic Category 1 emergency cooling capability is provided by the Residual Heat Removal (RHR) System.The Fuel Pool Cooling and Storage System can be aligned during refueling operations to circulate, cool, and process water from the reactor well and dryer/separator pit.Interconnections are provided to the Suppression Pool Cleanup System to facilitate filling and LaSalle County Station, Units 1 and 2 2.3-86 License Renewal Application Section 2 -Scoping and Screening Methodology and Results draining of the reactor well and dryer/separator pit in support of refueling operations.
The Fuel Pool Cooling and Storage System piping and equipment from the skimmer surge tanks to the RHR System and the return piping from the RHR System to the spent fuel pools is safety-related.
Piping and equipment in the flowpath through the fuel pool cooling pumps, filter demineralizers, heat exchangers and back to the fuel pool is nonsafety-related.
Piping that routes and detects leakage of the fuel pool gates and reactor well drain piping to the primary containment penetrations, is also safety-related up to normally closed valves. All other portions of the Fuel Pool Cooling and Storage System piping are nonsafety-related.
For more detailed information, see UFSAR Sections 7.7.12 and 9.1.Boundary The Fuel Pool Cooling and Storage System license renewal scoping boundary begins at the weirs at the surface of the spent fuel pools, reactor wells, and dryer/separator pits, and continues within the Reactor Building through piping to the skimmer surge tanks to the fuel pool cooling water pumps and connection to the RHR System. From the pump discharge the piping leaves the Reactor Building, passes through the Auxiliary Building, enters the Turbine Building, and continues to the filter demineralizers.
From the filter demineralizers, the piping returns through the Auxiliary Building to the Reactor Building and continues through the fuel pool heat exchangers to the spent fuel pools, reactor wells and dryer/separator pits. Included are the fuel pool cooling supply connections to the RHR System, the RHR System return piping to the spent fuel pools, supply and return connections to the Suppression Pool Cleanup System, and the connections to the Condensate System.Also included is the piping installed to drain the cask washdown area and new fuel storage vault, and piping that detects and routes leakage past the fuel pool gates, refueling bellows, and the liners installed in the spent fuel pools, reactor wells, dryer/separator pits, and cask well.The Fuel Pool Cooling and Storage System scoping boundary also includes the spent fuel storage racks, defective fuel storage racks and control rod blade storage racks within the spent fuel storage pools, and new fuel storage racks.All associated piping, components, and instrumentation contained within the boundary described above are also included in the Fuel Pool Cooling and Storage System scoping boundary.Also included in the Fuel Pool Cooling and Storage System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interactions with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located in the Reactor Buildings and Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawings for identification of this boundary, shown in red.Not included in the Fuel Pool Cooling and Storage System scoping boundary is the piping and equipment associated with the emergency make-up water source to the spent fuel pools which LaSalle County Station, Units 1 and 2 2.3-87 License Renewal Application Section 2 -Scoping and Screening Methodology and Results is evaluated with the ECW System.Not included in the Fuel Pool Cooling and Storage System scoping boundary are the spent fuel pools, transfer canals, reactor wells, dryer/separator pits and cask well including their liners, new fuel storage vault, and fuel storage pool gates which are evaluated with the Reactor Buildings structure.
Not included in the Fuel Pool Cooling and Storage System scoping boundary are the refueling bellows assemblies which are evaluated with the Primary Containment structure.
Not included in the scope of license renewal is the portion of the Fuel Pool Cooling and Storage System located within the Turbine Building, as this portion of the system is not located in areas where there are potential spatial interactions with safety-related components.
Components that are not required to support the system's leakage boundary intended functions are not included in the scope of license renewal.Reason for Scope Determination The Fuel Pool Cooling and Storage System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Fuel Pool Cooling and Storage System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Fuel Pool Cooling and Storage System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1, Ensure adequate cooling in the spent fuel pool to maintain stored fuel within acceptable temperature limits. The Fuel Pool Cooling and Storage System includes safety-related equipment to circulate and cool the fuel pool water inventory and maintain adequate water inventory.
10 CFR 54.4(a)(1) 2, Prevents criticality of fuel assemblies stored in the spent fuel pool. The spent fuel storage racks maintain new and spent nuclear fuel in a subcritical configuration, with at least 5 percent subcriticality margin. 10 CFR 54.4(a)(1)
: 3. Provides protection for safe storage of new and spent fuel. The spent fuel storage racks provide physical support, shelter and protection for new and spent nuclear fuel. 10 CFR 54.4(a)(1)
: 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The system includes nonsafety-related piping that has the potential to spatially and structurally interact with safety-related components located in the Reactor and Auxiliary Buildings.
10 CFR 54.4(a)(2)
LaSalle County Station, Units 1 and 2 2.3-88 License Renewal Application Section 2 -Scoping and Screening Methodology and Results UFSAR References Table 3.2.1 7.7.12 9.1 License Renewal Boundary Drawings LR-LAS-M-98, Sheets 1, 4 LR-LAS-M-144, Sheet 1 LR-LAS-M-91, Sheet 1 LR-LAS-M-96, Sheets 2, 5 LR-LAS-M-103, Sheet 19 LR-LAS-M-137, Sheet 1 LR-LAS-M-142, Sheet 2, 5 Table 2.3.3-13 Fuel Pool Cooling and Storage System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Control Rod Blade Storage Racks Structural Integrity Fuel Storage Racks (Defective Fuel) Structural Integrity Fuel Storage Racks (New Fuel Storage) Structural Integrity Fuel Storage Racks (Unit 1 Spent Fuel) Absorb Neutrons Structural Integrity Fuel Storage Racks (Unit 2 Spent Fuel) Absorb Neutrons Structural Integrity Heat Exchanger
-(Fuel Pool Cooling) Leakage Boundary Shell Side Components Hoses Leakage Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (Fuel Pool Cooling Pump) Leakage Boundary Strainer Element (Inside Skimmer Surge Filter Tank)Tanks (Skimmer Surge Tanks) Pressure Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-13 Fuel Pool Cooling and Storage System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-89 Section 2 -Scoping and Screening Methodology and Results 2.3.3.14 Nonessential Cooling Water System Description The Nonessential Cooling Water System is a normally operating system that is designed to provide cooling water to the main condensers and other plant heat exchangers.
The Nonessential Cooling Water System consists of the following plant systems: circulating water, service water, screen wash, chemical feed, gland water, and lake make-up and blowdown.The Nonessential Cooling Water System is in scope for license renewal. However, portions of the Nonessential Cooling Water System are not required to perform intended functions and are not included in the scope of license renewal.Circulating Water The purpose of the circulating water system is to provide the condensers with a continuous supply of cooling water. The circulating water system accomplishes this by taking water from the man-made Cooling Lake, pumping the water through the condensers and returning the heated water to the Cooling Lake.Service Water The purpose of the service water system is to supply cooling water for the turbine-generator and miscellaneous HVAC loads, fuel pool cooling, and the heat exchangers in the turbine building and reactor building closed cooling water systems. Water for the traveling screen wash is also provided by this system. The service water system provides water for filling the fire protection system and serves as a back-up supply for fire water. The service water system also provides water for use in the radwaste system. The circulating water system accomplishes this by taking water from the man-made Cooling Lake, pumping it through various plant equipment and returning water to the Cooling Lake.Piping in the service water system provides water from the Cooling Lake to the service water tunnel in the Lake Pump House that provides the water to supply the Fire Protection System.The service water system also functions as a credited back-up to the Fire Water System in the event that both diesel fire water pumps are unavailable at the same time.Screen Wash The purpose of the screen wash system is to provide water to wash and remove debris from the traveling screens in the Lake Screen House. The screen wash system accomplishes this by providing screened pressurized water to spray onto the traveling screens to dislodge debris from the screen surface for collection and removal.Chemical Feed The purpose of the chemical feed system is to minimize the macroscopic biological fouling and microbiologically influenced corrosion in plant systems. The chemical feed system accomplishes this by injection of chemicals into the water supplied from the Cooling Lake to the plant, such as biocides, scale inhibitors, corrosion inhibitors, and silt dispersants.
LaSalle County Station, Units 1 and 2 2.3-90 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Gland Water The purpose of the gland water system is to provide cooling water to plant equipment.
The gland water system accomplishes this by providing cooling and sealing water to plant rotating equipment, including the circulating water pumps.Lake Make-up and Blowdown The purpose of the lake make-up and blowdown system is to maintain an acceptable water level in the Cooling Lake, control dissolved solids in the Cooling Lake water, and dilute and discharge low-level radioactive wastes. The make-up and blowdown system accomplishes this by pumping water from the Illinois River to maintain level in the Cooling Lake for water lost due to evaporation, seepage, and blowdown.
Dissolved solids in the Cooling Lake water are controlled by discharging water from the lake through the blowdown line to the Illinois River.This same blowdown line is used for diluting low-level radioactive liquid waste and then discharging the diluted waste to the Illinois River.For more detailed information see UFSAR Sections 9.2.2, 9.2.12, and 10.4.5.Boundary The Nonessential Cooling Water System license renewal scoping boundary includes that portion of the system that provides water to fill the fire water system and to provide a source of pressurized water to the fire water system if the fire pumps are unavailable.
The scoping boundary begins with the traveling water screens and piping in the Lake Screen House that provides water from the Cooling Lake to fill the service water tunnel. The service water pumps as well as the fire water pumps take their suction from the service water tunnel located in the Lake Screen House. The in scope boundary for the service water piping extends from the service water tunnel to the service water pump and discharge piping and continues through strainers to, and including piping and isolation valves in branch lines downstream of the fire water system supply line interface for each unit. The Nonessential Cooling Water System scoping boundary includes the traveling water screens located in the Lake Screen House.The traveling water screens structural framework is subject to aging management review.However, the rotating screen assemblies are active components and are not subject to aging management review.All associated piping, components, and instrumentation contained within the boundaries described above are also included in the Nonessential Cooling Water System scoping boundary.Also included in the Nonessential Cooling Water System scoping boundary are those water filled portions of nonsafety-related piping and equipment located in areas where there are potential spatial interactions with safety-related equipment.
This includes the nonsafety-related portions of the system located within the Reactor Buildings, Turbine Buildings, and Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the Nonessential Cooling Water System scoping boundary is the service water tunnel which is evaluated with the Lake Screen House.LaSalle County Station, Units 1 and 2 2.3-91 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Not included in the scope of license renewal are the plant screen wash system and lake make-up and blowdown system which do not perform or support an intended function, are not located in areas that contain safety-related systems or components, and therefore are not included in the scope of license renewal.Reason for Scope Determination The Nonessential Cooling Water System is not in scope under 10 CFR 54.4(a)(1) because no portions of the system are safety-related and relied upon to remain functional during and following design basis events. The Nonessential Cooling Water System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Nonessential Cooling Water System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Nonessential Cooling Water System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Nonessential Cooling Water System contains nonsafety-related fluid filled lines in the Reactor Buildings, Turbine Buildings, and Auxiliary Building which have potential spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
: 2. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Nonessential Cooling Water System provides a source of fire water and provides a credited backup in the event the diesel fire pumps are unavailable at the same time. 10 CFR 54.4(a)(3)
UFSAR References 1.2.3.1.4 1.2.3.6.3 2.4.8.4 2.5.6.4.5 3.2 9.2.9.2.2 9.2.12 10.4.5 FPR Section 3 0 LaSalle County Station, Units 1 and 2 2.3-92 License Renewal Application Section 2 -Scoping and Screening Methodology and Results License Renewal Boundary Drawings LR-LAS-M-68, Sheet 1 LR-LAS-M-69, Sheets 1, 2, 3, 4 LR-LAS-M-125, Sheets 1, 2, 3 LR-LAS-M-63, Sheet 4 LR-LAS-M-70, Sheet 1 LR-LAS-M-77, Sheet 1 LR-LAS-M-87, Sheet 1 LR-LAS-M-89, Sheet 1 LR-LAS-M-91, Sheets 1, 3 LR-LAS-M-1 15, Sheet 2 LR-LAS-M-1 34, Sheet 1 LR-LAS-M-1 37, Sheets 1, 3 LR-LAS-M-1 53, Sheets 4, 6 LR-LAS-M-1 59, Sheet 2 LR-LAS-M-1467, Sheet 3 LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-93 Section 2 -Scoping and Screening Methodology and Results Table 2.3.3-14 Nonessential Cooling Water System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Structural Integrity Heat Exchanger
-(Aux Bldg HVAC Leakage Boundary Condenser Unit) Tube Side Components Heat Exchanger
-(Aux Bldg HVAC Leakage Boundary Condenser Unit) Tubes Heat Exchanger
-(Counting Room HVAC Leakage Boundary Condenser Unit) Tube Side Components Heat Exchanger
-(Counting Room HVAC Leakage Boundary Condenser Unit) Tubes Heat Exchanger
-(Fuel Pool Cooling) Leakage Boundary Tube Side Components Heat Exchanger
-(Primary Containment Leakage Boundary Ventilation Chiller Service Water Condenser)
Tube Side Components Heat Exchanger
-(Primary Containment Leakage Boundary Ventilation Chiller Service Water Condenser)
Tubes Heat Exchanger
-(Process Computer Leakage Boundary Room A/C Unit) Tube Side Components Heat Exchanger
-(Process Computer Leakage Boundary Room A/C Unit) Tubes Heat Exchanger
-(Reactor Building Leakage Boundary Closed Cooling Water Heat Exchanger)
Tube Side Components Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (Service Water) Pressure Boundary Tanks (Clean Gland Water) Leakage Boundary Traveling Water Screen Framework Structural Integrity Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-14 Nonessential Cooling Water System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-94 Section 2 -Scoping and Screening Methodology and Results 2.3.3.15 Nonsafety-Related Ventilation
 
===System Description===
The intended function of the Nonsafety-Related Ventilation (NSV) System for license renewal is to maintain leakage boundary integrity to preclude system interactions.
For this reason, this system's pressure-retaining components located in areas where there are potential spatial interactions with components performing safety-related functions have been included in the scope of license renewal. This system is not required to operate to support license renewal intended functions, and is in scope for potential spatial interaction.
The NSV System is a normally operating system designed to maintain a favorable environment for plant equipment and personnel while preventing the spread of contamination in the plant. The NSV system consists of various ventilation plant systems and the station heat recovery plant system.The NSV System provides ventilation to the following plant areas: Auxiliary Building equipment areas, Auxiliary Building office areas, Auxiliary Building laboratory, Lake Screen House, machine shop, Offgas Building, Radwaste Building, Service Building, Service Building storeroom, interim radwaste storage facility, River Screen House, QA records vault, and 345 kV relay house. The NSV system also includes the station heating and recovery plant system, which recycles heat from ventilation exhaust air to preheat ventilation intake air in the winter time, and provides supplemental cooling in the summer time.For more detailed information, see UFSAR sections 9.4.3, 9.4.6, 9.4.7, 9.4.8, 9.4.11, 9.4.12, 9.4.13, and 9.2.10.Boundary The NSV System license renewal scoping boundary encompasses the liquid-filled portions of nonsafety-related piping and equipment located in areas where there are potential spatial interactions with safety-related equipment.
This includes the nonsafety-related liquid-filled portions of the system located within the Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this system; specifically the station heat recovery components that are located within the Auxiliary Building.
For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the NSV System scoping boundary are the ventilation filter bank fire detection instrumentation and associated sprinkler systems. These components perform a fire protection function and are evaluated with the Fire Protection System. Additionally, the fire protection function of fire dampers is evaluated with the Fire Protection System.Not included in the scope of license renewal is the portion of the NSV System that is nonsafety-related and is not liquid-filled or is not located in areas where there are potential spatial interactions with equipment performing a safety-related function, and therefore does not create a concern for (a)(2) spatial concern. This includes the ventilation portion of the NSV system and the components in the station heat recovery portion of the system that are located in nonsafety-related buildings; for example, the Radwaste Building.LaSalle County Station, Units 1 and 2 2.3-95 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Reason for Scope Determination The Nonsafety-Related Ventilation System is not in scope under 10 CFR 54.4(a)(1) because no portions of the system are safety-related or relied upon to remain functional during and following design basis events. The Nonsafety-Related Ventilation System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Nonsafety-Related Ventilation System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The NSV system includes nonsafety-related water filled piping and components located in the Auxiliary Building that have the potential for spatial interactions (spray or leakage) with safety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References 9.4.3 9.4.6 9.4.7 9.4.8 9.4.11 9.4.12 9.4.13 9.2.10 License Renewal Boundary Drawings LR-LAS-M-1 02, Sheets 1, 2, 3, 5, 6, 7, 8, 9, 10, 11 LR-LAS-M-1 29, Sheet 2 LR-LAS-M-1 51, Sheet 4 LaSalle County Station, Units 1 and 2 2.3-96 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.3-15 Nonsafety-Related Ventilation System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Heat Exchanger
-(Primary Containment Leakage Boundary Vent Chiller Glycol Condenser)
Tube Side Components Heat Exchanger
-(Primary Containment Leakage Boundary Vent Chiller Glycol Condenser)
Tubes Heat Exchanger
-(Reactor Bldg, Turb Leakage Boundary Bldg, Switchgear Rm Supply and Exhaust Coils) Tube Side Components Heat Exchanger
-(Reactor Bldg, Turb Leakage Boundary Bldg, Switchgear Rm Supply and Exhaust Coils) Tubes Piping, piping components, and piping Leakage Boundary elements Pump Casing (Heat Recovery Transfer Leakage Boundary Pumps, Fill Pump, Make-up Tank Pump, Heat Coil Drain Pump)Tanks (Glycol Electric Heaters) Leakage Boundary Tanks (Heat Recovery System Expansion Leakage Boundary Tank)Tanks (Heat Recovery System Make-up Leakage Boundary Tank)Valve Body -Leakage Boundary The aging management review results for these components are provided in: Table 3.3.2-15 Nonsafety-Related Ventilation System Summary of Aging Management Evaluation LaSalle County Station, Units I and 2 License Renewal Application 2.3-97 Section 2 -Scoping and Screening Methodology and Results 2.3.3.16 Plant Drainage System Description The Plant Drainage System is a normally operating system designed to collect various liquid wastes generated in the operation of the plant. The Plant Drainage System consists of several plant systems including floor and equipment drain systems for the Primary Containment, Reactor Building, Auxiliary Building, Diesel Generator Building, Radwaste Building, Offgas Building, Turbine Building, Service Building, and Lake Screen House. The Plant Drainage System also includes the HVAC equipment drain system, generator vent and drain system, roof drain system, wastewater treatment system, and sewage treatment system. The Plant Drainage System is in scope for License Renewal. However, portions of the Plant Drainage System are not required to perform intended functions and are not in scope.Equipment and Floor Drainage Systems The purpose of the equipment and floor drainage systems is to collect radioactive, nonradioactive, and oily liquid wastes generated in the operation of the plant. The system accomplishes this by collecting waste liquids from their points of origin and transferring them for eventual processing.
Radioactive, nonradioactive, and oily wastes are segregated and processed separately by the appropriate methods.The drywell floor and equipment drain system includes safety-related and environmentally qualified primary containment isolation valves.The nonsafety-related drywell drain lines that are routed through the suppression chamber airspace prior to exiting the primary containment are in scope to ensure their pressure boundary integrity to prevent drywell to suppression chamber bypass leakage.The nonsafety-related floor drain system in the Reactor Building is credited for the mitigation of flooding as a result of a high energy line break (HELB) or a moderate energy line break (MELB) in the Reactor Building and is in scope for the protection of safety-related systems.Portions of the floor drain systems in the Auxiliary Building, Diesel Generator Building, and Turbine Building are credited for the removal of fire water from areas containing safe shutdown equipment and are in scope for Fire Safe Shutdown.
Portions of the floor drain system in the Diesel Generator Building are credited to prevent the accumulation of oil in areas containing safe shutdown equipment and are in scope for Fire Safe Shutdown.Exposed, non-embedded portions of the equipment and floor drainage systems which have potential spatial interaction with safety-related equipment in the Primary Containment, Reactor Building, Auxiliary Building, Diesel Generator Building, and Offgas Building perform a license renewal intended function and are in scope for potential spatial interaction.
HVAC Equipment Drain System The purpose of the HVAC equipment drain system is to prevent water accumulation within HVAC ventilation units. The HVAC equipment drain system accomplishes this by collecting condensate from the ventilation unit plenums and draining it for eventual processing.
The HVAC equipment drain system is not required to operate to support license renewal intended functions.
Only the exposed, non-embedded portions of the HVAC equipment drain system LaSalle County Station, Units 1 and 2 2.3-98 License Renewal Application Section 2 -Scoping and Screening Methodology and Results which have potential spatial interaction with safety-related equipment in the Reactor Building, Auxiliary Building, and Turbine Building perform a license renewal intended function and are in scope for potential spatial interaction.
Generator Vent and Drain System The purpose of the generator vent and drain system is to collect equipment leakoff and drainage from the main turbine and associated components.
The generator vent and drain system accomplishes this by collecting leakoff and drainage and transferring them for eventual processing.
The generator vent and drain system does not perform a license renewal intended function.Roof Drain System The purpose of the roof drain system is to prevent the accumulation of precipitation on plant building roofs. The roof drain system accomplishes this by collecting roof drainage and discharging it into the storm drain system. The roof drain system is not required to operate to support license renewal intended functions.
Roof drains are not credited to mitigate the effects of the probable maximum precipitation (PMP). The roofs of safety-related structures are designed for the maximum accumulation of water assuming the roof drains are clogged. Only the exposed, non-embedded portions of the roof drain branch lines and headers which have potential spatial interaction with safety-related equipment in the Reactor Building, Auxiliary Building, and Diesel Generator Building perform a license renewal intended function and are in scope for potential spatial interaction.
Wastewater Treatment System The purpose of the wastewater treatment system is to process the station's wastewater to comply with state and federal Environmental Protection Agency (EPA) guidelines regulating the effluent returned to the cooling lake. The wastewater system accomplishes this by processing plant waste water through oil separators, equalization tanks, flocculator-clarifier tanks, and media filters prior to releasing through the cooling lake discharge flume. The wastewater treatment system does not perform a license renewal intended function.Sewage Treatment System The purpose of the sewage treatment system is to collect and process plant sewage to meet the effluent quality limits set by the Illinois Environmental Protection Agency. The sewage treatment system accomplishes this by collecting sanitary waste through the sanitary waste drain system and transferring the waste to lift stations for processing through primary and secondary aerated lagoon cells. The effluent of the lagoon is treated by sand filtration for total suspended solids reduction then disinfected prior to release. The sewage treatment system is not required to operate to support license renewal intended functions.
Only the exposed, non-embedded portions of the sanitary waste drain system which have potential spatial interaction with safety-related equipment in the Auxiliary Building perform a license renewal intended function and are in scope for potential spatial interaction.
For more detailed information see UFSAR Sections 9.3.3.LaSalle County Station, Units 1 and 2 2.3-99 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Boundary The license renewal scoping boundary of the Plant Drainage System begins at floor and equipment drains and continues through individual drain lines and drain headers which route the collected drainage to plant collection sumps. Included in this scoping boundary are the collection sump pumps and discharge piping up to but not including the radwaste collection tanks. The radwaste collection tanks are evaluated with the Radwaste System. The collection sumps are evaluated with the structure in which they are located.The floor and equipment drain system for the Primary Containment includes primary containment isolation valves. The safety-related boundary begins at the Primary Containment wall and continues outside of the Primary Containment through piping and two containment isolation valves.The portion of the drywell drains that are in scope to prevent drywell to suppression chamber bypass leakage include those lines routed through the suppression chamber airspace.The floor drain system for the Reactor Building is credited for the mitigation of flooding as a result of a high energy line break (HELB) or a moderate energy line break (MELB). The boundary begins at the individual floor drains and continues through individual drain lines and drain headers and terminates at the Reactor Building floor drain collection sump.The floor drain system for the Auxiliary Building, Diesel Generator Building, and Turbine Building are credited for the removal of fire water from areas containing safe shutdown equipment.
Additionally, the floor drain system in the Diesel Generator Building is credited to prevent the accumulation of oil in areas containing safe shutdown equipment.
The boundary begins at the individual floor drains and continues through individual drain lines and drain headers and terminates at the Auxiliary Building, Diesel Generator Building, or Turbine Building floor drain collection sumps.All associated piping, components, and instrumentation contained within the boundary described above are also included in the Plant Drainage System scoping boundary.Also included in the Plant Drainage System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Primary Containment and Reactor Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. Also included in the Plant Drainage System scoping boundary are those water filled portions of nonsafety-related piping and equipment located in areas where there are potential spatial interactions with safety-related equipment.
This includes the nonsafety-related portions of the system located within the Primary Containment, Reactor Building, Auxiliary Building, Diesel Generator Building, Offgas Building, and Turbine Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the Plant Drainage System scoping boundary is the storm sewer system. The storm sewer system is evaluated with Yard Structures.
LaSalle County Station, Units 1 and 2 2.3-100 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Not included in the Plant Drainage System scoping boundary is the leak detection components used for the identification of leakage within the Primary Containment and outside of the Primary Containment.
These components are evaluated with the Leak Detection System.Not included in the scope of license renewal are the generator vent and drain system and wastewater treatment system which do not perform or support intended functions.
Also not included in the scope of license renewal are the portions of the Plant Drainage System that are nonsafety-related and are not located in areas where there are potential spatial interactions with safety-related equipment.
Reason for Scope Determination The Plant Drainage System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Plant Drainage System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Plant Drainage System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48) and Environmental Qualification (10 CFR 50.49). The Plant Drainage System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62)and Station Blackout (10 CFR 50.63).Intended Functions 1. Provide primary containment boundary.
The Plant Drainage System includes safety-related primary containment isolation valves. 10 CFR 54.4(a)(1)
: 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Plant Drainage System contains nonsafety-related water filled lines in the Reactor Building, Primary Containment, Auxiliary Building, Diesel Generator Building, Offgas Building, and Turbine Building which provide structural support or have potential spatial interactions with safety-related SSCs. The nonsafety-related floor drain system in the Reactor Building is credited for the mitigation of flooding as a result of a high energy line break (HELB) or a moderate energy line break (MELB) in the Reactor Building.Additionally, the nonsafety-related drywell drain lines that are routed through the suppression chamber airspace prior to exiting the primary containment are in scope to ensure their pressure boundary integrity to prevent drywell to suppression chamber bypass leakage. 10 CFR 54.4(a)(2)
: 3. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The Plant Drainage System contains components that are environmentally qualified.
10 CFR 54.4(a)(3)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The floor drain systems in the Auxiliary Building, Diesel Generator Building, and Turbine Building are credited for the removal of fire water from areas containing safe shutdown equipment.
The LaSalle County Station, Units 1 and 2 2.3-101 License Renewal Application Section 2 -Scoping and Screening Methodology and Results floor drain system in the Diesel Generator Building is credited to prevent the accumulation of oil in areas containing safe shutdown equipment.
10 CFR 54.4(a)(3)
UFSAR References 2.4.2.3 Table 3.2-1 3.4.1.4 Table 3.8-1 3.11.1.1 5.2.5.1.1 6.2.4.2.2 Table 6.2-21 Table 6.2-28 7.3.2.2.11 7.6.2.2 7.7.15 9.2.5 9.3.3 9.5 Appendix J.4 License Renewal Boundary Drawings LR-LAS-M-91, Sheets 1, 2, 3, 4, 5, 6 LR-LAS-M-1 04, Sheets 1, 2, 3 LR-LAS-M-1 05, Sheets 1, 2, 3 LR-LAS-M-1 06, Sheets 4, 8 LR-LAS-M-129, Sheets 1, 2, 3, 4, 7, 8, 9 LR-LAS-M-1 37, Sheets 1, 2, 3, 4, 5, 6 LR-LAS-M-149, Sheets 1, 2, 3 LR-LAS-M-1 50, Sheet 2 LR-LAS-M-151, Sheets 3, 4 LR-LAS-M-55, Sheets 1, 2, 7, 8 LR-LAS-M-66, Sheets 1, 3, 5, 9, 10, 11 LR-LAS-M-72, Sheets 1, 2, 5 LR-LAS-M-76, Sheet 4 LR-LAS-M-83, Sheets 1, 2, 3 LR-LAS-M-85, Sheet 1 LR-LAS-M-86, Sheet 1 LR-LAS-M-87, Sheets 1, 2, 3 LR-LAS-M-89, Sheet 1 LR-LAS-M-90, Sheets 1, 2, 3 LR-LAS-M-93, Sheets 1, 2, 4 LR-LAS-M-94, Sheet 1 LR-LAS-M-95, Sheet 1 LR-LAS-M-96, Sheets 1, 2, 3, 4 LR-LAS-M-97, Sheets 1, 2, 3, 4 LR-LAS-M-98, Sheets 1, 4 LR-LAS-M-99, Sheet 1 LR-LAS-M-100, Sheets 1, 3, 4 LaSalle County Station, Units 1 and 2 2.3-102 License Renewal Application Section 2 -Scoping and Screening Methodology and Results LR-LAS-M-101, Sheets 1, 2 LR-LAS-M-102, Sheet 11 LR-LAS-M-103, Sheets 15, 16, 19 LR-LAS-M-109, Sheet 1 LR-LAS-M-1 15, Sheets 2, 12 LR-LAS-M-1 16, Sheets 2, 7 LR-LAS-M-1 26 Sheets 1, 2, 3 LR-LAS-M-130, Sheets 1, 2 LR-LAS-M-132, Sheet 1 LR-LAS-M-133, Sheet 1 LR-LAS-M-134, Sheets 1, 2, 3 LR-LAS-M-1 36, Sheets 1, 2, 3 LR-LAS-M-139, Sheets 1, 2, 4 LR-LAS-M-140, Sheet 1 LR-LAS-M-141, Sheet 1 LR-LAS-M-142, Sheets 1, 2, 3, 4 LR-LAS-M-143, Sheets 1, 2, 3, 4 LR-LAS-M-144, Sheet 1 LR-LAS-M-145, Sheet 1 LR-LAS-M-146, Sheets 1, 3, 4 LR-LAS-M-147, Sheets 1, 2 LR-LAS-M-1 53, Sheets 4, 6 LR-LAS-M-159, Sheet 2 Table 2.3.3-16 Plant Drainage System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Heat Exchanger
-(Drywell Equipment Leakage Boundary Drain Sump Heat Exchanger)
Tube Side Components Heat Exchanger
-(Reactor Building Leakage Boundary Equipment Drain Tank Heat Exchanger)
Tube Side Components Hoses Leakage Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (Drywell Floor and Drywell Leakage Boundary Equipment Drain Pumps)Pump Casing (Reactor Building Leakage Boundary Equipment Drain Pump)Pump Casing (Sump Pumps) Leakage Boundary Tanks (Gland Seal Leakoff Reservoir)
Leakage Boundary Tanks (Reactor Building Equipment Drain Leakage Boundary Tank)Valve Body Leakage Boundary Pressure Boundary LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-103 Section 2 -Scoping and Screening Methodology and Results The aging management review results for these components are provided in: Table 3.3.2-16 Plant Drainage System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-104 Section 2 -Scoping and Screening Methodology and Results 2.3.3.17 Primary Containment Ventilation
 
===System Description===
The Primary Containment Ventilation (PCV) System is a normally operating system designed to limit the maximum average temperature of the air to maintain drywell air temperature within equipment operating limits.The purpose of the PCV System is to maintain a suitable environment inside the drywell for equipment operation and longevity.
The PCV system is in scope for license renewal.However, portions of the PCV System are not required to perform intended functions and are not in scope.The PCV System is composed of two subsystems, the primary containment ventilation plant system and the primary containment chilled water plant system. The two subsystems work together to maintain the reliability of equipment located in the drywell. The ventilation subsystem circulates cooling air within the drywell. The chilled water subsystem removes heat from the drywell air.A portion of the PCV system performs a safety-related function.
The chilled water piping that penetrates Primary Containment and the associated primary containment isolation valves are safety-related components that are relied upon to provide the primary containment boundary.These components are also environmentally qualified.
For more detailed information, see UFSAR Sections 9.2.9 and 9.4.9.Boundary The ventilation portion of the PCV system consists of two supply systems, each containing a supply fan which takes suction from the drywell, circulates this air through a drywell cooler train, and discharges the cooled air to two ring headers inside the drywell. The lower ring header supplies cooled air to the lower levels of the drywell. The upper ring header contains six area coolers, and supplies cooled air to the upper levels of the drywell.The chilled water portion of the PVC system provides cooling water to the drywell cooler trains and the area coolers. The chilled water subsystem is composed of two chilled water loops, consisting of chiller units, chilled water pumps, expansion tanks, a holdup tank, and associated piping, valves and controls.
Each chiller unit provides refrigerant for its associated chilled water loop, and consists of an evaporator, condenser, economizer, compressor, and oil cooler.The portion of the PCV that is in scope for license renewal includes the safety-related portion of the system, the primary containment isolation valves on the chilled water supply and return piping and associated piping and valves.All associated piping, components, and instrumentation contained within the boundary described above are also included in the PCV System scoping boundary.Also included in the PCV scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the LaSalle County Station, Units 1 and 2 2.3-105 License Renewal Application Section 2 -Scoping and Screening Methodology and Results nonsafety-related portions of the system located within the Primary Containment, the Reactor Buildings and the Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system, including all associated piping, components and instrumentation.
For more information, refer to the License Renewal Boundary Drawings for identification of this boundary, shown in red.Not included in the PCV System scoping boundary are the components associated with the cooling water supply to the chiller condensers which are evaluated with both the Nonessential Cooling Water System and the Nonsafety-Related Ventilation System.Not included in the PCV System scoping boundary are the interfaces with the reactor building closed cooling water plant system, which can be aligned to provide an alternate source of containment cooling when the reactor is shut down and the normal chilled water subsystem is unavailable.
These components are evaluated with the Closed Cycle Cooling Water System.Not included in the scope of license renewal is the portion of the PCV System that is nonsafety-related and is not liquid-filled or is not located in areas where there are potential spatial interactions with safety-related equipment, and therefore does not create a concern for (a)(2) spatial concern. This includes the ductwork and ventilation components in the drywell that do not contain chilled water.Reason for Scope Determination The Primary Containment Ventilation System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Primary Containment Ventilation System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Primary Containment Ventilation System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49). The Primary Containment Ventilation System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provide primary containment boundary.
The PCV system contains safety-related primary containment isolation valves in the chilled water piping to and from the drywell. 10 CFR 54.4(a)(1)
: 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The PCV system includes nonsafety-related water filled piping and components that have the potential for spatial interactions (spray or leakage) with safety-related SSCs. 10 CFR 54.4(a)(2)
: 3. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The PCV system contains components associated with the primary containment isolation LaSalle County Station, Units 1 and 2 2.3-106 License Renewal Application Section 2 -Scoping and Screening Methodology and Results valves that are environmentally qualified.
10 CFR 54.4(a)(3)
UFSAR References 9.2.9 9.4.9 Table 3.2-1 License Renewal Boundary DrawinQs LR-LAS-M-86, Sheets 1, 3 LR-LAS-M-1 33, Sheets 1, 3 LR-LAS-M-1453, Sheet 1 LR-LAS-M-1454, Sheet 1 LR-LAS-M-90, Sheet 3 LR-LAS-M-1 02, Sheet 11 LR-LAS-M-136, Sheet 3 LR-LAS-M-1 29, Sheets 1, 8, 9 Table 2.3.3-17 Primary Containment Ventilation System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Ducting and Components Leakage Boundary Heat Exchanger
-(Primary Containment Leakage Boundary Vent Chiller Compressor Oil Cooler) Shell Side Components Heat Exchanger
-(Primary Containment Leakage Boundary Vent Chiller Evaporator)
Tube Side Components Heat Exchanger
-(Primary Containment Leakage Boundary Vent Chiller Evaporator)
Tubes Heat Exchanger
-(Primary Containment Leakage Boundary Ventilation HX and Drywell Area Cooler)Tubes Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (Primary Containment Leakage Boundary Chilled Water Pumps)Tanks (Chilled Water Holdup and Leakage Boundary Expansion Tanks, Chilled Water Chemical Feeders)Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-107 Section 2 -Scoping and Screening Methodology and Results Table 3.3.2-17 Primary Containment Ventilation System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 2.3-108 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 2.3.3.18 Process Radiation Monitoring
 
===System Description===
The Process Radiation Monitoring System is a normally operating system designed to monitor the level of radioactivity of various process liquid and gas lines that can serve as discharge routes for radioactive materials, provide indication and record of detected levels, and for certain systems, support the prevention of an uncontrolled release of radioactive liquids, gases, and particulates by providing isolation signals to the monitored systems. The Process Radiation Monitoring System consists of safety-related and nonsafety-related portions and is in scope for license renewal. However, portions of the Process Radiation Monitoring System are not required to perform intended functions and are not in scope.The following process radiation monitors within the Process Radiation Monitoring System are safety-related:
The main steam line radiation monitors are located downstream of the outboard main steam isolation valves, providing indication of radiation levels external to the main steam lines. An abnormal high radiation condition indicates a release of fission products from the fuel and results in a control room alarm.The Reactor Building ventilation exhaust radiation monitors indicate and record radiation levels from the vent plenum upstream of the duct isolation valves. An abnormal high radiation condition results in automatic isolation of the reactor building ventilation system (part of the license renewal Safety-Related Ventilation System), start of the Standby Gas Treatment System, closure of primary containment purge and vent valves, and a control room alarm.The fuel floor vent plenum exhaust radiation monitors indicate and record radiation levels from the fuel floor area vent exhaust duct upstream of the duct isolation valves. An abnormal high radiation condition results in automatic isolation of the Reactor Building ventilation system, start of the Standby Gas Treatment System, closure of primary containment purge and vent valves, and a control room alarm.The control room ventilation intake radiation monitors indicate and record radiation levels from the duct supplying outside air to the main control room. An abnormal high radiation condition results in isolation of the normal outside air supply and a control room alarm. Outside air is then routed through an emergency makeup air filter train to the Control Room Ventilation System, The standby gas treatment stack effluent monitor draws a sample from the Standby Gas Treatment System stack exhaust whenever the system is operating.
Indication of radiation level is provided in the control room. An abnormal high radiation condition results in a control room alarm.The following process radiation monitors within the Process Radiation Monitoring System are nonsafety-related:
The residual heat removal (RHR) service water (part of the Essential Cooling Water license renewal system) effluent radiation monitors are located on the cooling water piping downstream of each of the two RHR heat exchangers.
Indication of radiation level is provided in the control room. An abnormal high radiation condition results in a control room alarm.LaSalle County Station, Units 1 and 2 2.3-109 License Renewal Application Section 2 -Scoping and Screening Methodology and Results The service water (part of the Non-Essential Cooling Water license renewal system) effluent radiation monitor is located at the inlet to the circulating water standpipe prior to discharge to the cooling lake. Indication of radiation level is provided in the control room. An abnormal high radiation condition results in a control room alarm.The liquid radwaste effluent radiation monitor is located on the radwaste effluent line prior to mixing with lake blowdown flow prior to entering the river. Indication of radiation level is provided in the control room. An abnormal high radiation condition results in automatic isolation of the effluent discharge valve and a control room alarm.The reactor building closed cooling water (RBCCW) (part of the Closed Cycle Cooling Water license renewal system) radiation monitor is located upstream of the RBCCW heat exchangers to provide indication of leakage into the system from higher pressure contaminated systems.Indication of radiation level is provided in the control room. An abnormal high radiation condition results in a control room alarm.The off-gas pre-treatment monitor draws an off-gas sample from the downstream side of the recombiner upstream of the charcoal beds. Indication of radiation level is provided in the control room. An abnormal high radiation condition results in a control room alarm.The off-gas post-treatment monitor draws an off-gas sample from the downstream side of the charcoal beds upstream of the discharge valve. Indication of radiation level is provided in the control room. An abnormal high radiation condition results in automatic closure of the carbon bed filter bypass valve if it is open, opening of the off-gas valve to the carbon bed if it is closed, closure of the off-gas system outlet and drain valves, and a control room alarm.The off-gas carbon bed vault monitor is located in the carbon vault area. Indication of radiation level is provided in the control room. An abnormal high radiation condition results in a control room alarm.The station vent stack effluent radiation monitor draws a sample from the station vent stack exhaust. Indication of radiation level is provided in the control room. An abnormal high radiation condition results in a control room alarm.For more detailed information, see UFSAR Sections 6.4, 7.1.2, 7.3.4, 7.6.1, 7.7.14, 9.4.1, and 11.5.Boundary The scoping evaluation boundary for the Process Radiation Monitoring System begins at the sample panel inlet valve on each of the following sample panels: RHR service water effluent monitor loops A and B, RBCCW monitor, service water effluent monitor, and liquid radwaste effluent monitor. The scoping boundary continues through the sample pump, sample chamber, flow control valve, flow indicator, and ends at the sample panel outlet valve, from which the sample is routed back to the process piping. The components within these boundaries are all nonsafety-related, but located within the Reactor Buildings and Auxiliary Buildings.
Therefore, they are within the scope of license renewal to support (a)(2) spatial and/or structural support functions.
The scoping boundary for the radiation monitor systems for the main steam lines, control room LaSalle County Station, Units 1 and 2 2.3-110 License Renewal Application Section 2 -Scoping and Screening Methodology and Results air intake, reactor building ventilation exhaust, and fuel floor vent plenum exhaust only includes the radiation elements since the radiation elements are external to the process flow path and do not have associated tubing or piping components.
These radiation elements are safety-related components that are within the scope of license renewal. The scoping boundary for the off-gas gas carbon bed vault radiation monitor system also only includes the radiation elements since the radiation elements are external to the process flow path and do not have associated tubing or piping components.
These radiation elements are nonsafety-related, do not have intended functions, and therefore are not within the scope of license renewal.The scoping boundary for the off-gas pre-treatment and off-gas post-treatment radiation monitors begins and ends at the piping connections to the associated sample panels and includes all piping components, sample pumps, and instrumentation on the panels. These radiation monitoring systems are nonsafety-related and do not have the potential for spatial interaction with safety- related equipment since they do not contain fluids. Therefore they do not have intended functions and are not within the scope of license renewal.The scoping boundary for the standby gas treatment stack effluent monitor begins at the piping connections to the standby gas treatment stack and continues to the standby gas treatment vent monitoring panels (OPL58JA and OPL58JB) and continues via the piping that returns to the stack. The radiation elements on these monitoring panels are abandoned in place, do not have intended functions, and are not in scope for license renewal. The scoping boundary also continues to the standby gas treatment vent sample conditioner panel, continues to the standby gas treatment vent gas monitor panel, and continues via the piping that returns to the stack where the boundary ends. Included are piping components, sample pumps, and instrumentation on the panels. The components within this boundary are safety-related and within the scope of license renewal.The scoping boundary for the station vent stack effluent monitor begins at the piping connections to the station vent stack and continues to the station vent stack sample conditioner panel, continues to the station vent stack wide range gas monitor panel, and continues via the piping that returns to the stack where the boundary ends. Included are piping components, sample pumps, and instrumentation on the panels. The components within this boundary are nonsafety-related but the alarm function from the station vent stack wide range radiation monitor is credited for prompting operator actions in response to a radioactive gaseous leak abnormal operational transient.
Therefore, the station vent stack effluent monitor and associated piping components are within the scope of license renewal.All associated piping, components, and instrumentation contained within the boundary described above are also included in the Process Radiation Monitoring System scoping boundary.Also included in the Process Radiation Monitoring System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Buildings and Auxiliary Buildings.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawings for identification of this boundary, shown in red.LaSalle County Station, Units 1 and 2 2.3-111 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Not included in the Process Radiation Monitoring System scoping boundary are those portions of piping, piping components, and piping elements coming from the various plant systems connected to the radiation monitoring systems. While in scope for license renewal, they are evaluated with the license renewal system from which the fluid originates.
These systems include the Closed Cooling Water System, Nonessential Cooling Water System, Radwaste System, Essential Cooling Water System, and Standby Gas Treatment System. The station vent stack is evaluated with the Auxiliary Building Structure.
Reason for Scope Determination The Process Radiation Monitoring System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Process Radiation Monitoring System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Process Radiation Monitoring System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49). The Process Radiation Monitoring System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Sense process conditions and generate signals for reactor trip or engineered safety features actuation.
The Process Radiation Monitoring System monitors plant processes for radiation level and initiates appropriate protective action to limit the potential release of radioactive materials if predetermined levels are exceeded.
The reactor building ventilation exhaust and fuel floor vent plenum exhaust radiation monitors initiate primary and secondary containment isolation and initiate the Standby Gas Treatment System. The control room ventilation intake radiation monitors isolate the normal outside air supply. 10 CFR 54.4(a)(1)
: 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
Some nonsafety-related portions of the system provide structural restraint or support for safety-related components.
Some nonsafety-related portions of the system are liquid-filled and have the potential for spatial interaction with safety-related equipment in the Reactor and Auxiliary Buildings.
10 CFR 54.4(a)(2)
: 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The station vent stack wide range radiation monitor is credited to sense process conditions and generate signals to actuate control room alarms to prompt operator actions in response to a radioactive gas waste system leak or failure abnormal operational transient.
10 CFR 54.4(a)(2)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The Process Radiation Monitoring System includes safety-related electrical equipment that is environmentally qualified to remain functional during post-accident conditions.
10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 2.3-112 License Renewal Application Section 2 -Scoping and Screening Methodology and Results UFSAR References 6.4 7.1.2 7.3.4 7.6.1 7.7.14 9.4.1 11.5 15.7.1 License Renewal Boundary Drawinqgs LR-LAS-M-153, Sheets 1, 3, 4, 6, 7 Table 2.3.3-18 Process Radiation Monitoring System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Hoses Leakage Boundary Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Structural Integrity Pump Casing ( SGTS and SVS Wide Pressure Boundary Range Sample Pumps)Pump Casing (RHR Service Water Leakage Boundary Sample Pumps)Pump Casing (SGTS Vent Monitor Structural Integrity 0PL058 Sample Pumps)Pump Casing (Sample Pumps -Leakage Boundary Radwaste, Service Water, RBCCW)Valve Body Leakage Boundary Pressure Boundary Structural Integrity The aging management review results for these components are provided in: Table 3.3.2-18 Process Radiation Monitoring System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-113 Section 2 -Scoping and Screening Methodology and Results 2.3.3.19 Process Sampling and Post Accident Monitoring
 
===System Description===
The Process Sampling and Post Accident Monitoring System is a normally operating system designed to provide indication of critical parameters within containment, to obtain representative samples from process streams and convey them to central sample stations for use in minimizing leakage, spillage, and potential radiation exposure during normal operations, and to collect liquid and gaseous samples of the reactor coolant and containment atmosphere following a post-accident condition.
The Process Sampling and Post Accident Monitoring System consists of the containment monitoring system, process sampling system, and post-accident sampling system.Containment Monitoring System The purpose of the containment monitoring system is to provide indication and alarms for various containment parameters during normal and abnormal operating conditions.
Most of the containment monitoring system is designed to operate during and following a design basis LOCA, and is therefore safety-related.
All subsystems, except oxygen monitoring, tritium grab sample station, and continuous air monitoring (CAMS), continue to operate during LOCA conditions and are provided with redundant instrumentation which are powered by separate by ESF Division I and II AC power. It accomplishes this through the use of redundant instrumentation connected to the containment environment.
The containment monitoring system measures the following parameters:
Drywell (DW) and Suppression Chamber (SC)pressure, DW, SC and Suppression Pool (SP) temperature, SP and containment flooding water levels, DW and SC oxygen and hydrogen concentrations, DW gross radiation and DW 0 and SC airborne radiation levels.Process Sampling System The purpose of the process sampling portion of the system is to provide the capability for sampling various process systems during normal plant power operation and shutdown conditions.
Plant process sampling stations are located in the Reactor, Turbine, and Radwaste Buildings, and the River Screen House. The process sampling system has no safety-related function.
It accomplishes this purpose by taking representative samples from various process lines. The Reactor Building and Turbine Building sample stations are equipped with analyzers that continuously monitor critical parameters.
Grab samples may be taken periodically from each station to determine constituents.
At each station, samples are adjusted for pressure and temperature as required by the monitoring instruments and for operators' safety. Sample wastes are returned to the condenser, radwaste drains, or equipment drain system as appropriate.
Post-Accident Sampling The purpose of the post-accident portion of the system is to obtain representative liquid and gas grab samples from the reactor coolant system and within containments for radiological and chemical analysis under accident conditions.
The post-accident sampling system has no safety-related function.
Failure of the system does not compromise any safety-related system or component, or prevent safe shutdown of the plant. The post-accident portion of the system was originally designed to satisfy certain requirements of NUREG-0737, however elimination V of the requirements to have and maintain the post-accident sampling system, has been LaSalle County Station, Units 1 and 2 2.3-114 License Renewal Application Section 2 -Scoping and Screening Methodology and Results approved by plant license amendments.
Gaseous and liquid samples are capable of being taken by the post-accident sampling system from the suppression chamber and drywell atmospheres, secondary containment atmosphere, reactor coolant, and drywell equipment and floor drain sumps. Suppression chamber and drywell atmosphere samples are taken utilizing the containment monitoring system.Secondary containment atmosphere samples are taken from the Reactor Building in the vicinity of access doors to determine post-accident accessibility of the Reactor Building.Reactor coolant samples can be taken from the reactor recirculation inlet header and Residual Heat Removal System (RHR) loop sample points. The RHR System sample points provide suppression pool inventory samples when operating in suppression pool cooling, spray, or low pressure coolant injection modes. Fuel pool inventory liquid samples can be obtained when RHR is operating in the fuel pool cooling assist mode. Gaseous samples are returned to the suppression chamber. Liquid samples and leakage collected in the High Radiation Sampling System (HRSS) waste tank are returned either to the waste collection tank or the drywell equipment sump.For more detailed information, see UFSAR Sections 7.5.2, 9.3.2, and 11.5.5.Boundary The scoping evaluation boundary for containment monitoring system begins at various sample points located within containment and are connected to various sampling panels and instruments.
The sensing lines have installed excess flow check valves in series with manual isolation valves. Sample lines have series mounted solenoid valves on both sample source and return lines to provide containment isolation when required.
Sample stations are enclosed units preventing internal leakage from impacting surrounding in scope equipment.
The sample station enclosures are evaluated as a structural commodities as they serve as piping anchor points for (a)(1) in scope piping. Components within the sample station enclosure, not required for license renewal functions, are not in scope for spatial or structural interaction.
Portions of the containment monitoring system that are safety-related or are relied upon to support specific (a)(3) functions, are identified on boundary drawings in green. System components that are in scope for spatial interaction or structural support are shown on boundary drawings marked in red.The scoping boundary for the process sampling system begins at the point where the various process lines connect to sample panel inlet isolation valves. It continues through sample coolers and where installed, specific sampling instrumentation.
It ends where the sampled fluid is returned to the condenser, turbine building drains, reactor building equipment or floor drains, radwaste or lake sample pit based on the specific sample station. Components within the sample station enclosures, not required for license renewal functions, are not in scope for spatial interaction or structural support. The process sampling system is not safety-related and is only in scope for spatial interaction or structural support.The scoping boundary for the post-accident sampling system begins at the point where the various process lines connect to sample panel inlet isolation valves. It continues through sample coolers and where installed, specific sampling instrumentation.
Process fluids are piped to the HRSS waste tank where they can be returned to the unit waste collection tank or drywell equipment sumps based on sampling results. The scoping boundary ends where the piping system connects to the Radwaste System (waste collection tank) and the Plant Drainage System (drywell equipment drain sump). Components within the sample station LaSalle County Station, Units 1 and 2 2.3-115 License Renewal Application Section 2 -Scoping and Screening Methodology and Results enclosure, not required for license renewal functions, are not in scope for spatial interaction or structural support. The post-accident sampling system is not safety-related and is only in scope for spatial interaction or structural support.All associated piping, components, and instrumentation contained within the boundary described above are also included in the Process Sampling and Post Accident Monitoring System scoping boundary.Also included in the Process Sampling and Post Accident Monitoring System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Buildings and Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the Process Sampling and Post Accident Monitoring System scoping boundary are those portions of piping, piping component, and piping elements coming from various plant systems connected to the various sample stations.
While within the scope of license renewal, they are evaluated with the license renewal system from which the fluid originates.
Systems include Closed Cooling Water System, Condensate System, Nonessential Cooling Water System, Reactor Coolant Pressure Boundary System, Reactor Water Cleanup System, and the Residual Heat Removal System. The sample enclosures and compressed gas bottle storage racks are in scope and are evaluated with the Structural Commodity Group. The heat trace that is installed on containment monitoring piping is evaluated with the Heat Trace System.Not included in the scope of license renewal for the Process Sampling and Post Accident Monitoring System are piping and components not supporting an intended function, located within the sample enclosures surrounding the sample stations, piping racks, and sample chiller assemblies located in the Reactor Buildings, Auxiliary Building, and Turbine Building structures, as these sample enclosures contain no safety-related equipment.
The sample enclosures provide physical shielding, and the enclosed components do not have the potential for spatial interaction with safety-related components.
The sample enclosures prevent leakage or spray from impacting safety-related components.
Also not included in the scope of license renewal are the Process Sampling and Post Accident Monitoring System components within the River Screen House which do not perform or support intended functions.
Reason for Scope Determination The Process Sampling and Post Accident Monitoring System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Process Sampling and Post Accident Monitoring System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Process Sampling and Post Accident Monitoring System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63).LaSalle County Station, Units 1 and 2 2.3-116 License Renewal Application Section 2 -Scoping and Screening Methodology and Results The Process Sampling and Post Accident Monitoring System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Sense process conditions and generate signals for reactor trip or engineered safety feature actuation.
The Process Sampling and Post Accident Monitoring System includes containment pressure instrumentation that actuates a reactor trip and an actuation of emergency core cooling system and primary and secondary containment isolation.
10 CFR 54.4(a)(1)
: 2. Provide primary containment boundary.
The Process Sampling and Post Accident Monitoring System includes piping and isolation valves that are part of the primary containment boundary.
10 CFR 54.4(a)(1)
: 3. Control combustible gas mixtures in the primary containment atmosphere.
The Process Sampling and Post Accident Monitoring System includes equipment that samples the containment atmosphere and provides indication of oxygen and hydrogen concentration.
10 CFR 54.4(a)(1)
: 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
Some portions of the nonsafety-related the Process Sampling and Post Accident Monitoring System are relied upon to preserve the structural support intended function of the safety-related piping used for sampling and instrumentation as well as for containment isolation.
Some portions of the sampling system may be liquid filled and have the potential for spatial interaction with safety-related equipment found in the Reactor and Auxiliary Buildings.
10 CFR 54.4(a)(2)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48).Suppression pool instrumentation for level and temperature supports Fire Safe Shutdown requirements.
10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).Containment monitoring instrumentation is required to remain functional following a design basis LOCA. 10 CFR 54.4(a)(3)
: 7. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63).Suppression pool instrumentation for level and temperature supports Station Blackout under coping requirements.
10 CFR 54.4(a)(3)
UFSAR References 7.5.2 9.3.2 11.5.5 LaSalle County Station, Units 1 and 2 2.3-117 License Renewal Application Section 2 -Scoping and Screening Methodology and Results License Renewal Boundary Drawings LR-LAS-M-92, Sheets 1, 2 LR-LAS-M-93, Sheets 4, 5 LR-LAS-M-115, Sheets 1, 2, 12, 13, 14, 15 LR-LAS-M-138, Sheets 1, 2 LR-LAS-M-1 39, Sheets 4, 5 LR-LAS-M-1 56, Sheets 1, 2, 3, 4, 5 LR-LAS-M-158, Sheets 1, 2, 3, 4 LR-LAS-M-159, Sheets 1, 2 Table 2.3.3-19 Process Sampling and Post Accident Monitoring System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Compressor Housing Structural Integrity Flow Device Pressure Boundary Throttle Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Structural Integrity Pump Casing (H2/02 Sample Pumps) Pressure Boundary Pump Casing (HRSS Room Sump Pump) Leakage Boundary Pump Casing (HRSS Sample Pump) Leakage Boundary Pump Casing (HRSS Waste Pumps) Leakage Boundary Tanks (HRSS Waste Tank) Leakage Boundary Valve Body Leakage Boundary Pressure Boundary Structural Integrity The aging management review results for these components are provided in: Table 3.3.2-19 Process Sampling and Post Accident Monitoring System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-118 Section 2 -Scoping and Screening Methodology and Results 2.3.3.20 Radwaste System Description The intended function of the Radwaste System for license renewal is to maintain leakage boundary integrity to preclude system interactions.
For this reason, this system's pressure-retaining components located in areas where there are potential spatial interactions with safety-related equipment have been included in the scope of license renewal. This system is not required to operate to support license renewal intended functions, and is in scope only for potential spatial interaction.
The Radwaste System is a normally operating system designed to collect, monitor, process, and dispose of radioactive wastes. The Radwaste System consists of liquid, solid, and gaseous radwaste plant systems. The Radwaste System is in scope for license renewal.However, portions of the Radwaste System are not required to perform intended functions and are not in scope.Liquid Radwaste System The liquid radwaste plant system includes the waste/equipment drain processing subsystem, the floor drain processing subsystem, the chemical waste subsystem, the laundry waste subsystem, and the sludge subsystem.
The purpose of the liquid radwaste system is to collect, monitor, and process all potentially radioactive liquid wastes produced by the station.The waste/equipment drain processing subsystem collects and processes high purity (low conductivity) sources of radioactive liquid waste such as plant equipment drains. This water is treated by settling, filtration, and demineralization and is returned for station reuse through the cycled condensate storage tank (evaluated with the Condensate System).The floor drain processing subsystem collects and processes low purity (high conductivity) sources of radioactive liquid waste such as plant floor drains. This water is treated using portable vendor supplied waste treatment equipment and is returned for station reuse through the cycled condensate storage tank (evaluated with the Condensate System) or discharged from the station. The floor drain processing subsystem includes mixed bed demineralizers which may be used to assist in processing.
The chemical waste subsystem collects and processes the highest conductivity sources of radioactive liquid waste such as decontamination and laboratory drains, and, spent resin and sludge tank decantate.
This water is treated using portable vendor supplied waste treatment equipment and is returned to liquid radwaste system tanks for additional processing.
The chemical waste subsystem includes mixed bed demineralizers which may be used to assist in processing.
The laundry waste subsystem collects and processes laundry waste or other soapy, high organic radioactive liquid waste. This water is treated by filtration.
This water is discharged from the station or returned to liquid radwaste system tanks for additional processing.
The sludge subsystem provides for intermediate storage of slurries produced as a result of processing radioactive liquid wastes. Sludge subsystem tanks provide settling capability for separation of liquid and solid wastes, holdup for radioactive decay, and storage of slurries prior to transfer to the solid radwaste system.LaSalle County Station, Units 1 and 2 2.3-119 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Solid Radwaste System The purpose of the solid radwaste plant system is to process all radioactive wet solid wastes produced by the station. The solid radwaste system accomplishes this by receiving, dewatering, solidifying, packaging, handling, and providing temporary storage for radioactive wet solid wastes, such as expended demineralizer resins and spent precoat material, prior to offsite shipment and disposal.
The solid radwaste system also receives, decontaminates and/or compacts, and provides temporary storage for all radioactive dry wastes produced by the station prior to offsite shipment and disposal.Gaseous Radwaste System The purpose of the gaseous radwaste plant system is to process and control the release of gaseous radioactive wastes to the site environment.
The gaseous radwaste system accomplishes this through the use of high-temperature catalytic recombining, holdup for decay, high-efficiency particulate filtration, and charcoal adsorption prior to discharging to the station vent stack (evaluated with the Auxiliary Building structure).
For more detailed information see UFSAR Sections 11.2, 11.3, and 11.4.Boundary The Radwaste System scoping boundary encompasses the liquid-filled portions of nonsafety-related piping and equipment located in areas where there are potential spatial interactions with safety-related equipment.
This includes the liquid-filled portions of the system located within the Reactor Building and Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the Radwaste System scoping boundary are the plant drains, collection sumps, sump pumps, and sump pump discharge piping to the Radwaste System collection tanks.Plant drains, sump pumps, and sump pump discharge piping are evaluated with the Plant Drainage System. Collection sumps are evaluated with the structure where they are located.Not included in the Radwaste System scoping boundary is the standby gas treatment system wide range gas monitoring sample pump. The standby gas treatment system wide range gas monitoring sample pump is evaluated with the Process Radiation Monitoring system.Reason for Scope Determination The Radwaste System is not in scope under 10 CFR 54.4(a)(1) because no portions of the system are safety-related or relied upon to remain functional during and following design basis events. The Radwaste System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Radwaste System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).LaSalle County Station, Units 1 and 2 2.3-120 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Intended Functions 1. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Radwaste System contains nonsafety-related fluid filled lines in the Reactor Building and Auxiliary Building which have potential spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References 1.2.3.4 2.4.12 3.1.2.6.2.3 Table 3.2-1 7.7.10 7.7.11 11.2 11.3 11.4 11.5.2.3.3 License Renewal Boundary Drawings LR-LAS-M-97, Sheet 1 LR-LAS-M-103, Sheets 15, 16, 27 LR-LAS-M-113, Sheet 1 LR-LAS-M-143, Sheet 1 LR-LAS-M-1 53, Sheet 4 Table 2.3.3-20 Radwaste System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Piping, piping components, and piping Leakage Boundary elements Pump Casing (Cleanup Phase Separator Leakage Boundary Sludge Pump)Tanks (RWCU Cleanup Phase Leakage Boundary Separators)
Valve Body Leakage Boundary The aging management review results for these components are provided in: Table 3.3.2-20 Radwaste System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 2.3-121 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 2.3.3.21 Reactor Water Cleanup System Description The Reactor Water Cleanup (RWCU) System is designed to maintain high purity reactor water. The RWCU system may be operated at any time during reactor operations (normal, startup, shutdown, hot standby, and refueling) or may be shutdown when not required to clean up reactor coolant.The purpose of the RWCU System is to: remove solid and dissolved impurities from recirculated reactor coolant; discharge excess reactor water during startup, shutdown, and hot standby conditions; minimize temperature gradients in the recirculation piping and vessel during periods of low flow rates; and conserve reactor heat. The RWCU System accomplishes these purposes by forced circulation of reactor coolant through regenerative and non-regenerative heat exchangers and filter-demineralizers.
The RWCU System also provides for monitoring the durability and effectiveness of noble metal compounds deposited on reactor vessel and piping surfaces.
The RWCU System accomplishes this by processing reactor coolant through a material monitoring system and a data acquisition system.The RWCU System includes a safety-related and environmentally qualified remote manual-operated primary containment isolation valve on the return line to the reactor which provides for long-term leakage control in the event of a piping failure in the RWCU System. A nonsafety-related and non-environmentally qualified check valve is provided for instantaneous reverse flow isolation.
The RWCU System is a high energy system and includes safety-related flow elements and instrumentation for the determination of RWCU System high differential flow. The high differential flow signal is an indication of leakage or a break in RWCU piping and is used to automatically isolate the RWCU system from the reactor coolant pressure boundary.The RWCU blowdown flow control valve, RWCU discharge to main condenser valve, and RWCU drain to waste surge tanks valve are credited as high-low pressure interfaces for Fire Safe Shutdown.For more detailed information see UFSAR Section 5.4.8.Boundary The RWCU System license renewal scoping boundary begins downstream of the RWCU System suction outboard containment isolation valve. The boundary continues through the two RWCU recirculation pumps, the common pump discharge header, the tube sides of the two regenerative heat exchangers, the tube sides of the two non-regenerative heat exchangers (the shell sides are evaluated with the Closed Cycle Cooling Water System), and the three cleanup filter demineralizers, including associated backwash and precoat equipment.
The boundary then continues through the shell sides of the two regenerative heat exchangers, the RWCU return containment isolation valve, and then ends at the attachments to the Feedwater System. The RWCU System license renewal scoping boundary includes blowdown lines to the main condenser (evaluated with the Condenser and Air Removal System) and waste surge tanks (evaluated with the Radwaste System).LaSalle County Station, Units 1 and 2 2.3-122 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Included in the RWCU System license renewal scoping boundary are the material monitoring system and a data acquisition system which monitor the durability and effectiveness of noble metal compounds deposited on reactor vessel internals and reactor coolant pressure boundary piping surfaces.
The material monitoring system samples reactor coolant from the common discharge header of the RWCU pumps and returns reactor coolant to the common header upstream of the RWCU pumps.All associated piping, components and instrumentation contained within the boundary described above are also included in the RWCU System scoping boundary.Also included in the RWCU System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Building and Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the RWCU System scoping boundary are the reactor coolant pressure boundary and containment isolation piping and components associated with the suction portion of the system which are evaluated with the Reactor Coolant Pressure Boundary System.Reason for Scope Determination The Reactor Water Cleanup System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Reactor Water Cleanup System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Reactor Water Cleanup System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48) and Environmental Qualification (10 CFR 50.49). The Reactor Water Cleanup System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62) and Station Blackout (10 CFR 50.63).Intended Functions 1. Provide reactor coolant pressure boundary.
The RWCU System includes a safety-related remote manual-operated valve on the return line to the reactor to provide long-term leakage control in the event of a piping failure in the RWCU System. 10 CFR 54.4(a)(1)
: 2. Provide primary containment boundary.
The RWCU System includes a safety-related remote manual-operated primary containment isolation valve on the return line to the reactor.10 CFR 54.4(a)(1)
: 3. Sense process conditions and generate signals for reactor trip or engineered safety LaSalle County Station, Units 1 and 2 2.3-123 License Renewal Application Section 2 -Scoping and Screening Methodology and Results features actuation.
The RWCU System includes safety-related flow elements and instrumentation for the determination of RWCU System high differential flow. The high differential flow signal is an indication of leakage or a break in RWCU piping and is used to automatically isolate the RWCU System from the reactor coolant pressure boundary.
10 CFR 54.4(a)(1)
: 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The RWCU System contains nonsafety-related high energy and moderate energy lines in the Reactor Building and Auxiliary Building which provide structural support or have potential spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The RWCU blowdown flow control valve, RWCU discharge to main condenser valve, and RWCU drain to waste surge tanks valve are credited as high-low pressure interfaces for Fire Safe Shutdown.10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The RWCU System includes an environmentally qualified remote manual-operated valve on the return line to the reactor. 10 CFR 54.4(a)(3)
UFSAR References 1.2.2.3.5 1.2.2.6.6 Table 3.2-1 5.2.5 Table 5.2-8 5.4.8 6.2.4.2.1 Table 6.2-21 Table 6.2-28 7.3.2.2.3.8 7.6.2.2.6 7.7.8 Appendix C License Renewal Boundary Drawings LR-LAS-M-97, Sheets 1, 2, 3, 4, 5 LR-LAS-M-143, Sheets 1, 2, 3, 4, 5 LR-LAS-M-57, Sheet 1 LR-LAS-M-91, Sheets 1, 2 LR-LAS-M-100, Sheet 1 LR-LAS-M-103, Sheets 15,16, 19 LR-LAS-M-115, Sheets 1, 12 LR-LAS-M-118, Sheet 1 LR-LAS-M-1 37, Sheets 1, 2 LR-LAS-M-146, Sheet 1 0 LR-LAS-M-159, Sheet 1 LaSalle County Station, Units I and 2 2.3-124 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.3-21 Reactor Water Cleanup System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Heat Exchanger
-(Clean-Up Leakage Boundary Regenerative Heat Exchangers)
Shell Side Components Heat Exchanger
-(Clean-Up Leakage Boundary Regenerative Heat Exchangers)
Tube Side Components Heat Exchanger
-(Clean-up Non- Leakage Boundary Regenerative Heat Exchanger)
Tube Side Components Heat Exchanger
-(RWCU Pump Heat Leakage Boundary Exchanger)
Shell Side Components Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Pump Casing (Clean-Up Filter Leakage Boundary Demineralizer Holding Pump)Pump Casing (Clean-Up Filter Leakage Boundary Demineralizer Precoat Pump)Pump Casing (Reactor Water Clean-Up Leakage Boundary Recirculation Pump)Tanks (Clean-Up Filter Demineralizer Leakage Boundary Precoat Tank)Tanks (Clean-Up Filter Demineralizer)
Leakage Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-21 Reactor Water Cleanup System Summary of Aging Management Evaluation LaSalle County Station, Units I and 2 License Renewal Application 2.3-125 Section 2 -Scoping and Screening Methodology and Results 2.3.3.22 Safety-Related Ventilation
 
===System Description===
The Safety-Related Ventilation (SRV) System is a normally operating system designed to provide a favorable environment for plant equipment and personnel while preventing the spread of contamination in the plant. The SRV System also includes dampers and ductwork that are part of the secondary containment boundary.
The SRV System is in scope for license renewal. However, portions of the SRV System are not required to perform intended functions and are not in scope. The SRV license renewal system consists of the following plant systems: Reactor Building ventilation system, ECCS equipment cooling ventilation system, diesel generator room ventilation system, switchgear heat removal system, and Turbine Building ventilation system.Reactor Building Ventilation The Reactor Building ventilation plant system provides filtered outdoor air to control the Reactor Building temperature in generally accessible areas, and to maintain a minimum negative pressure of 0.25 inches of water with respect to atmospheric pressure.
The system performs the safety-related functions to close isolation dampers when secondary containment isolation is required, isolate the main steam tunnel in the event of a pipe break in the tunnel, and isolate the fuel pool area exhaust ducts during a fuel drop accident.
Additionally, the exhaust duct pressure relief dampers and excess flow check dampers ensure the integrity of the Seismic Category I exhaust plenum walls.ECCS Equipment Cooling Ventilation The ECCS equipment cooling ventilation plant system performs the safety-related function to provide cooling to the ECCS equipment cubicles whenever the ECCS equipment is required for service. The system removes equipment heat from the ECCS equipment areas and maintains temperatures within equipment limits.Diesel Generator Room Ventilation The diesel generator room ventilation plant system provides safety-related ventilation to the diesel generator rooms, the diesel generator storage tank rooms, the diesel generator day tank rooms, the high pressure core spray (HPCS) diesel generator cooling water pump rooms, and the HPCS switchgear rooms and battery rooms. The system maintains area temperatures within equipment requirements, and provides ventilation to the diesel generators.
Switchgear Heat Removal The switchgear heat removal plant system provides safety-related ventilation to the reactor protection system MG Set room, the essential switchgear areas, and battery rooms. The system removes equipment heat to maintain area temperatures within equipment requirements.
Turbine Building Ventilation The Turbine Building ventilation plant system provides ventilation to operating areas in the Turbine Building to maintain area temperatures within equipment requirements.
The steam LaSalle County Station, Units 1 and 2 2.3-126 License Renewal Application Section 2 -Scoping and Screening Methodology and Results tunnel check dampers in this system perform a safety-related function to close during high energy line break conditions to form a pressure boundary between the main steam tunnel and the HPCS switchgear room. The Turbine Building ventilation exhaust through the station vent stack provides a pathway for the potential release of fission products following certain abnormal operating conditions.
For more detailed information, see UFSAR Sections 6.2.3, 7.3.7, 9.4.2, 9.4.4, 9.4.5, and 15.7.1.Boundary The SRV System license renewal scoping boundary includes the following plant systems as discussed in the System
 
== Description:==
 
Reactor Building ventilation system, ECCS equipment cooling ventilation system, diesel generator room ventilation system, switchgear heat removal system, and Turbine Building ventilation system. The scoping boundary begins where outside air provides fresh air to supply fans and ends where exhaust air either exits the structure or enters the ventilation stack for each plant system. The scoping boundary includes inlet filters, supply and exhaust fans, associated dampers, ductwork, instrumentation, and controls.The portion of the SRV System which is in scope for license renewal includes secondary containment isolation dampers and associated ductwork; the spent fuel pool exhaust ducts from elevation 843'6" to elevation 736'6" inside the Reactor Building; and the steam tunnel isolation dampers. The SRV System also includes the ECCS equipment cooling ventilation equipment including the cubicle cooling fans and coils and associated ductwork.
Also included are the diesel generator room ventilation and switchgear heat removal plant systems, which include supply and exhaust fans, filters and associated dampers and ductwork, and the Turbine Building ventilation exhaust to the plant vent stack and associated components and ductwork.
The SRV boundary also includes the associated instrumentation and controls for the above equipment.
All associated piping, components, and instrumentation contained within the boundary described above are also included in the SRV System scoping boundary.Also included in the SRV System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Buildings.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function, specifically the CSCS equipment area cubicle cooler drain pans.For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the SRV System scoping boundary are the components associated with the cooling water supply to the ECCS equipment cubicle coolers which are evaluated with the Essential Cooling Water System. Additionally, the fire protection function of fire dampers is evaluated with the Fire Protection System. The ventilation stack that receives exhaust air from the Reactor Building ventilation system is evaluated with the Auxiliary Building Structure.
The SRV system interfaces with the heat recovery plant system, which heats the air entering the building.
The heat recovery subsystem components are evaluated with the Nonsafety-Related Ventilation System.LaSalle County Station, Units 1 and 2 2.3-127 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Not included in the scope of license renewal are the nonsafety-related portions of the Reactor Building and Turbine Building ventilation systems since they do not perform or support system intended functions.
Reason for Scope Determination The Safety-Related Ventilation System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Safety-Related Ventilation System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Safety-Related Ventilation System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63). The Safety-Related Ventilation System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Maintain emergency temperature limits within areas containing safety-related components.
The SRV System maintains environmental conditions to ensure that the operability of safety-related equipment in the ECCS equipment rooms, the diesel generator rooms, and the essential switchgear rooms is maintained.
10 CFR 54.4(a)(1)
: 2. Provide secondary containment boundary.
The SRV System contains isolation dampers which close when secondary containment isolation is required.
10 CFR 54.4(a)(1)
: 3. Provide a pathway to the station vent stack for the potential release of fission products following certain abnormal operating conditions.
10 CFR 54.4(a)(2)
: 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The SRV System includes water filled components that have the potential for spatial interactions (spray or leakage) with safety-related SSCs. 10 CFR 54.4(a)(2)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The ECCS equipment cooling ventilation, diesel generator room ventilation, and switchgear heat removal plant portions of the SRV license renewal system are relied upon to operate during a Fire Safe Shutdown event. 10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The ECCS equipment cooling ventilation and the Reactor Building ventilation portions of the SRV System contain components that are environmentally qualified.
10 CFR 54.4(a)(3)
: 7. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The SRV System is relied upon to provide equipment cooling for the diesel generators and other safety-LaSalle County Station, Units 1 and 2 2.3-128 License Renewal Application Section 2 -Scoping and Screening Methodology and Results related equipment during SBO coping and recovery.
10 CFR 54.4(a)(3)
UFSAR References 6.2.3 7.3.7 9.4.2 9.4.4 9.4.5 15.7.1 License Renewal Boundary Drawings LR-LAS-M-92, Sheet 1 LR-LAS-M-1 04, Sheet 1 LR-LAS-M-129, Sheet 1 LR-LAS-M-1 38, Sheet 1 LR-LAS-M-149, Sheet 1 LR-LAS-M-1444, Sheet 1 LR-LAS-M-1445, Sheet I LR-LAS-M-1446, Sheet 1 LR-LAS-M-1447, Sheet 1 LR-LAS-M-1455, Sheets 1, 2, 3 LR-LAS-M-1459, Sheets 1, 2 LR-LAS-M-1460, Sheets 1, 2 LR-LAS-M-1456, Sheets 1, 2, 3 LR-LAS-M-1462, Sheets 1, 2 LR-LAS-M-1463, Sheet 1 LR-LAS-M-1464, Sheet 1 LR-LAS-M-1465, Sheet 1 LaSalle County Station, Units 1 and 2 2.3-129 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.3-22 Safety-Related Ventilation System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Ducting and Components Leakage Boundary Pressure Boundary Flexible Connection Pressure Boundary Heat Exchanger
-(CSCS Equipment Area Heat Transfer Cubicle Coolers) Fins Heat Exchanger
-(CSCS Equipment Area Pressure Boundary Cubicle Coolers) Shell Side Components Heat Exchanger
-(CSCS Equipment Area Heat Transfer Cubicle Coolers) Tubes Pressure Boundary Piping, piping components, and piping Pressure Boundary elements Valve Body Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-22 Safety-Related Ventilation System Summary of Aging Management Evaluation 0 LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-130 Section 2 -Scoping and Screening Methodology and Results 2.3.3.23 Standby Liquid Control System Description The Standby Liquid Control (SLC) System is a standby system that is manually operated to shutdown the reactor if the normal reactivity control provisions become inoperative.
The system is designed to bring the reactor to a shutdown condition at any time in core life independent of control rod insertion capability.
The most severe requirement for which the system is designed is shutdown from a full power operating condition assuming complete failure of the Control Rod Drive (CRD) System to respond to a scram signal. The SLC System is in scope for license renewal. However, portions of the SLC System are not required to perform intended functions and are not in scope.The primary purpose of the SLC System is to shutdown the reactor independent of the CRD System. The SLC System accomplishes this purpose by injecting sodium pentaborate solution directly into the reactor vessel to absorb thermal neutrons.
The SLC System operation is also credited during a Loss of Coolant Accident to maintain suppression pool water pH at acceptable levels to minimize the radiological release to the environment.
The SLC System is capable of satisfying the requirements of the system generic design basis as well as the requirement for the reduction of risks from an Anticipated Transient Without Scram (ATWS) as specified in 10 CFR 50.62 (ATWS Rule).For more detailed information see UFSAR Section 9.3.5.Boundary The SLC System license renewal scoping boundary begins at the SLC solution tank and continues through two positive displacement pumps, pulsation dampeners, pump discharge relief valves, and up to two parallel explosive actuated valves that open upon SLC System manual initiation.
Also included in the system boundary are the electric heaters and air sparger within the SLC solution tank, heat tracing on piping that normally contains sodium pentaborate solution, and the SLC test tank.All associated piping, components and instrumentation contained within the boundary described above are included in the SLC System boundary.Also included in the SLC System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Buildings.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of the system. For more information, refer to the License Renewal Boundary Drawing for identification of the boundary, shown in red.Not included in the SLC System scoping boundary are the piping and components from the two parallel explosive actuated injection valves to the nozzle on the reactor pressure vessel which are evaluated with the Reactor Coolant Pressure Boundary System. The SLC injection line within the reactor vessel is evaluated with the Reactor Vessel Internals.
The heat trace that is installed on the SLC System piping that normally contains SLC solution while the LaSalle County Station, Units 1 and 2 2.3-131 License Renewal Application Section 2 -Scoping and Screening Methodology and Results system is in standby mode is evaluated with the Heat Trace System.Reason for Scope Determination The Standby Liquid Control System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Standby Liquid Control System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Standby Liquid Control System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62). The Standby Liquid Control System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63).Intended Functions 1. Introduce emergency negative reactivity to make the reactor subcritical.
The SLC System provides backup capability for reactivity control, independent of normal reactivity control provisions in the nuclear reactor, to be able to shutdown the reactor if the normal control ever becomes inoperative.
10 CFR 54.4(a)(1)
: 2. Control and treat radioactive materials released to the secondary containment.
In the event of a Loss of Coolant Accident, the SLC System is manually initiated from the control room to pump sodium pentaborate into the reactor to maintain suppression pool pH at a level of 7.0 or higher to minimize iodine releases from primary containment to the environment.
10 CFR 54.4(a)(1)
: 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The SLC System includes nonsafety-related fluid filled lines in the Reactor Building which have the potential for spatial and structural interaction with safety-related SSCs. 10 CFR 54.4(a)(2)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transients Without Scram (10 CFR 50.62). The SLC System injects sodium pentaborate solution into the reactor to achieve shutdown for mitigation of an Anticipated Transient Without Scram. 10 CFR 54.4(a)(3)
UFSAR References 9.3.5 7.4.2 Table 3.2-1 Table 6.2-28 15.8 License Renewal Boundary Drawings LR-LAS-M-99, Sheet 1 LR-LAS-M-145, Sheet 1 LaSalle County Station, Units 1 and 2 2.3-132 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.3-23 Standby Liquid Control System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Structural Integrity Pump Casing (SLC Pump) Pressure Boundary Tanks (SLC Solution Tank) Pressure Boundary Tanks (SLC Test Tank) Leakage Boundary Valve Body Leakage Boundary Pressure Boundary Structural Integrity The aging management review results for these components are provided in: Table 3.3.2-23 Standby Liquid Control System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-133 Section 2 -Scoping and Screening Methodology and Results 2.3.3.24 Suppression Pool Cleanup System Description The intended function of the Suppression Pool Cleanup (SPC) System for license renewal is to maintain leakage boundary integrity to preclude system interactions.
For this reason, this system's pressure-retaining components located in areas where there are potential spatial interactions with safety-related equipment have been included in the scope of license renewal.This system is not required to operate to support license renewal intended functions, and is in scope only for potential spatial interaction.
The SPC System is a normally operating system designed to provide a means of improving the quality of the water in the suppression pool and transferring suppression pool water to the reactor well and the dryer-separator well in support of refueling operations.
The SPC System can also be used to transfer suppression pool water to the main condenser.
The SPC System does not have any safety-related functions.
The SPC System is in scope for license renewal.However, portions of the SPC System are not required to perform intended functions and are not in scope.The SPC System includes two pumps for each unit that can be aligned to circulate water from the suppression pool via Residual Heat Removal (RHR) System piping, through the condensate prefilters and polishers, and back to the suppression pool to improve suppression pool water chemistry parameters.
The SPC pumps can also be aligned to discharge suppression pool water to the main condenser via Feedwater System piping or to the reactor well or the dryer/separator pit via Fuel Pool Cooling and Storage System piping. The SPC System can also be aligned to provide a flowpath from the fuel pool cooling demineralizers to the suppression pool to drain the reactor well or the dryer/separator pit. All SPC System piping interconnections with the RHR System, Feedwater System, Fuel Pool Cooling and Storage System and Condensate System are via removable piping spool pieces that are physically removed with blank flanges installed during plant operation.
For more detailed information see UFSAR Section 9.2.11.Boundary The SPC System scoping boundary encompasses the liquid-filled portions of the nonsafety-related piping and equipment located in areas where there are potential spatial interactions with safety-related equipment.
This includes the liquid-filled portions of the system located within the Reactor Buildings, Turbine Buildings, and Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Reason for Scope Determination The Suppression Pool Cleanup System is not in scope under 10 CFR 54.4(a)(1) because no portions of the system are safety-related or relied upon to remain functional during and following design basis events. The Suppression Pool Cleanup System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Suppression Pool Cleanup System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon in LaSalle County Station, Units 1 and 2 2.3-134 License Renewal Application Section 2 -Scoping and Screening Methodology and Results safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The SPC System contains nonsafety-related fluid filled lines in the Reactor Buildings, Turbine Buildings, and Auxiliary Building which have potential spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References 9.2.11 License Renewal Boundary Drawings LR-LAS-M-91, Sheets 1, 5 LR-LAS-M-96, Sheets 3, 5 LR-LAS-M-1 37, Sheets 1, 5 LR-LAS-M-142, Sheets 3, 5 Table 2.3.3-24 Suppression Pool Cleanup System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Piping, piping components, and piping Leakage Boundary elements Pump Casing (Suppression Pool Cleanup Leakage Boundary Pump)Valve Body Leakage Boundary The aging management review results for these components are provided in: Table 3.3.2-24 Suppression Pool Cleanup System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-135 Section 2 -Scoping and Screening Methodology and Results 2.3.3.25 Traversing Incore Probe System Description The Traversing Incore Probe (TIP) System is a standby system designed to calibrate the Local Power Range Monitor (LPRM) Neutron Monitoring System detectors and update parameters that incorporate LPRM and TIP data into local power distribution calculations.
The TIP System includes mechanical components that provide primary containment boundaries and support insertion and withdrawal of neutron flux detectors into the reactor core.The purpose of the TIP System is to measure local neutron flux at various locations throughout the core in support of calibrating the LPRMs. The TIP System accomplishes its purpose by utilizing five neutron monitoring detectors and positioning systems capable of moving the flux detectors to various locations in the core corresponding to the locations of the LPRM detectors.
The moveable TIP detectors generate signals that are processed to indicate local power in the vicinity of each LPRM detector.
The TIP System is in scope for license renewal.However, portions of the TIP System are not required to perform intended functions and are not in scope.The five TIP detectors are normally fully withdrawn from the core and stored outside of primary containment within a radiation shield chamber. Each detector has a drive mechanism that includes a motor and drive reel assembly.
The detectors are attached to a drive and signal cable that that inserts and retracts the detector from the reactor core, driven by the drive mechanism.
Digital position indicators provide continuous indication of detector position and core top and core bottom position for the selected location.
TIP guide tubing provides a guide for the TIP detector throughout its travel from the shield chamber to the core top position inside the reactor vessel. An indexing mechanism associated with each detector allows the selection of the core locations, including a core location common to all five detectors used for cross-calibrating the detectors.
The TIP flux probe monitor consists of a dual channel amplifier and a power supply. The amplifier conditions the detector signal to provide an input to the plant computer for determining local power. The power supply provides operating power to the flux amplifier and to the detector.
A drive control unit in the main control room provides control of detector insertion and retraction and displays TIP detector location, drive speed, travel limits, indexer alignment status, and ball valve position.Each of the five drive mechanism trains includes an explosive-actuated shear valve and a ball valve located outside primary containment that perform a primary containment isolation function.
The ball valve is normally closed except when the detector is inserted.
The ball valve can be manually controlled, but is normally opened and closed automatically, with interlocks to open the valve when the detector leaves the shield, and to de-energize the drive mechanism should the ball valve not open after the insert operation is selected for the TIP detector.
Upon receipt of a primary containment isolation signal, an inserted TIP detector is fully retracted and the ball valve automatically closes when the detector reaches the shield chamber. The explosive-actuated shear valve is used only to isolate the guide tube while a detector is inserted past the ball valve and power is lost to the drive mechanism or some other fault has occurred which prevents retraction of the TIP detector and closure of the ball valve.A key-lock switch manually activates the explosive-actuated shear valve. When actuated, a guillotine cuts the TIP guide tube and detector cable inside it, sealing the guide tube.The Drywell Pneumatic System provides a purge supply of nitrogen to the TIP indexing mechanisms within containment.
The Compressed Air System provides a purge supply of dry LaSalle County Station, Units 1 and 2 2.3-136 License Renewal Application Section 2 -Scoping and Screening Methodology and Results air to the TIP drive mechanisms outside of containment.
The majority of the TIP System is not in scope for license renewal. However, the portions that maintain the primary containment boundary are in scope for license renewal.For more detailed information, see UFSAR Section 7.7.6.4.Boundary The TIP system license renewal scoping boundary begins outside containment at the TIP drive mechanisms and includes the detectors, drive reel assembly, and drive and signal cable. The boundary continues to TIP guide tubes to detector shield chambers, shear valves, ball valves, and to the primary containment penetrations.
Inside primary containment, the TIP guide tubes continue to the TIP indexing mechanisms, from which multiple TIP guide tubes continue to the reactor vessel. Included are the five-way connector (which provides a pathway for each indexing mechanism to send a detector to the same location for calibration), drive and signal cables, detectors, and electronic equipment necessary to obtain and process the TIP signals.The portion of the TIP System that has primary containment boundary function is in scope for license renewal. This includes shear valves, ball valves, and TIP guide tubing from the shear valve assembly on each of the five TIP system trains, through the downstream ball valves to the primary containment penetration.
Not included in the TIP System scoping boundary are the dry tubes inside the reactor vessel which are evaluated with the Reactor Vessel Internals.
Not included in the TIP System scoping boundary are the TIP guide tube primary containment penetrations which are evaluated with the Primary Containment structure.
Not included in the TIP System are the valves and piping components that provide a nitrogen purge supply to the TIP indexing mechanisms which are evaluated with the Drywell Pneumatic System.Not included in the TIP System are the valves and piping components that provide a dry air purge supply to the TIP drive mechanisms which are evaluated with the Compressed Air System.Reason for Scope Determination The Traversing Incore Probe System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Traversing Incore Probe System is not in scope under 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system would not prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Traversing Incore Probe System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).LaSalle County Station, Units 1 and 2 2.3-137 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Intended Functions 1. Provide primary containment boundary.
The TIP System ball valves, shear valves, and TIP tubing between the shear valves and the primary containment penetrations form a primary containment boundary.
10 CFR 54.4(a)(1)
UFSAR References 7.7.6.4 Table 3.2-1 Table 6.2-21 License Renewal Boundary Drawings None.Table 2.3.3-25 Traversing Incore Probe System Components Subject to Aging Management Review Component Type Intended Function Piping, piping components, and piping Pressure Boundary elements Valve Body Pressure Boundary The aging management review results for these components are provided in: Table 3.3.2-25 Traversing Incore Probe System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-138 Section 2 -Scoping and Screening Methodology and Results 2.3.4 STEAM AND POWER CONVERSION SYSTEM The following systems are addressed in this section:* Condensate System (2.3.4.1)* Condenser and Air Removal System (2.3.4.2)* Feedwater System (2.3.4.3)* Main Steam System (2.3.4.4)* Main Turbine and Auxiliaries System (2.3.4.5)LaSalle County Station, Units 1 and 2 2.3-139 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 2.3.4.1 Condensate
 
===System Description===
The Condensate System is a normally operating system designed to provide filtered and demineralized condensate from the condenser hotwell to the Feedwater System. The Condensate System also provides for the storage of clean and cycled condensate water for use in normal plant operations and refueling operations.
The Condensate System consists of the following plant systems: acid feed, caustic handling, clean condensate, condensate, condensate booster, condensate polishing, cycled condensate gland water, and cycled condensate.
The Condensate System is in scope for license renewal. However, portions of the Condensate System are not required to perform intended functions and are not in scope.Acid Feed and Caustic Handling Systems Acid and caustic are no longer used for resin regeneration at LaSalle. The acid and caustic storage and day tanks have been abandoned in place. The tanks contents have been removed and the tanks neutralized and cleaned. The tanks have been isolated, vented, and drained. Therefore, these tanks do not create the potential for spatial interaction and are not in scope for license renewal.Clean Condensate System The purpose of the clean condensate system is to provide clean (non-contaminated) reactor grade water to various plant systems. The clean condensate system accomplishes this by distributing clean condensate from the clean condensate storage tank to plant equipment and water service connections located in the Turbine Building, Radwaste Building, Offgas Building, Service Building, Auxiliary Building, Reactor Building, Diesel Generator Building, and other areas in the plant.Clean condensate is also provided to water service connections inside the primary containment for use during reactor shutdown and outages. The clean condensate supply lines which penetrate the primary containment are equipped with manually operated primary containment isolation valves.Condensate and Condensate Booster System The purpose of the condensate and condensate booster systems is to provide a means of transferring water from the condenser hotwell to the suction of the reactor feed pumps. The condensate and condensate booster systems also provide cooling for the steam jet air ejectors, steam packing exhauster, offgas condenser, and low pressure heaters. The condensate and condensate booster systems accomplish this by taking suction from the condenser hotwell using the condensate pumps, delivering the condensate through the steam jet air ejector condensers, gland steam packing exhauster condensers, off-gas condensers, and condensate polishing system to the condensate booster pumps, which discharge through the low-pressure feedwater heaters to the reactor feed pumps.Condensate Polishing System The purpose of the condensate polishing system is to remove dissolved and suspended solids LaSalle County Station, Units 1 and 2 2.3-140 License Renewal Application Section 2 -Scoping and Screening Methodology and Results from the condensate in order to maintain high quality reactor feedwater.
The condensate polishing system accomplishes this by processing condensate through prefilters and condensate demineralizers.
Cycled Condensate Gland Water System The purpose of the gland water system is to provide gland water to various nonsafety-related plant pumps. The gland water system accomplishes this by providing cycled condensate from the cycled condensate gland seal head tank to each pump gland.Cycled Condensate System The purpose of the cycled condensate system is to provide the necessary source of condensate (potentially contaminated) to various systems in the plant and also to provide additional water for on-line and refueling activities.
The cycled condensate system accomplishes this through the distribution of condensate from the cycled condensate storage tanks to various systems throughout the plant.The cycled condensate storage tanks are credited for Fire Safe Shutdown as a suction source for the Reactor Core Isolation Cooling (RCIC) System for both the basic and alternate shutdown methods.For more detailed information see UFSAR Sections 5.4.6.3, 6.2.4.2.2, 9.2.7, 10.4.6, and 10.4.7.Boundary The Condensate System license renewal scoping boundary includes that portion of the system necessary to achieve primary containment isolation.
The clean condensate supply lines which penetrate the primary containment are equipped with manually operated primary containment isolation valves which are locked closed during reactor operations.
In addition, each line is equipped with a spool piece which is removed and respective blank flanges installed during reactor operations.
The Condensate System license renewal scoping boundary also includes the cycled condensate storage tank and attached piping and valves necessary to maintain a usable supply volume for RCIC System operation.
Not included in this boundary is the safety-related condensate storage tank level instrumentation that provides a low tank level signal to automatically swap the RCIC pump suction to the suppression pool. This instrumentation is evaluated with the RCIC System.All associated piping, components and instrumentation contained within the boundaries described above are also included in the Condensate System scoping boundary.Also included in the Condensate System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related to nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Primary Containment, Auxiliary Building, Reactor Building, Diesel Generator Building, Offgas Building, and Turbine Building.
Included in this boundary are pressure-retaining components relied upon to preserve LaSalle County Station, Units 1 and 2 2.3-141 License Renewal Application Section 2 -Scoping and Screening Methodology and Results the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Reason for Scope Determination The Condensate System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Condensate System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Condensate System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Condensate System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provide primary containment boundary.
The clean condensate supply lines which penetrate the primary containment are equipped with manually operated primary containment isolation valves. 10 CFR 54.4(a)(1)
: 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Condensate System contains nonsafety-related fluid filled lines in the Primary Containment, Auxiliary Building, Reactor Building, Diesel Generator Building, Offgas Building, and Turbine Building which provide structural support or have potential spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
: 3. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The cycled condensate storage tanks are credited for Fire Safe Shutdown as a suction source for the Reactor Core Isolation Cooling System (RCIC) for both the basic and alternate shutdown methods. 10 CFR 54.4(a)(3)
UFSAR References 1.2.2.3.10 1.2.3.1.5 3.1.2.4.6 Table 3.2-1 Table 3.8-1 4.6.1.1.2.4.2.1 5.4.6.3 6.1.1.2 6.2.4.2.2 Table 6.2-21 7.4.1.2.2 9.1.3.2.3.6 9.2.4.1.2 LaSalle County Station, Units 1 and 2 2.3-142 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 9.2.7 10.4.6 10.4.7 11.2.2 15.9.3 Appendix J License Renewal Boundary Drawings LR-LAS-M-74, Sheet 1 LR-LAS-M-75, Sheets 1, 2, 3, 4 LR-LAS-M-77, Sheet 1 LR-LAS-M-1 13, Sheet 1 LR-LAS-M-127, Sheet I LR-LAS-M-86, Sheet 1 LR-LAS-M-89, Sheet 1 LR-LAS-M-90, Sheet 1 LR-LAS-M-96, Sheets 1, 2, 3 LR-LAS-M-97, Sheets 1, 5 LR-LAS-M-98, Sheet 1 LR-LAS-M-99, Sheet 1 LR-LAS-M-1 00, Sheet 1 LR-LAS-M-102, Sheets 1, 10 LR-LAS-M-103, Sheets 15, 16, 19, 27 LR-LAS-M-105, Sheet 1 LR-LAS-M-115, Sheets 1, 12,13 LR-LAS-M-129, Sheet 3 LR-LAS-M-1 30, Sheets 1, 2 LR-LAS-M-133, Sheet 1 LR-LAS-M-136, Sheet 1 LR-LAS-M-1 42, Sheets 1, 2, 3 LR-LAS-M-143, Sheets 1, 5 LR-LAS-M-144, Sheet 1 LR-LAS-M-145, Sheet 1 LR-LAS-M-146, Sheet 1 LR-LAS-M-159, Sheet 1 LaSalle County Station, Units 1 and 2 2.3-143 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.3.4-1 Condensate System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Tanks (Cycled Condensate Gland Seal Leakage Boundary Head Tank)Tanks (Cycled Condensate Storage Pressure Boundary Tank)Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.4.2-1 Condensate System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-14 Section 2 -Scoping and Screening Methodology and Results 2.3.4.2 Condenser and Air Removal System Description The Condenser and Air Removal System is a normally operating system designed to provide a heat sink for exhaust steam from the main turbine and reactor feed pump turbines during normal operation.
The system also removes noncondensible gases from the condenser and exhausts them to the gaseous radwaste system. The system has a function to provide passive hold-up for leakage from the main steam isolation valves following an accident and isolate the main condenser off-gas outlet lines upon detection of high radiation in the main steam lines when the mechanical vacuum pump is operating.
The Condenser and Air Removal System consists of the following plant systems: main condenser and main condenser evacuation system. The Condenser and Air Removal System is in scope for license renewal. However, portions of the Condenser and Air Removal System are not required to perform intended functions and are not in scope.Main Condenser The purpose of the main condenser is to provide a heat sink for turbine exhaust steam, turbine bypass steam, and other turbine cycle flows, and to receive and collect flows for return to the reactor. The main condenser accomplishes these functions by passing circulating water through the condenser tubes to condense the steam from turbine exhausts and other sources, removing noncondensible gases during normal operation and plant startup, and providing a volume for collection and storage of condensate to be returned to the reactor. Attached to the main condenser is safety-related and environmentally qualified instrumentation to sense loss of condenser vacuum and initiate closure of the MSIVs and main steam line drains. The condenser also provides passive hold-up and plateout of radioactive material that leaks through the main steam isolation valves following a LOCA by receiving input from drains for the main steam lines.Condenser Evacuation System The purpose of the condenser evacuation system is to maintain a vacuum in the condenser for the three low pressure turbine exhausts.
The system accomplishes this function by removing the noncondensible gases from the condenser, including air inleakage and dissociation products originating in the reactor, and discharging them to the gaseous radwaste system.The system also functions to minimize the release of radioactivity to the environment following a control rod drop accident.
It accomplishes this function by manual isolation of the main condenser off-gas outlet isolation valves and manual trip of the mechanical vacuum pump when high radiation is detected in the main steam lines when the mechanical vacuum pump is in operation.
For more detailed information see UFSAR Sections 6.8, 7.3.2.2.3.12, 10.4.1, 10.4.2, 15.4.9, and 15.6.5.Boundary The license renewal scoping boundary of the Condenser and Air Removal System includes the main condenser and the off-gas air ejector supply piping from the condenser up to and including the main condenser off-gas outlet isolation valves. The scoping boundary also includes the safety-related main condenser vacuum instrumentation that initiates isolation of LaSalle County Station, Units 1 and 2 2.3-145 License Renewal Application Section 2 -Scoping and Screening Methodology and Results the MSIVs and main steam line drains upon loss of condenser vacuum.All associated piping, components, and instrumentation contained within the boundaries described above is included in the Condenser and Air Removal System scoping boundary.For more information, refer to the License Renewal Boundary Drawings for identification of these components, shown in green.Not included in the Condenser and Air Removal System scoping boundary are the main steam line drains that route MSIV leakage from the steam lines to the condenser for holdup and plateout which are evaluated with the Main Steam System.Not included in the Condenser and Air Removal System scoping boundary are the low pressure turbine exhaust hoods, which form a portion of the post-accident holdup boundary with the main condenser and are evaluated with the Main Turbine and Auxiliaries System.Reason for Scope Determination The Condenser and Air Removal System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Condenser and Air Removal System is not in scope under 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system would not prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Condenser and Air Removal System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49). The Condenser and Air Removal System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Sense process conditions and generate signals for reactor trip or engineered safety features actuation.
Main condenser low vacuum instrumentation initiates MSIV closure and main steam line drain isolation.
10 CFR 54.4(a)(1)
: 2. Post-accident containment holdup and plate out of MSIV bypass leakage. The main condenser is credited for holdup and plateout of MSIV leakage following a LOCA. 10 CFR 54.4(a)(2)
: 3. Minimize the release of radioactive material to the environment.
Manual isolation of the main condenser off-gas outlet valves and manual tripping of the mechanical vacuum pump is credited following a control rod drop accident to minimize radioactive releases.
10 CFR 54.4(a)(2)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The Condenser and Air Removal System includes environmentally qualified pressure switches to sense loss of condenser vacuum and initiate closure of the MSIVs and main steam line drains. 10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 2.3-146 License Renewal Application Section 2 -Scoping and Screening Methodology and Results UFSAR References 1.2.3.1.3 3.2 6.8 7.3.2.2.3.12 10.4.1 10.4.2 15.4.9 15.6.5.5 15.7.1 License Renewal Boundary Drawings LR-LAS-M-56, Sheets 2, 3, 4 LR-LAS-M-1 17, Sheets 2, 3, 4 LR-LAS-M-80, Sheet 2 LR-LAS-M-128, Sheet 2 LR-LAS-M-88, Sheet 1 LR-LAS-M-135, Sheet 1 Table 2.3.4-2 Condenser and Air Removal System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Heat Exchanger
-(Main Condenser)
Shell Containment, Holdup and Plateout Side Components Piping, piping components, and piping Pressure Boundary elements Valve Body Pressure Boundary The aging management review results for these components are provided in: Table 3.4.2-2 Condenser and Air Removal System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-147 Section 2 -Scoping and Screening Methodology and Results 2.3.4.3 Feedwater
 
===System Description===
The Feedwater System is a normally operating system designed to provide a dependable supply of high quality feedwater to the reactor vessel. The Feedwater System consists of the following plant systems: feedwater, feedwater heaters and drains, feedwater miscellaneous drains, feedwater control, zinc injection, hydrogen, and hydrogen water chemistry.
The Feedwater System is in scope for license renewal. However, portions of the Feedwater System are not required to perform intended functions and are not in scope.Feedwater The purpose of the feedwater system is to provide feedwater at the required flow, pressure, and temperature to the reactor vessel. The feedwater system accomplishes this by taking high quality, preheated feedwater from the feedwater heaters and injecting the feedwater into the reactor vessel using motor or turbine driven reactor feed pumps.The feedwater system includes a safety-related and environmentally qualified motor-operated primary containment isolation valve installed upstream of the feedwater injection line primary containment isolation check valves (evaluated with the Reactor Coolant Pressure Boundary System). The check valves provide for immediate isolation should a break occur in the feedwater line outside of the primary containment.
The motor-operated valve provides for long-term leakage protection and isolation capability.
Feedwater Heaters and Drains/Feedwater Miscellaneous Drains The purpose of the feedwater heaters and drains is to recover thermal energy for preheating feedwater to increase the thermal efficiency of the plant. The feedwater heaters and drains accomplish this by using cascading drains and extraction steam to heat reactor feedwater through the use of feedwater heaters.Feedwater Control The purpose of the feedwater control system is to automatically control the flow of feedwater into the reactor vessel to maintain the water level in the vessel within predetermined levels over the entire power range of the reactor. The feedwater control system accomplishes this by using a three-element controller to regulate the feedwater flow. The controller uses main steam flow rate, feedwater flow rate, and reactor water level. The feedwater control signal maintains a predetermined level by varying the speed of the turbine driven feed pumps and/or by varying the flow control valve position on the discharge of the constant speed motor driven feed pump. Operation in a single element control that utilizes reactor water level only is also available.
Zinc Injection The purpose of the zinc injection system is to reduce dose rates in the reactor recirculation piping by reducing the level of cobalt that is incorporated into the iron oxide layers on the recirculation piping. The zinc injection system accomplishes this by injecting a solution of depleted zinc oxide into the suction header of the reactor feed pumps using a zinc injection skid.LaSalle County Station, Units 1 and 2 2.3-148 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Hydrogen System The purpose of the hydrogen system is to provide a source of hydrogen for hydrogen water chemistry.
The hydrogen system accomplishes this by providing regulated hydrogen from a cryogenic hydrogen storage facility to the hydrogen water chemistry injection system.Hydrogen Water Chemistry System The purpose of the hydrogen water chemistry system is to reduce rates of intergranular stress corrosion cracking (IGSCC) in recirculation piping and reactor vessel internals.
The hydrogen water chemistry system accomplishes this by injecting hydrogen into the condensate booster pump suction header (evaluated with the Condensate System) to suppress the formation of radiolytic oxygen in the reactor coolant.For more detailed information see UFSAR Sections 5.4.15, 6.2, 7.7.4, and 10.4.7 Boundary The Feedwater System license renewal scoping boundary includes that portion of the system necessary to achieve primary containment isolation and maintain reactor coolant system pressure boundary.
The feedwater primary containment penetrations are provided with a series arrangement of three isolation valves. The scoping boundary begins with the outer feedwater inlet outboard motor-operated containment isolation valve and continues up to, but does not include, the inner outboard containment isolation check valve located immediately outside of the containment.
The inner outboard containment isolation check valve is evaluated with the Reactor Coolant Pressure Boundary System.All associated piping, components and instrumentation contained within the boundaries described above are also included in the Feedwater System scoping boundary.Also included in the Feedwater System scoping boundary are those portions of nonsafety-related piping and equipment that extend beyond the safety-related to nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located within the Reactor Building, Auxiliary Building, and Turbine Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion of the system. For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the scope of license renewal are the heaters and drains, zinc injection, hydrogen supply and hydrogen water chemistry portions of the system, as these portions of the system are either gas filled or liquid filled, are not located in areas where there are potential spatial interactions with components performing safety-related functions, and do not perform or support an intended function.Not included in the scope of license renewal is the feedwater control portion of the system.The feedwater control system is an operational control system which has no safety function, and does not perform or support an intended function.LaSalle County Station, Units 1 and 2 2.3-149 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Reason for Scope Determination The Feedwater System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Feedwater System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Feedwater System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49). The Feedwater System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provide primary containment boundary.
The Feedwater System includes safety-related motor-operated primary containment isolation valves in the feedwater inlet lines to the reactor.10 CFR 54.4(a)(1)
: 2. Provide reactor coolant pressure boundary.
The Feedwater System includes safety-related motor-operated valves in the feedwater inlet lines to the reactor to provide long-term leakage control in the event of a piping failure in the Feedwater System. 10 CFR 54.4(a)(1)
: 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Feedwater System contains nonsafety-related fluid filled lines in the Reactor Building, Auxiliary Building, and Turbine Building which provide structural support or have potential spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
: 4. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The Feedwater System motor-operated primary containment isolation valves include components that are environmentally qualified.
10 CFR 54.4(a)(3)
UFSAR References 1.2.3.1.5 1.2.3.3.2 Table 3.2-1 5.4.9 5.4.15 6.2.4.2.1 Table 6.2-21 Table 6.2-28 7.7.4 9.5.1.2.2 10.3.6 10.4.7 10.4.8 LaSalle County Station, Units 1 and 2 2.3-150 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Appendix C Appendix J. 1 License Renewal Boundary Drawingqs LR-LAS-M-57, Sheet 1 LR-LAS-M-1 18, Sheet 1 Table 2.3.4-3 Feedwater System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Valve Body Leakage Boundary Pressure Boundary The aging management review results for these components are provided in: Table 3.4.2-3 Feedwater System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-151 Section 2 -Scoping and Screening Methodology and Results 2.3.4.4 Main Steam System Description The Main Steam System is a normally operating system that is designed to convey steam produced in the reactor to the main turbine and direct steam from the main steam relief valve discharge to the suppression pool. The Main Steam System consists of the following plant systems: main steam system and MSIV leakage control system. The Main Steam System includes the MSIV Isolated Condenser Leakage Treatment Method components that control and minimize the release of fission products which could leak through the closed main steam isolation valves after a LOCA. The Main Steam System is in scope for license renewal.However, portions of the system are not required to perform intended functions and are not in scope.The purpose of the Main Steam System is to provide the high pressure steam produced by the reactor to the main turbine during normal plant operation.
It accomplishes this function via the four main steam lines between the outboard primary containment isolation valves, the main turbine stop valves, and the main turbine bypass valves.The purpose of the Main Steam System is to also provide the capability to bypass steam around the main turbine. It accomplishes this by operation of main turbine bypass valves that discharge to the main condenser.
The purpose of the Main Steam System is also to provide steam to users such as reactor feed pump turbines, steam jet air ejectors, offgas preheaters, second stage reheaters, and steam seal evaporator.
It accomplishes this function by providing high pressure steam, from upstream of the main turbine stop valves to flow or pressure control valves at each of the steam users.The Main Steam System also includes the discharge piping from the main steam relief valves inside the primary containment.
The purpose of this portion of the Main Steam System is to route the MSRV discharge to the suppression pool to minimize the thermal effects of opening the relief valves. It accomplishes this function by routing the steam from the MSRV into the suppression pool, below the normal water level, to a quencher to facilitate condensation of the steam. Several of the discharge lines are no longer used for MSRV steam discharge and are installed in the primary containment and capped in the drywell to prevent bypass leakage between the drywell and suppression pool air space.The purpose of the Main Steam System is also to contain main steam isolation valve leakage following a LOCA. It accomplishes this function by providing a volume within the large diameter main steam piping for plateout and holdup and a flow path through main steam drain lines to the main condenser for additional plateout and holdup in the condenser.
The Main Steam System includes the station main steam isolation valve leakage control system which is abandoned in place for Unit 1 and deleted for Unit 2.Portions of the Main Steam System are located in areas where there are potential spatial interactions with safety-related equipment in the Reactor Building.
The intended function of these portions of the Main Steam System is to resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of the safety-related functions of the safety-related SSC.For more detailed information see UFSAR Sections 3.2, 6.7, 6.8, 10.3, and 15.6.LaSalle County Station, Units 1 and 2 2.3-152 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Boundary The license renewal scoping boundary of the Main Steam System includes the main steam lines from the outboard containment isolation valves up to and including the main turbine stop valves, main turbine bypass valves, and isolation valves to steam users.The license renewal scoping boundary of the Main Steam System also includes instrumentation that is part of the plant reactor protection system, including turbine stop valve closure, turbine control valve fast closure, and turbine first stage pressure.The main steam piping from the reactor vessel to, and including, the outboard MSIVs and the MSRVs, is not included in the Main Steam System and is evaluated with the Reactor Coolant Pressure Boundary System for license renewal.The main turbine control valves and downstream piping are also not included in the scope of the Main Steam System and are evaluated with the Main Turbine and Auxiliaries System for license renewal.The license renewal scoping boundary of the Main Steam System also includes the safety-related MSRV discharge piping that is connected to the MSRVs as well as the MSRV discharge piping that is capped in the drywell and no longer used.The license renewal scoping boundary of the Main Steam System includes the MSIV isolated condenser leakage treatment method. This includes nonsafety-related drain lines from the main steam lines outside the primary containment to the main condenser.
The main condenser is not included in the scope of the Main Steam System and is evaluated with the Condenser and Air Removal System for license renewal.The plant MSIV leakage control system is part of the Main Steam System. This system is deleted for Unit 2 and abandoned in place for Unit 1. This portion of the Main Steam System for Unit 1 does not perform any license renewal intended function, has been physically disconnected from the main steam lines and drained, and is not in the scope of license renewal. The function of this plant system is performed by the MSIV isolated condenser leakage treatment method.All associated piping, components, and instrumentation contained within the boundaries described above are also included in the Main Steam System scoping boundary.Also included in the license renewal scoping boundary for the Main Steam System are those portions of nonsafety-related piping and equipment that extend beyond the safety-related/nonsafety-related interface up to the location of the first seismic anchor, or to a point where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of the system located in the Reactor Building.
Included in this boundary are pressure-retaining components that are relied upon to preserve the leakage boundary intended function of this portion of the system.For more information, refer to the License Renewal Boundary Drawing for identification of this boundary, shown in red.LaSalle County Station, Units 1 and 2 2.3-153 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Reason for Scope Determination The Main Steam System meets 10 CFR 54.4(a)(1) because it is a safety-related system that is relied upon to remain functional during and following design basis events. The Main Steam System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Main Steam System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63). The Main Steam System is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Sense process conditions and generate signals for reactor trip or engineered safety features actuation.
The Main Steam System contains reactor protection system instrumentation that initiates reactor scram or turbine trip. 10 CFR 54.4(a)(1)
: 2. Provide emergency heat removal from primary containment and provide containment pressure control. The Main Steam System includes the MSRV discharge piping which prevents bypass leakage between the drywell and suppression pool and routes MSRV discharge to the suppression pool. 10 CFR 54.4(a)(1)
: 3. Post-accident containment holdup and plateout of MSIV bypass leakage. The Main Steam System contains leakage from MSIVs and routes the leakage to the main condenser for holdup and plateout prior to release following LOCA. 10 CFR 54.4(a)(2)
: 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of a safety-related function.
The Main Steam System includes nonsafety-related SSCs with the potential for spatial and structural interaction with safety-related SSCs in the Reactor Building.10 CFR 54.4(a)(2)
: 5. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Main Steam System includes the MSRV discharge piping which is used to reduce and control reactor pressure to support Fire Safe Shutdown.
10 CFR 54.4(a)(3)
: 6. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).The Main Steam System contains reactor protection instrumentation that is subject to the requirements of 10 CFR 50.49, the EQ rule. 10 CFR 54.4(a)(3)
: 7. Relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). The Main Steam System includes the MSRV discharge lines which are used during station blackout to reduce and control reactor pressure.
10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 2.3-154 License Renewal Application Section 2 -Scoping and Screening Methodology and Results UFSAR References 1.2.3.1.2 1.2.2.4.5 3.2 5.4.9 6.7 6.8 7.2 10.3 15.2.6 15.6.5.5 15.9.3 License Renewal Boundary Drawinas LR-LAS-M-55, Sheets 1, 2, 3, 7 LR-LAS-M-92, Sheet 1 LR-LAS-M-116, Sheets 1, 2, 3, 7 LR-LAS-M-138, Sheet 1 Table 2.3.4-4 Main Steam System Components Subject to Aging Management Review Component Type Intended Function Bolting Mechanical Closure Piping, piping components, and piping Leakage Boundary elements Pressure Boundary Valve Body Pressure Boundary The aging management review results for these components are provided in: Table 3.4.2-4 Main Steam System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-155 Section 2 -Scoping and Screening Methodology and Results 2.3.4.5 Main Turbine and Auxiliaries
 
===System Description===
The Main Turbine and Auxiliaries System is a normally operating system designed to convert the thermal energy in the steam supplied from the reactor into rotational mechanical energy.The Main Turbine and Auxiliaries System consists of the following subsystems:
turbine-generator, gland seal steam system, turbine lube oil system, electro-hydraulic control system, turbine test system and portions of the main steam system. The Main Turbine and Auxiliaries System is in scope for license renewal, however, portions of the system are not required to perform intended functions and are not in scope.Main Turbine The main turbine consists of one double-flow high pressure and three double-flow low pressure turbines on the same shaft. The turbine system also includes two (2) horizontal moisture separator reheaters and associated piping running from the main turbine control valves and ending at the low pressure turbine inlets. The purpose of the main turbine is to convert the thermal energy in the steam produced by the reactor into rotational mechanical energy for use by the main generator in producing electricity and to provide a passive holdup volume in conjunction with the main condenser following an accident for any leakage through the Main Steam Isolation Valves (MSIV). It accomplishes the first purpose by passing main steam through the turbine blade stages to turn the turbine rotors which are coupled directly to the generator shaft. It accomplishes the second purpose using the exhaust hoods of the low pressure turbines which are mounted on the top of the main condenser to form the boundary for holdup of MSIV leakage.Gland Seal Steam The purpose of the sealing steam system is to provide a source of clean (low level radioactivity) steam to the shaft seals for the main high and low pressure turbine rotors, shaft seals for the reactor feed pump turbine rotors, and large main steam valves including the main turbine stop valves, main turbine control valves, main turbine bypass valves, combined intermediate valves, and reactor feed pump turbine stop and control valves. It accomplishes this by heating condensate during power operation in the steam seal evaporator.
The seal steam keeps radioactive steam inside the sealed components while keeping outside air from penetrating the seals.Turbine Lube Oil The purpose of the lube oil system is to provide clean pressurized oil to the main turbine thrust bearing, main turbine journal bearings, lift pump suction, hydrogen seal oil and reactor feed pump turbine control system and bearings.
It accomplishes this by purifying the lube oil and providing the pressurized oil to the selected users and returning it to the purification equipment.
Electro-Hydraulic Control (EHC) system The purpose of the EHC system is to provide hydraulic fluid for control of main steam header pressure, turbine speed, and steam flow during normal operating and transient conditions.
It accomplishes this by positioning the main steam stop valves, control valves, combined LaSalle County Station, Units 1 and 2 2.3-156 License Renewal Application Section 2 -Scoping and Screening Methodology and Results intermediate valves, and bypass valves.Turbine Test The purpose of turbine test system is to provide various system connection points such that thermal performance testing can be performed on the turbine assembly.
It accomplishes this by installed instrumentation connection points to monitor process variables in the Main Turbine and Auxiliaries System. This system is only installed on Unit 2 and is used to perform ASME performance testing on newly installed turbine components.
For more detailed information, see UFSAR Section 10.2.Boundary The Main Turbine and Auxiliaries System scoping evaluation boundary begins at the outlet side of the turbine main stop valves. The scoping boundary continues through the high pressure turbine, the moisture separator reheaters, and then the low pressure turbines.
It includes the piping from the outlet of the turbine bypass valves and ends at the inlets to the main condenser.
The scoping boundary also includes the EHC system components which begin at the EHC reservoir.
The scoping boundary continues through the system supply piping, the hydraulic valve actuators on the main turbine valves and the system return piping.The scoping boundary ends where the system return piping returns to the EHC reservoir.
The scoping boundary also includes the components associated with the turbine oil system. The scoping boundary begins at the main turbine oil reservoir.
The scoping boundary continues through the system supply piping to various components including the main turbine bearings, the supply to the seal oil skid, and the system return piping. The scoping boundary ends where the system return piping enters the main turbine oil reservoir.
The gland steam system begins at the inlet to the steam seal evaporator, continues through system piping to turbine shaft seals, the steam packing exhauster, and ends at the outlet pipe connecting to the main stack. The system boundary also includes sealing steam supplies to various main turbine and feed pump turbine valve stem seals and ends where the piping system connects to the condenser.
All associated piping, components and instrumentation, contained within the flowpath described above, are included in the system boundary evaluation unless specifically excluded.The Main Turbine and Auxiliaries System scoping boundary encompasses those components that perform an intended function as part of the MSIV alternate treatment leakage paths. This includes the low pressure turbine exhaust hoods that in combination with the main condenser provide for passive holdup and plateout of MSIV leakage following a design basis LOCA. For more information, refer to the License Renewal Boundary Drawings for the identification of this boundary shown in green.Not included in the Main Turbine and Auxiliaries System scoping boundary is the instrumentation within the Main Turbine and Auxiliaries System boundary associated with the Reactor Protection System which is evaluated with the Main Steam System.Reason for Scope Determination The Main Turbine and Auxiliaries System is not in scope under 10 CFR 54.4(a)(1) because no portions of the system are safety-related or relied upon to remain functional during and following design basis events. The Main Turbine and Auxiliaries System meets 10 CFR LaSalle County Station, Units 1 and 2 2.3-157 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 54.4(a)(2) because failure of nonsafety-related portions of the system could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Main Turbine and Auxiliaries System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Post-accident containment holdup and plateout of MSIV bypass leakage. Credit is taken for holdup and plateout in the main condenser for MSIV leakage. The low pressure turbine exhaust hoods form part of this holdup boundary with the main condenser.
10 CFR 54.4(a)(2)
UFSAR References 6.8 7.7.5 10.2 10.4.3 10.4.4 License Renewal Boundary Drawinqs LR-LAS-M-55, Sheet 4 LR-LAS-M-1 16, Sheet 4 Table 2.3.4-5 Main Turbine and Auxiliaries System Components Subject to Aging Management Review Component Type Intended Function Turbine Casings (Low Pressure Turbine Containment, Holdup and Plateout Exhaust Hoods)The aging management review results for these components are provided in: Table 3.4.2-5 Main Turbine and Auxiliaries System Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application 2.3-158 Section 2 -Scoping and Screening Methodology and Results 2.4 SCOPING AND SCREENING RESULTS: STRUCTURES AND COMPONENT SUPPORTS The following structural components are addressed in this section:* Auxiliary Building (2.4.1)* Component Supports Commodity Group (2.4.2)" Cooling Lake (2.4.3)* Diesel Generator Building (2.4.4)* Lake Screen House (2.4.5)* Offgas Building (2.4.6)" Primary Containment (2.4.7)* Radwaste Building (2.4.8)" Reactor Building (2.4.9)* Structural Commodity Group (2.4.10)* Switchyard Structures (2.4.11)* Tank Foundations and Dikes (2.4.12)* Turbine Building (2.4.13)* Yard Structures (2.4.14)LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-1 Section 2 -Scoping and Screening Methodology and Results 2.4.1 Auxiliary Building Description The Auxiliary Building is a Seismic Category I safety-related multi-story structure.
Portions of the structure are constructed above and below grade.The structure is a part of the power generation complex which includes several contiguous buildings.
The Auxiliary Building is located west of the Seismic Class I safety-related Reactor Building, and east of the Turbine Building.
The Diesel Generator Buildings are located north and south of the Auxiliary Building.
The shear walls for the Reactor Building, Auxiliary Building, Turbine Building, Radwaste Building, Diesel Generator Buildings, and Off-gas Filter Building are interconnected.
These shear walls have been considered to act together to resist lateral loads applied to these buildings.
Therefore, the shear walls for these buildings are Seismic Category I.The Auxiliary Building is comprised of a reinforced concrete shear wall structure supported on a reinforced concrete mat foundation on soil which is continuous with the mat foundation under the reactor, turbine, and diesel generator buildings.
Above the mat the Auxiliary Building is structurally integral with the reactor and turbine buildings.
The lower levels of the Auxiliary Building are continuous, two-way slab and beam construction.
The floor levels above grade are steel framing with concrete slabs. Exterior walls are reinforced concrete.
Interior partitioning consists of reinforced concrete and concrete block walls. The roof is galvanized metal decking with portions consisting of reinforced concrete and built-up roofing.The station ventilation stack is located on the Auxiliary Building roof and serves as a single point of release for the Reactor Building, Turbine Building and Radwaste Building ventilation as well as off-gas standby gas treatment and plant gland seal exhaust systems. The stack is a steel structure and it is designed to withstand postulated seismic and tornado conditions.
The roof also supports exhaust vent lines leading to the vent stack.The Auxiliary Building houses the main steam tunnel, Turbine Building access elevator, vent stack, HVAC equipment, laboratories, electrical equipment, 4160-volt and 6900-volt switchgear, 480-volt substation, battery rooms, instrument room, computer room, control room and offices, and facilities for shift operating personnel.
The Auxiliary Building is divided into compartments designed to protect Unit 1 and Unit 2 safety-related systems and components.
Among these compartments are the control room envelope, switchgear compartments, and miscellaneous equipment compartments.
The control room envelope consists of control room and auxiliary electric equipment rooms for both Units 1 and 2, control room toilet and the main security control center. Air handling units, filter trains, ducts and dampers are also part of the control room envelope.
Safe occupancy of the control room during abnormal conditions is provided for in the design. Adequate shielding is provided to maintain acceptable radiation levels in the control room in the event of a design basis accident for the duration of the accident.
The control room is protected by a minimum of 2 feet of concrete shielding.
The outside air for the control room supply is brought in through independent and separate missile-protected roof openings.
The control room is isolated from LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-2 Section 2 -Scoping and Screening Methodology and Results the Turbine Building through leak tight double doors.The purpose of the Auxiliary Building is to provide structural support, shelter and protection to systems, structures and components (SSCs) along with personnel housed within the building during normal plant operations, and during and following postulated design basis accidents and extreme environmental conditions.
The building also contains the control room, which is the main operation center for the plant providing a centralized area for control and monitoring of safety-related and nonsafety-related equipment throughout the station. The control room envelope in conjunction with the ventilation system provides a habitable environment for plant operators so that the plant can be safely operated and shutdown under design basis accident conditions.
The Auxiliary Building also supports and protects both safety and nonsafety-related equipment.
Included in the boundary of the Auxiliary Building are blowout panels, concrete anchors, concrete embedments, curbs, equipment supports and foundations, hatches, plugs, masonry walls, metal components such as the control room ceiling, metal decking, pipe whip restraints, reinforced concrete elements of the building, steel components, steel elements (including the ventilation stack), and structural bolting.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Auxiliary Building.Included within the boundary of the Auxiliary Building and determined not to be within the scope of license renewal are certain architectural elements in the miscellaneous operational support areas such as the computer room and labs that include drywall partitions and soffits, and suspended ceilings.
These components and structures are nonsafety-related, and are provided to facilitate miscellaneous operational support. These components and structures do not perform a license renewal intended function, such that their failure will not prevent satisfactory accomplishment of a safety-related function.Not included within the evaluation boundary of the Auxiliary Building are the fire barriers, component supports, and structural commodities.
Fire barriers are evaluated separately with the Fire Protection System. Component supports, including their respective bolting, are evaluated with the Component Supports Commodity Group. Structural commodities, including their respective bolting, are evaluated with the Structural Commodity Group. The Structural Commodity Group evaluates components such as bird screens; cable trays; compressible joints and seals; conduit; doors; piping and component insulation and insulation jacketing; louvers; miscellaneous structural steel including platforms, stairs, ladders; panels, racks, cabinets, and other enclosures for electrical equipment and instrumentation; penetration seals;penetration sleeves including end caps; roofing; structural sealants, seismic gap seals, gaskets, flashing and other sealants and gap seals; and tube track. In addition, mechanical and electrical systems and components housed in or located within the Auxiliary Building are evaluated with their respective mechanical and electrical license renewal system or commodity group.For more detailed information, see UFSAR Sections 3.8.4 and 3.8.5 LaSalle County Station, Units 1 and 2 Page 2.4-3 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Reason for Scope Determination The Auxiliary Building meets 10 CFR 54.4(a)(1) because it is a safety-related structure that is relied upon to remain functional during and following design basis events. The Auxiliary Building meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Auxiliary Building also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provide physical support, shelter, and protection for safety-related systems, structures, and components (SSCs). 10 CFR 54.4(a)(1)
: 2. Provide centralized area for control and monitoring of nuclear safety-related equipment.
10 CFR 54.4(a)(1)
: 3. Provides for the discharge of treated gaseous waste to meet the requirements of 10 CFR 50.67 or 10 CFR 100. 10 CFR 54.4(a)(1)
: 4. Controls the potential release of fission products to the external environment so that offsite consequences of design basis events are within acceptable limits. 10 CFR 54.4(a)(1)
: 5. Provides physical support, shelter, and protection for nonsafety-related systems, structures, and components (SSCs) whose failure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
10 CFR 54.4(a)(2)
: 6. Provides structural support or restraint to SSCs not in scope of license renewal to prevent interaction with safety-related SSCs. 10 CFR 54.4(a)(2)
: 7. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
: 8. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).10 CFR 54.4(a)(3)
: 9. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transients Without Scram (10 CFR 50.62). 10 CFR 54.4(a)(3)
: 10. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-4 Section 2 -Scoping and Screening Methodology and Results demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). 10 CFR 54.4(a)(3)
UFSAR References 1.1 1.2.2.2 Table 3.2-1 3.5.2.2 Figure 3.5-4 3.8.1.4.2 3.8.4 3.8.4.1 3.8.4.1.2 3.8.4.1.4 3.8.4.1.6.1 3.8.5 3.8.5.1.1 6.4.2 9.5.1.2.2 12.3.1.5 License Renewal Boundary Drawinas LR-M-3 Table 2.4-1 Auxiliary Building Components Subject to Aging Management Review Component Type Intended Function Blowout Panels Pressure Relief Bolting (Structural)
Structural Support Concrete Anchors Structural Support Concrete Curbs Direct Flow Concrete Embedments Structural Support Concrete:
Above-grade Exterior Flood Barrier (accessible areas) Missile Barrier Shelter, Protection Shielding Structural Pressure Barrier Structural Support Concrete:
Above-grade Exterior Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Shielding Structural Pressure Barrier Structural Support Concrete:
Below-grade Exterior Flood Barrier LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-5 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function (accessible areas) Missile Barrier Shelter, Protection Shielding Structural Pressure Barrier Structural Support Concrete:
Below-grade Exterior Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Structural Pressure Barrier Structural Support Concrete:
Foundation, Subfoundation Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Structural Support Component Type Intended Function Concrete:
Interior Flood Barrier Missile Barrier Shelter, Protection Shielding Structural Pressure Barrier Structural Support Equipment Supports and Foundations Structural Support Hatches/Plugs Flood Barrier Missile Barrier Shelter, Protection Shielding Structural Support Masonry Walls: Interior Shelter, Protection Shielding Structural Support Metal Components (Including Control Structural Support Room Ceiling)Metal Decking Structural Support Pipe Whip Restraints Pipe Whip Restraint Steel Components:
Structural Steel Structural Support Steel Elements (Ventilation Stack) Gaseous Release Path Structural Support Steel Elements:
Liner, Liner Anchors, Water Retaining Boundary Integral Attachments (accessible areas -Sump)The aging management review results for these components are provided in: Table 3.5.2-1 Auxiliary Building Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-6 Section 2 -Scoping and Screening Methodology and Results 2.4.2 Component Supports Commodity Group Description The Component Supports Commodity Group consists of structural elements and specialty components designed to transfer the load applied from a system, structure, or component (SSC) to the building structural element or directly to the building foundation.
Supports include seismic anchors or restraints, support frames, constant and variable spring hangers, rod hangers, guides, stops, straps, and clamps. Specialty components include snubbers, and sliding surfaces.The commodity group is comprised of the following supports:-Supports for ASME Class 1, 2, and 3, and MC piping and components, including reactor vessel anchorage.
-Supports for cable trays, conduit, HVAC ducts, tube track, instrument tubing and non-ASME piping and components.
-Supports for emergency diesel generators, HVAC system components and other miscellaneous mechanical equipment.
-Supports for platforms, spray shields, and other miscellaneous structures.
-Supports for racks, panels, cabinets and enclosures for electrical equipment and instrumentation.
The purpose of a support is to transfer loads such as gravity, thermal, seismic, and other lateral and vertical loads imposed on, or by the system, structure, or component to the supporting building structural element or foundation.
Sliding surfaces when incorporated into the support design permit release of lateral forces but are relied upon to provide vertical support. Specialty supports such as snubbers only resist seismic forces. Vibration isolators are incorporated in the design of some vibrating equipment to minimize the impact of vibration.
Other support types such as guides and position stops allow displacement in a specified direction or preclude unacceptable movements and interactions.
The Component Supports Commodity Group includes supports for mechanical, electrical and instrumentation systems, components, and structures that are within the scope of license renewal. The group also includes supports for SSCs, which are not within the scope of license renewal, but their supports are required to restrain or prevent physical interaction with safety-related SSCs (e.g. Seismic II over I). The supports include support members, welded and bolted connections, sliding surfaces and bearings, concrete anchors, concrete embedments, and grout.Included in the boundary of the Component Supports Commodity Group for each of the supports indicated above are building concrete at locations of expansion and grouted anchors, grout pads for support base plates; constant and variable load spring hangers, guides, stops;support members, sliding surfaces, welds, bolted connections, and support anchorage to building structure.
Snubbers are also included in the boundary of this commodity group;however, they are considered active components and are not subject to aging management LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-7 Section 2 -Scoping and Screening Methodology and Results review except for the end connections, which perform a passive function for structural support.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Component Supports Commodity Group.Not included in the boundary of the Component Supports Commodity Group are concrete equipment foundations, pipe whip restraints, columns, concrete embedments, and concrete anchors used for components other than supports listed herein. These commodities are evaluated separately with the license renewal structure that contains them.For more detailed information, see UFSAR Sections Table 3.2-1, 3.6.2.3.2, 3.6.2.3.2.6, 3.6.2.3.3, 3.7.3.3, 3.9.2, and 3.9.3.Reason for Scope Determination The Component Supports Commodity Group meets 10 CFR 54.4(a)(1) because it is a safety-related supports that is relied upon to remain functional during and following design basis events. The Component Supports Commodity Group meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the supports could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Component Supports Commodity Group also meets 10 CFR 54.4(a)(3) because supports are relied upon in the safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provides structural support or restraint to SSCs in scope of license renewal.10 CFR 54.4(a)(1), (a)(2), (a)(3)2. Provides structural support or restraint to SSCs not in scope of license renewal to prevent interaction with safety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References Table 3.2-1 3.6.2.3.2 3.6.2.3.2.6 3.6.2.3.3 3.7.3.3 3.9.2 3.9.3 3.10 8.3.1 Appendix G.2 Appendix J.3 License Renewal Boundary Drawings LR-M-3 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-8 Section 2 -Scoping and Screening Methodology and Results Table 2.4-2 Component Supports Commodity Group Components Subject to Aging Management Review Component Type Intended Function Supports for ASME Class 1 piping and Structural Support components (Building concrete at locations of expansion and grouted anchors; grout pads for support base plates)Supports for ASME Class 1 piping and Structural Support components (Constant and variable load spring hangers; guides; stops)Supports for ASME Class 1 piping and Structural Support components (Support members; welds;bolted connections; support anchorage to building structure)
Supports for ASME Class 2 and 3 piping Structural Support and components (Building concrete at location of expansion and grouted anchors; grout pads for support base plates)Supports for ASME Class 2 and 3 piping Structural Support and components (Constant and variable load spring hangers; guides; stops)Supports for ASME Class MC Structural Support components (Building concrete at location of expansion and grouted anchors; grout pads for support base plates)Supports for ASME Class 2 and 3 piping Structural Support and components (Support members;welds; bolted connections; support anchorage to building structure)
Supports for ASME Class MC Structural Support components (Constant and variable load spring hangers; guides; stops)Supports for ASME Class MC Structural Support components (Support members; welds;bolted connections; support anchorage to building structure)
Supports for Cable Trays, Conduit, HVAC Structural Support Ducts, Tube Track, Instrument Tubing, Non-ASME Piping and Components (Support members; welds; bolted connections; support anchorage to building structure)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-9 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function Supports for Cable Trays, Conduit, HVAC Ducts, Tube Track, Instrument Tubing, Non-ASME Piping and Components (Building concrete at location of expansion and grouted anchors; grout pads for support base plates)Structural Support Supports for Emergency Diesel Generator, HVAC System Components, and Other Misc. Mechanical Equipment (Building concrete at location of expansion and grouted anchors; grout pads for support base plates)Structural Support Supports for Emergency Diesel Structural Support Generator, HVAC System Components, and Other Misc. Mechanical Equipment (Support members; welds; bolted connections; support anchorage to building structure)
Supports for Platforms, Jet Impingement Structural Support Shields, Masonry Walls, and Other Misc.Structures (Building concrete at location of expansion and grouted anchors; grout pads for support base plates)Supports for Platforms, Jet Impingement Structural Support Shields, Masonry Walls, and Other Miscellaneous Structures (Support members; welds; bolted connections; support anchorage to building structure)
Supports for Racks, Panels, Cabinets, Structural Support and Enclosures for Electrical Equipment and Instrumentation (Building concrete at location of expansion and grouted anchors; grout pads for support base plates)Supports for Racks, Panels, Cabinets, Structural Support and Enclosures for Electrical Equipment and Instrumentation (Support members;welds; bolted connections; support anchorage to building structure)
The aging management review results for these components are provided in: Table 3.5.2-2 Component Supports Commodity Group Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-10 Section 2 -Scoping and Screening Methodology and Results 2.4.3 Cooling Lake Description The Cooling Lake is located over 800 feet east of the power block building complex. The Cooling Lake evaluation boundary includes the Cooling Lake embankment (including discharge structure and discharge flume), submerged core standby cooling system (CSCS)pond and intake flume (ultimate heat sink), CSCS pipeline outfall structure, makeup pipeline outfall structure and makeup and blowdown valve house, service spillway (which is also known as the blowdown intake structure), and the auxiliary spillway.Cooling Lake Embankment (including discharge structure and discharge flume): The 2058 acre Cooling Lake was constructed by excavation of the local soil. The west side of the shore line (plant side) is made up of natural topography.
The lake also has peripheral dike embankments comprised of soil, crushed stone, and riprap on the north, east, and south sides.The Cooling Lake embankments, which are also described as peripheral dikes, are designed to contain the Cooling Lake water level at a normal water level of 700' MSL which is 10 feet below plant grade. The purpose of the Cooling Lake is to provide a source of cooling water for the Nonessential Cooling Water System which includes the circulating water and service water systems. A discharge structure is located west of the power block and the connected discharge flume returns cooling water from the Nonessential Cooling Water System to the Cooling Lake during normal plant operations.
The Cooling Lake has an internal dike system to increase the flow path of returning warm water for efficient heat dissipation.
Failure of the Cooling Lake embankment and internal dikes (including the discharge structure and discharge flume) does not affect any license renewal intended function and does not affect the ultimate heat sink. Failure of the Cooling Lake embankment would not result in flooding of plant facilities since plant grade and floor elevations are 710 feet and 710.5 feet respectively.
The upper portion of the Cooling Lake including the embankment and discharge structure and discharge flume are not safety-related and do not perform an intended function for license renewal. The submerged CSCS pond and intake flume (ultimate heat sink) as well as the CSCS outfall structure which are located within the Cooling Lake are safety-related and are evaluated under separate headings below.Submerged CSCS Pond and Intake Flume (Ultimate Heat Sink)The ultimate heat sink (UHS) is the submerged core standby cooling systems (CSCS) pond which includes the intake flume. The CSCS pond and intake flume are excavated from the local soil and is contained within and underlies the Cooling Lake and the natural grade of the site. Failure of the Cooling Lake embankment and internal dikes does not affect any intended function and does not affect the ultimate heat sink. The intake flume and CSCS pond have a combined surface area of 85 acres and depth of 5 feet. The submerged CSCS Pond and intake flume design emergency water level is 690 feet MSL, which is 10 feet below the Cooling Lake normal water level. The intake flume is 2,500 feet long. The upper flume walls are protected against wave action by riprap placed over crushed stone. At the Lake Screen House, the sides of the flume are formed by a concrete retaining wall on the south and a sheet pile retaining wall on the north. The concrete retaining wall and the sheet pile retaining wall are evaluated with the Lake Screen House. A nonsafety-related shad net is installed across the end of the intake flume at the Cooling Lake. The purpose of the CSCS pond and intake LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-11 Section 2 -Scoping and Screening Methodology and Results flume are to provide the ultimate heat sink by providing water for the Essential Cooling Water System and also to provide water for the Fire Protection System. The ultimate heat sink (UHS) provides sufficient cooling water to permit the safe shutdown and cool down of the station for 30 days with no makeup for both normal and accident conditions, and also provides water for fire protection equipment.
The submerged CSCS pond and intake flume are in scope; since they are Seismic Category I, safety-related structures required to maintain structural integrity and an adequate volume of cooling water for safety-related systems during design basis events, and additionally, they provide water for fire protection equipment.
CSCS Outfall Structure The CSCS outfall structure, also known as the CSCS pipeline outlet chute, the CSCS outlet chute, or the CSCS pond water inlet chute is a safety-related structure consisting of concrete enclosing the ends of the three (3) CSCS return lines which discharge to a reinforced concrete channel or chute which directs return water into the CSCS pond. The CSCS outfall structure is a safety-related structure which directs return flow from CSCS pipelines to the ultimate heat sink and therefore is in scope for license renewal.Makeup Pipeline Outfall Structure and Makeup and Blowdown Valve House The makeup pipeline outfall structure, also known as the cooling lake makeup water discharge structure consists of concrete encasing the end of the 60-inch diameter makeup pipeline which discharges to a reinforced concrete channel structure directing makeup water into the Cooling Lake. The purpose of the makeup pipeline outfall structure is to discharge the makeup water from the Illinois River into the lake. The makeup and blowdown valve house contains valves for the subject pipelines, and it is constructed of reinforced concrete below grade and concrete masonry block above grade. The emergency shutdown capability of the plant is not dependent on water input from the main Cooling Lake or makeup pipeline water from the Illinois River. The ultimate heat sink (UHS) provides sufficient cooling water to permit the safe shutdown and cool down of the station for 30 days with no makeup for both normal and accident conditions.
The UHS also provides water for fire protection equipment.
Therefore, the nonsafety-related Lake Makeup Pipeline Outfall Structure and the Makeup and Blowdown Valve House do not perform an intended function for license renewal and are not in scope.Service Spillway (or Lake Blowdown Intake Structure) and Blowdown Valve House (Pit)The service spillway (which is also known as the lake blowdown intake structure) and the blowdown valve house (pit) are constructed of reinforced concrete.
The purpose of the service spillway is to direct lake water into the blowdown line for discharge into the Illinois River. The spillway including its gates and valve pit provide for Cooling Lake level control, dilution of wastes and control of the dissolved solids. The blowdown line connects with the lake blowdown outfall structure located on the Illinois River which is evaluated with Miscellaneous Not in Scope Structures.
The service spillway and blowdown valve house (pit)are not in scope since they are nonsafety-related and do not perform a license renewal intended function.Auxiliary Spillway: The auxiliary spillway is located on northwest corner of the discharge flume (discharge channel).
It is constructed of soil and riprap on crushed stone. The purpose of the spillway is LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-12 Section 2 -Scoping and Screening Methodology and Results to passively drain the Cooling Lake when the water level becomes sufficiently high to prevent overtopping of the exterior dikes. Failure of the exterior dikes or Cooling Lake embankment does not affect an intended function.
The nonsafety-related auxiliary spillway does not perform an intended function for license renewal and, therefore it is not in scope.Included within the boundary of the Cooling Lake and determined to be within the scope of license renewal are reinforced concrete elements, concrete embedments, earthen and riprap elements, shad net anchors, and hatches and plugs which are part of the submerged CSCS pond, intake flume, and the CSCS outfall structure.
Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Cooling Lake structure.
Included in the boundary of the Cooling Lake and determined to be not in scope for license renewal are the auxiliary spillway, cooling lake embankment (including discharge structure and discharge flume), makeup pipeline outfall structure, service spillway, and lake blowdown valve pit. These structures are nonsafety-related and are designed to provide and maintain a volume of water for nonsafety-related cooling purposes, level control, waste dilution or to protect the Cooling Lake embankment (dikes). They are not necessary for the function of the UHS, fire protection, or to provide flood protection for LSCS plant. Additionally, there are other features in the immediate vicinity of the Cooling Lake which are associated with access to the Lake, public recreation on the lake, and the fish hatchery.
These structural components and features do not perform a license renewal intended function and their failure will not prevent satisfactory accomplishment of a safety-related function.Not included within the boundary of the Cooling Lake are the Lake Screen House and the retaining walls on the north and south sides of the Lake Screen House which are evaluated separately with the Lake Screen House. Also not included within the boundary of the Cooling Lake are the lake blowdown outfall structure and associated valve pit, and the river screen house which are evaluated with Miscellaneous Not in Scope Structures.
The shad net (cable, polymer and steel components) are included within the Essential Cooling Water System the shad net anchors are within scope of the Cooling Lake.For more detailed information, see UFSAR Sections 2.4, 2.5, Table 3.2-1, 9.2, 10.4, and 11.2.Reason for Scope Determination The Cooling Lake meets 10 CFR 54.4(a)(1) because it is a safety-related structure that is relied upon to remain functional during and following design basis events. The Cooling Lake meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Cooling Lake also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48) and Station Blackout (10 CFR 50.63). The Cooling Lake is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49) and Anticipated Transient Without Scram (10 CFR 50.62).LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-13 Section 2 -Scoping and Screening Methodology and Results Intended Functions 1. Provides physical support, shelter, and protection for safety-related systems, structures, and components (SSCs). 10 CFR 54.4(a)(1)
: 2. Provides Ultimate Heat Sink (UHS) during design basis events. 10 CFR 54.4(a)(1) 3, Provides a source of cooling water for plant safe shutdown.
10 CFR 54.4(a)(1)
: 4. Provides physical support, shelter, and protection for nonsafety-related systems, structures, and components whose failure could prevent satisfactory accomplishment of functions(s) identified for 10 CFR 54.4(a)(1).
10 CFR 54.4(a)(2)
: 5. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
: 6. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). 10 CFR 54.4(a)(3)
UFSAR References 2.4 2.4.1.1 2.4.8 2.4.11.6 2.5 2.5.4 2.5.5 2.5.6 Table 3.2-1 9.2 9.2.6 10.4 11.2 License Renewal Boundary Drawings LR-M-3 LaSalle County Station, Units 1 and 2 Page 2.4-14 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.4-3 Cooling Lake Components Subject to Aging Management Review Component Type Intended Function Concrete Embedments Structural Support Concrete: (CSCS Outfall Structure)
Direct Flow Structural Support Concrete:
Shad Net Anchors Structural Support Earthen Water-Control Structures (Intake Direct Flow Flume and Submerged CSCS Pond) Water retaining boundary Hatches/Plugs Shelter, Protection Structural Support The aging management review results for these components are provided in: Table 3.5.2-3 Cooling Lake Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-15 Section 2 -Scoping and Screening Methodology and Results 2.4.4 Diesel Generator Building Description The Diesel Generator Building consists of a separate structure for each unit. One is located north of the Auxiliary Building, the other south, both east of the Turbine Building.
Each Diesel Generator Building is a multi-level Seismic Category I structure.
These structures are part of the power generation complex which includes several contiguous buildings.
The shear walls for the Reactor Building, Auxiliary Building, Turbine Building, Radwaste Building, Diesel Generator Buildings, and Off-gas Filter Building are interconnected.
These shear walls have been considered to act together to resist lateral loads applied to these buildings.
The shear walls for these buildings are Seismic Category I.The Diesel Generator Buildings are comprised of a multi-level reinforced concrete substructure supported on a reinforced concrete mat foundation on soil with a steel frame above the grade floor. Exterior walls are reinforced concrete.
Structural steel columns support the upper elevation slabs. The roof is reinforced concrete with built up roofing. The diesel intakes are provided with a metal enclosure located on the roof. The Diesel Generator Buildings are also designed to withstand tornados, missiles and flooding.
Each Diesel Generator Building includes roof extensions for the air intakes, and diesel exhaust penthouses.
The purpose of the Diesel Generator Building is to provide structural support, shelter, access control, and protection to safety-related systems, components and structures housed within it during operation, shutdown, and postulated design basis accidents.
Each Diesel Generator Building is divided into separate bays, one for each of the diesel generators provided.
Three (3) diesel generator units are located in the Unit 1 Diesel Generator Building, including one (1)diesel generator common to both plant units; and two (2) diesel generators are located in the Unit 2 Diesel Generator Building.
Major components contained within the Diesel Generator Building include the emergency diesel generators, fuel oil storage and day tanks, electrical switchgear, HVAC diesel compartment cooling and ventilation equipment, and miscellaneous equipment required to support the operation and maintenance of the emergency diesel generators.
Each diesel generator unit is enclosed in its own reinforced concrete missile protected bay which is designed to provide physical separation for redundant mechanical and electrical safety-related components.
Each bay contains a diesel generator, fuel oil day tank, air receivers and compressor and control cabinets.
Each bay also contains overhead rigging beams which support maintenance activities.
The upper mezzanine portion of each bay contains the air intakes, exhaust, ventilation, and coolant support system. The lower elevations contain the fuel oil storage tanks.Included in the boundary of the Diesel Generator Building and determined to be in scope for license renewal are concrete anchors, concrete embedments, curbs, equipment supports and foundations, hatches, plugs, masonry walls, metal decking, reinforced concrete elements of the building, steel components, steel elements, and structural bolting.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Diesel Generator Building.Not included within the boundary of the Diesel Buildings are the cranes and hoists, fire LaSalle County Station, Units 1 and 2 Page 2.4-16 License Renewal Application Section 2 -Scoping and Screening Methodology and Results barriers, component supports, and structural commodities.
Cranes and hoists are evaluated separately with the Cranes, Hoists and Refueling Equipment System. Fire barriers are evaluated separately with the Fire Protection System. Component supports, including their respective bolting, are evaluated with the Component Supports Commodity Group. The Structural Commodity Group evaluates components such as bird screens; cable trays;compressible joints and seals; conduit; doors; piping and component insulation and insulation jacketing; louvers; miscellaneous structural steel including platforms, stairs, ladders; panels, racks, cabinets, and other enclosures for electrical equipment and instrumentation; penetration seals; penetration sleeves including end caps; roofing; structural sealants, seismic gap seals, gaskets, flashing and other sealants and gap seals; and tube track. In addition, mechanical and electrical systems and components housed in or located within the Diesel Buildings are evaluated with their respective mechanical and electrical license renewal systems or commodities group.For more detailed information, see UFSAR Sections 1.2.2.2, 3.5.1, 3.5.2, 3.7.1.4, and 3.8.4.1.5.
Reason for Scope Determination The Diesel Generator Building meets 10 CFR 54.4(a)(1) because it is a safety-related structure that is relied upon to remain functional during and following design basis events. The Diesel Generator Building is not in scope under 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure would not prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Diesel Generator Building also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48) and Station Blackout (10 CFR 50.63). The Diesel Generator Building is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49)and Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provides physical support, shelter, and protection for safety-related systems, structures, and components.
10 CFR 54.4(a)(1)
: 2. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
: 3. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). 10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-17 Section 2 -Scoping and Screening Methodology and Results UFSAR References 1.2.2.2 1.2.4.1 2.5.4.10 3.5.1 3.5.2 3.7.1.4 3.8.4.1.5 3.8.5.1.1 9.5.1 9.5.7.1.1 9.5.8.3 Table 3.2-1 Appendix H -Fire Hazards Analysis License Renewal Boundary Drawings LR-M-3 Table 2.4-4 Diesel Generator Building Components Subject to Aging Management Review Component Type Intended Function Bolting (Structural)
Structural Support Concrete Anchors Structural Support Concrete Curbs Direct Flow Concrete Embedments Structural Support Concrete: (Exhaust Enclosure)
Above- Missile Barrier grade exterior Shelter, Protection Structural Support Concrete:
Above-grade Exterior Flood Barrier (accessible areas) Missile Barrier Shelter, Protection Structural Support Concrete:
Above-grade Exterior Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Structural Support Concrete:
Below-grade Exterior Flood Barrier (inaccessible areas) Shelter, Protection Structural Support Concrete:
Foundation, Subfoundation Flood Barrier (inaccessible areas) Shelter, Protection Structural Support Concrete:
Interior Flood Barrier Missile Barrier Shelter, Protection LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-18 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function Structural Support Equipment Supports and Foundations Structural Support Hatches/Plugs Missile Barrier Shelter, Protection Structural Support Masonry Walls: Above-grade Exterior Missile Barrier Shelter, Protection Structural Support Masonry Walls: Interior Missile Barrier Shelter, Protection Structural Support Metal Decking Structural Support Metal Siding Shelter, Protection Steel Components:
Structural Steel Structural Support Steel Elements:
Liner, Liner Anchors, Water Retaining Boundary Integral Attachments (Sump Liner)The aging management review results for these components are provided in: Table 3.5.2-4 Diesel Generator Building Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-19 Section 2 -Scoping and Screening Methodology and Results 2.4.5 Lake Screen House Description The Lake Screen House includes the service water tunnel, the two (2) flume retaining walls directly north and south of the building, and the contiguous chemical feed building.
The south retaining wall is a reinforced concrete gravity wall. The north retaining wall is steel sheet piling.The Lake Screen House is a multi-story building.
It consists of a reinforced concrete box type structure.
A steel frame is constructed using block walls with a precast concrete roof. The structure is located on the west edge of the Cooling Lake. It is located approximately 800 feet, east of the main power block. The Lake Screen House foundation is supported on a 4-foot thick reinforced concrete mat foundation on soil. The Seismic Category I service water tunnel is located in the building.The Lake Screen House is designed to provide support and protection for the Seismic Category I service water tunnel and the associated safety-related piping and valve components.
The Lake Screen House is designed to provide a water retaining boundary and access to the submerged portion of the Core Standby Cooling Systems (CSCS) pond UHS cooling water under postulated environmental and design basis accident loadings.
The Lake Screen House is also designed to provide support, shelter and protection of the station fire pumps and other equipment.
The building is classified non-Seismic Category I. However, concrete portions of the building are designed to withstand Seismic Category I loads.Equipment housed within the Lake Screen House includes the service and circulating water pumps, traveling screens, bar racks (trash rack grill), fire protection pumps, the service water tunnel and associated piping. A normally closed bypass line is available to bypass the traveling screens providing lake water directly to the service water tunnel. Buried CSCS piping is connected to the service water tunnel and to safety-related CSCS pumps located within the power block. The bypass line valve is housed in an external concrete valve enclosure which is part of the below grade south exterior wall. The Lake Screen House structure also houses and supports various other nonsafety-related equipment including cranes and hoists, electrical equipment, and panels. A chemical feed system located near the Lake Screen House provides chemical treatment of lake water to control pH, scaling, silting and biological growth.The chemical feed building is located immediately southwest of the Lake Screen House and includes chemical storage and equipment for water treatment purposes.
The chemical feed building is an above grade steel frame and metal siding structure on a concrete mat foundation.
The northeast corner of the chemical feed building is in contact with the southwest corner of the Lake Screen House.Openings are provided in front of the structure to allow lake water to flow into each of the six bays where the nonsafety-related pumps are located. Closure of the stop logs on these openings, and realignment of system valves allows isolation of each of the bays for maintenance and different modes of operation.
The purpose of the Lake Screen House is to provide structural support, shelter, protection, and access to submerged CSCS pond water (UHS) for Seismic Category I safety-related concrete structural components and mechanical components under postulated environmental and LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-20 Section 2 -Scoping and Screening Methodology and Results design basis accident loading conditions.
The Lake Screen House also provides a water retaining boundary for the Cooling Lake. The Lake Screen House also, provides structural support, shelter, protection, and access to Cooling Lake water for non-Seismic Category I plant equipment and components, including fire protection pumps and associated piping, valves and related equipment.
The Lake Screen House is therefore in scope for license renewal.Evaluation of the chemical feed building with the chemical feed pump house determined that it does not perform an intended function delineated in 10 CFR 54.4(a); however a portion of the chemical feed building is in the vicinity of, and in contact with, the Lake Screen House and therefore, the chemical feed building structure is in scope for license renewal. The adjacent chemical feed pump house south of the chemical feed building is not in scope for license renewal.Included within the boundary of the Lake Screen House which also includes the chemical feed building, and determined to be within the scope of license renewal are reinforced concrete elements (including south flume wall), concrete embedments, concrete anchors, equipment supports and foundations, hatches and plugs, metal decking, masonry walls, steel components (structural steel), steel elements (trash rack bar grill assembly) and piles (sheet piling -north flume wall), precast concrete panels (roof slab), and metal siding. Also included within the boundary is structural bolting associated with specific in scope components evaluated as part of the Lake Screen House and chemical feed building.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Lake Screen House structure.
Included in the boundary for the Lake Screen House structure and determined not to be in scope for license renewal are the active stop logs and valve motor operators which are subject to periodic testing. These components are active, or are provided for maintenance activities.
They do not perform a license renewal intended function and their failure does not prevent satisfactory accomplishment of a safety-related function.Not included in the boundary of the Lake Screen House structure are cranes and hoists, fire barriers, structural commodities, and components supports.
Cranes and hoists are evaluated separately with the Cranes, Hoists and Refueling Equipment system, fire barriers are evaluated separately with the Fire Protection System. Component supports, including their respective bolting, are evaluated separately with the Component Supports Commodity Group.Structure commodities are evaluated with the Structures Commodity Group. The Structural Commodity Group evaluates components such as bird screens; cable trays; compressible joints and seals; conduit; doors; piping and component insulation and insulation jacketing; louvers; miscellaneous structural steel including platforms, stairs, ladders; panels, racks, cabinets, and other enclosures for electrical equipment and instrumentation; penetration seals;penetration sleeves including end caps; roofing; structural sealants, gaskets, moisture barriers and water stops, flashing and other sealants and gap seals; and tube track. In addition, mechanical and electrical systems and components housed in or located at the Lake Screen House are evaluated with their respective mechanical and electrical license renewal systems or commodities group. Also not included is the Cooling Lake, which is evaluated separately as the Cooling Lake structure.
For more detailed information, see UFSAR Sections 3.8.4.1, 3.8.4.1.7.2, and 9.2.1.3.LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-21 Section 2 -Scoping and Screening Methodology and Results Reason for Scope Determination The Lake Screen House meets 10 CFR 54.4(a)(1) because portions of the building include a safety-related structure that is relied upon to remain functional during and following design basis events. The Lake Screen House meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the building could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Lake Screen House also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48) and Station Blackout (10 CFR 50.63). The Lake Screen House is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49) and Anticipated Transients Without Scram (10 CFR 50.62).Intended Functions 1. Provides physical support, shelter, and protection for safety-related systems, structures, and components (SSCs). 10 CFR 54.4(a)(1)
: 2. Provides a source of cooling water for plant safe shutdown.
10 CFR 54.4(a)(1)
: 3. Provides physical support, shelter, and protection for nonsafety-related systems, structures, and components (SSCs) whose failure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
10 CFR 54.4(a)(2)
: 4. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
: 5. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). 10 CFR 54.4(a)(3)
UFSAR References 1.2.2.2 2.5.4.10.3 3.8.4.1 3.8.4.1.7.2 3.3.2.3 3.4.1.3 9.2.1.3 9.2.12 Table 3.2-1 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-22 Section 2 -Scoping and Screening Methodology and Results License Renewal Boundary Drawings LR-M-3 Table 2.4-5 Lake Screen House Components Subject to Aging Management Review Component Type Intended Function Bolting (Structural)
Structural Support Concrete Anchors Structural Support Concrete Embedments Structural Support Concrete:
Above-grade Exterior Flood Barrier (accessible areas) Missile Barrier Shelter, Protection Structural Support Concrete:
Above-grade Exterior Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Structural Support Concrete:
Below-grade Exterior Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Structural Support Water retaining boundary Concrete:
Foundation, Subfoundation Flood Barrier (inaccessible areas) Shelter, Protection Structural Support Water retaining boundary Concrete:
Interior Missile Barrier Shelter, Protection Structural Support Equipment Supports and Foundations Structural Support Hatches/Plugs Missile Barrier Shelter, Protection Structural Support Masonry Walls: Above-grade Exterior Shelter, Protection Structural Support Masonry Walls: Interior Shelter, Protection Structural Support Metal Siding Shelter, Protection Piles (Sheet Piling- North Flume Wall) Flood Barrier Structural Support Precast Panel (Roof Slab) Shelter, Protection Steel Components:
Structural Steel Structural Support Steel Elements (Bar Grill) Filter The aging management review results for these components are provided in: LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-23 Section 2 -Scoping and Screening Methodology and Results Table 3.5.2-5 Lake Screen House Summary of Aging Management Evaluation 0 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-24 Section 2 -Scoping and Screening Methodology and Results 2.4.6 Offgas Building Description The Offgas Building, which is also known as the Off-gas Filter Building, is located east of the Reactor Building.
The Offgas Building is part of the power generation complex which includes several contiguous buildings.
The shear walls for the Reactor Building, Auxiliary Building, Turbine Building, Radwaste Building, Diesel Generator Buildings, and Offgas Filter Building are interconnected.
These shear walls have been considered to act together to resist lateral loads applied to these buildings.
Therefore, the shear walls for these buildings are Seismic Category I.The Offgas Building consists of reinforced concrete structural steel and metal siding with interior, reinforced concrete and concrete block walls. Exterior walls are reinforced concrete and metal siding. The structure is supported by a reinforced concrete mat foundation on soil.The roof is galvanized metal decking with insulation and built-up roofing and a portion of the roof is reinforced concrete.
The Offgas Building is also contiguous with the equipment access building which is a part of the Reactor Building.
The majority of the south wall of the equipment access building is common with the north wall of the Offgas Building.
This common wall is evaluated with the Reactor Building.The Offgas Building is classified as a Seismic Category II, nonsafety-related structure.
However, the Offgas Building foundation shear walls are designed to act together with the other power generation complex shear walls and are Seismic Category I.The purpose of the Offgas Building is to provide structural support, shelter, and protection for nonsafety-related systems, structures, and components during normal plant operation.
The Offgas Building contains the off-gas filters and associated equipment components and the support systems and components necessary to support Fire Protection.
The Offgas Building is in the vicinity of the Reactor Building, resists exterior flooding, and the foundation shear walls are Seismic Category I. Therefore, the Offgas Building is in scope of license renewal.Included in the boundary of the Offgas Building and determined to be within the scope of license renewal are concrete anchors, concrete embedments, equipment supports and foundations, hatches, plugs, masonry walls, metal decking, metal siding, reinforced concrete elements of the building, steel components, steel elements, and structural bolting.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Offgas Building.Not included within the evaluation boundary of the Offgas Building are the fire barriers, component supports, and structural commodities.
Fire barriers are evaluated separately with the Fire Protection System. Component supports, including their respective bolting, are evaluated with the Component Supports Commodity Group. Structural commodities, including their respective bolting, are evaluated with the Structural Commodity Group. The Structural Commodity Group evaluates components such as bird screens; cable trays; compressible joints and seals; conduit; doors; piping and component insulation and insulation jacketing; louvers; miscellaneous structural steel including platforms, stairs, ladders; panels, racks, cabinets, and other enclosures for electrical equipment and instrumentation; penetration seals;penetration sleeves including end caps; roofing; structural sealants, seismic gap seals, LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-25 Section 2 -Scoping and Screening Methodology and Results gaskets, flashing and other sealants and gap seals; and tube track. In addition, mechanical and electrical systems and components housed in or located within the Offgas Building are evaluated with their respective mechanical and electrical license renewal system or commodity group.For more detailed information, see UFSAR Sections 1.1 and Table 3.2-1.Reason for Scope Determination The Offgas Building is not in scope under 10 CFR 54.4(a)(1) because no portions of the structure are safety-related and relied upon to remain functional during and following design basis events. The Offgas Building meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Offgas Building also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Offgas Building is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provides structural support or restraint to SSCs in the scope of license renewal. 10 CFR 54.4(a)(2)
: 2. Provides physical support, shelter, and protection for nonsafety-related systems, structures, and components whose failure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
10 CFR 54.4(a)(2)
: 3. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
UFSAR References 1.1 1.2.2.2 Table 3.2-1 3.4.1.3 3.8.4.1.6.3
 
===9.5 License===
Renewal Boundary Drawings LR-M-3 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-26 Section 2 -Scoping and Screening Methodology and Results Table 2.4-6 Offqas Building Components Subject to Aging Management Review Component Type Intended Function Bolting (Structural)
Structural Support Concrete Anchors Structural Support Concrete Curbs Flood Barrier Concrete Embedments Structural Support Concrete:
Above-grade Exterior Flood Barrier (accessible areas) Missile Barrier Shelter, Protection Shielding Structural Support Concrete:
Above-grade Exterior Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Shielding Structural Support Concrete:
Below-grade Exterior Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Structural Support Concrete:
Foundation, Subfoundation Flood Barrier (inaccessible areas) Shelter, Protection Structural Support Concrete:
Interior Missile Barrier Shelter, Protection Shielding Structural Support Equipment Supports and Foundations Structural Support Hatches/Plugs Shelter, Protection Structural Support Masonry Walls: Interior Shelter, Protection Shielding Structural Support Metal Decking Shelter, Protection Structural Support Metal Siding Shelter, Protection Steel Components:
Structural Steel Structural Support The aging management review results for these components are provided in: Table 3.5.2-6 Offgas Building Summary of Aging Management Evaluation LaSalle County Station, Units I and 2 License Renewal Application Page 2.4-27 Section 2 -Scoping and Screening Methodology and Results 2.4.7 Primary Containment Description The Primary Containment includes the LaSalle County Station Unit 1 and Unit 2 Primary Containment structures, and the containment internal structures.
Each Primary Containment is entirely enclosed and contained within the reinforced concrete Reactor Building.
The Reactor Building provides secondary containment, and shelter and protection for the Primary Containment and the components housed within.The Units 1 and 2 Primary Containment(s) are steel lined, post-tensioned, reinforced concrete, Mark II type, seismic category I, and safety-related structures.
The Primary Containment is a concrete structure with the exception of the drywell head and access penetrations, which are fabricated from steel. The containment is a BWR (boiling water reactor) Mark II design of over-under pressure suppression configuration with multiple downcomers penetrating a reinforced concrete drywell floor and connecting the reactor drywell to the water pool in the suppression chamber. The Primary Containment consists of a steel dome head and post-tensioned concrete wall standing on a base mat of conventionally reinforced concrete.
The inner concrete surface of the drywell is lined with carbon steel plate. The entire suppression chamber is lined with stainless steel including the underside of the drywell floor. The drywell and suppression chamber are connected four vacuum relief valves which are outside of the Primary Containment and form an extension of the containment pressure boundary.The purpose of the Primary Containment is to provide a high integrity barrier to contain the effects of the postulated design basis line break and direct the steam released to the suppression chamber pool. The suppression chamber provides a reservoir of water capable of condensing steam flow from the drywell. It also provides a source of water for the ECCS (emergency core cooling system) and for pressure suppression in the event of a loss-of-coolant accident.
The Primary Containment and internal structures provide structural support to safety and nonsafety-related systems, structures, and components housed within the Primary Containment.
The steel lined concrete drywell and suppression chamber walls provide a structural pressure barrier, water retaining boundary, radiation shielding, and structural support for floors in the reactor building including the refueling floor and pools.Major systems and components in the Primary Containment include the reactor vessel and associated auxiliary systems, vent pipe system (downcomers) connecting the drywell and wetwell, containment cooling system, and the main steam safety relief valve (MSRV)discharge piping with associated quencher components.
The Primary Containment consists of the following major structural components:
-Primary Containment wall -The Primary Containment wall is constructed of post-tensioned and reinforced concrete approximately 6 foot thick for the drywell wall and 4 foot thick for the suppression pool wall. The drywell wall is lined with a carbon steel plate on the inside surface.The suppression pool walls are lined with stainless steel. The Primary Containment wall is reinforced with conventional reinforcing steel and with vertical and horizontal tendons. The unbounded tendons are protected by a corrosion protection medium. The Reactor Building floor slabs rest on reinforced concrete corbels that are a part of the Primary Containment wall.-Base foundation slab -The containment base foundation slab is approximately 7 foot thick LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-28 Section 2 -Scoping and Screening Methodology and Results reinforced concrete continuous under both the containment and the reactor building and is founded on soil. The top of the base foundation slab is lined with a stainless steel liner plate that serves as the suppression pool floor.-Liner plate and anchorages
-The carbon steel liner plate in the drywell and the stainless steel liner plate in the suppression pool are %-inch thick except for areas thickened for attachments and are anchored to the concrete containment wall by structural steel members welded to the outside of the liner plate and embedded in the concrete.
Loads from internal containment attachments are transferred directly into the containment concrete wall by thickening the liner, and by attaching structural weldments or embeds that transfer the load to the concrete.-Penetrations and access hatches- Services and access between the inside and the outside of the containment are performed through penetrations.
Basic penetration types include pipe penetrations, electrical penetrations, and access hatches (equipment hatch, personnel lock, suppression chamber access hatches, and CRD removal hatch). Pipe penetration sleeves are embedded into the concrete.
The pipe is welded directly to the head fitting which is welded to the sleeve. Air gaps are provided around the pipes. Pipe penetrations are of welded steel construction without expansion bellows, gaskets, or sealing compounds and are an integral part of the construction.
Electrical penetration assemblies are used to extend electrical conductors through the pressure boundary of the Primary Containment.
The assembly is sized to be inserted in steel penetration sleeves furnished as part of the containment.
Seals are provided between each conductor and the electrical penetration end plate. Access hatches providing access into the Primary Containment are the equipment hatch, personnel lock, suppression chamber access hatches, and the control rod drive removal hatch.-Drywell Head -The drywell head assembly consists of a steel hemi-ellipsoidal head and a cylindrical lower flange. The head is made of steel plate and is secured with bolts at the mating flange to the ring girder assembly, which is also known as the cone skirt.-Internal Structures
-The internal structures consist of reinforced concrete and structural steel and have the major functions of supporting and shielding the reactor vessel, support recirculation pumps, support piping and auxiliary equipment, and form the pressure-suppression system. These structures include the drywell floor, reactor stabilizer structure (or seismic truss), steam supply system supports, reactor pedestal, reactor shield (wall), platforms and galleries, the suppression chamber columns (concrete columns with an outer lining of stainless steel plate) supporting the diaphragm slab, and downcomers and bracing system.The drywell floor serves as a pressure barrier between the drywell and suppression chamber, provides lateral support for the reactor pedestal, and provides lateral and vertical support for the downcomers.
It is a reinforced concrete circular slab, 3 feet thick. A stainless steel liner plate is provided on underside of the drywell floor. The drywell floor is supported by the reactor pedestal, the containment wall, steel lined reinforced concrete columns. The drywell floor is penetrated by 98 downcomers.
The cavity floor which is a reinforced concrete floor slab internal to the reactor pedestal is lined on both the upper and lower sides since it is also the floor of the drywell sump.The reactor stabilizer structure (also known as the seismic truss) is a steel truss which serves to laterally brace the top of the reactor shield wall to the containment wall.LaSalle County Station, Units I and 2 License Renewal Application Page 2.4-29 Section 2 -Scoping and Screening Methodology and Results Reactor steam supply system piping and pumps are supported by various component supports which are supported by the structural steel galleries, or the reactor shield or containment wall. These component supports are evaluated separately with the Component Supports Commodity Group. The reactor stabilizer bracket is included and evaluated with the Primary Containment.
The reactor pedestal is an upright cylindrical reinforced concrete shell that rests on the containment base foundation slab, and supports the drywell floor slab, cavity floor slab, reactor vessel, reactor shield wall, platforms and galleries, downcomer bracing, and piping and equipment supports.The reactor shield wall is a composite steel and plain concrete open-ended upright cylindrical shell placed around the reactor pressure vessel and supported by the reactor pedestal.
The reactor shield functions as a radiation and heat barrier between the RPV and the drywell wall.The reactor shield is also designed as a structural member to support drywell platforms, galleries, equipment and piping-loads as well as to resist pipe rupture, pressure, thermal, and seismic loads. The reactor shield wall is constructed of inner and outer carbon steel plates and un-reinforced concrete between the two (2) plates. The concrete is used for radiation shielding and is not relied upon as a structural element.The drywell platforms and galleries provide access and support for electrical and mechanical components.
The platforms consist of structural steel framing, with steel or aluminum grating and plate. The platforms and galleries consist of structural steel framing supported by the pedestal, containment, and shield walls with steel and aluminum grating. Beams which span between the shield or pedestal and the containment wall are provided with connections at the containment that allow for free thermal expansion.
The suppression chamber columns consist of stainless steel lined reinforced concrete columns which provide support the drywell floor slab.The stainless steel downcomers which connect the drywell to the pool of water in the suppression chamber are provided with bracing in the suppression chamber.Other miscellaneous internal structural components include: pipe whip restraints, wetwell platforms, MSRV discharge pipe bracing and support, quencher supports, equipment and piping supports, reactor shield doors and plugs, seals and gaskets, the containment seal plate, drywell sump liner, and the refueling bellows assembly.Included in the boundary of the Primary Containment are the reinforced concrete components that make up the Primary Containment including the prestressing system components, and internal concrete structures.
Steel elements and components in the boundary of the Primary Containment include gallery structural members, pipe whip restraints, reactor shield, reactor stabilizer structure, reactor stabilizer bracket, downcomers and bracing, vacuum relief valves and piping, refueling bellows assembly, seal plate, grating, liner, liner anchors and integral attachments, and the drywell head. Other components included in the boundary of the Primary Containment are bolting (containment closure and structural), Service Level 1 coatings, concrete anchors and embedments, doors (reactor shield doors and plugs), electrical penetration assemblies, hatches and plugs, metal components ( including permanent drywell shielding), penetration sleeves and flued head closures, personnel lock, equipment hatch, CRD hatch, and other hatches and closures, jet deflectors, seals and gaskets, and includes LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-30 Section 2 -Scoping and Screening Methodology and Results internal structures mentioned above.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Primary Containment.
The Primary Containment performs intended functions delineated in 10 CFR 54.4 and is in scope for license renewal in it's entirely.Not included in the boundary of the Primary Containment are main steam safety relief valves and discharge lines, monorails and hoists, quenchers, drywell and suppression chamber spray headers, ECCS suction strainers, component supports, reactor coolant system and other mechanical systems and components, electrical systems and commodities, fire barriers, and piping and component insulation and structural commodities.
Fire barriers are evaluated separately with the Fire Protection System. Component supports, including their respective bolting, are evaluated with the Component Supports Commodity Group. Structural commodities, including their respective bolting, are evaluated with the Structural Commodity Group. The Structural Commodity Group evaluates components such as cable trays; conduit;doors; piping and component insulation and insulation jacketing; louvers; miscellaneous structural steel including platforms, stairs, ladders; panels, racks, cabinets, and other enclosures for electrical equipment and instrumentation; and tube track. In addition, mechanical and electrical systems and components housed in or located within the Primary Containment are evaluated with their respective mechanical and electrical license renewal system or commodity group.For more detailed information, see UFSAR Sections 3.8.1, and 6.2.1.Reason for Scope Determination The Primary Containment meets 10 CFR 54.4(a)(1) because it is a safety-related structure that is relied upon to remain functional during and following design basis events. The Primary Containment meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Primary Containment also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provides physical support, shelter, and protection for safety-related systems, structures, and components.
10 CFR 54.4(a)(1)
: 2. Provide primary containment boundary.
10 CFR 54.4(a)(1)
: 3. Controls the potential release of fission products to the external environment so that offsite consequences of design basis events are within acceptable limits. 10 CFR 54.4(a)(1)
: 4. Controls the release of fission products to the secondary containment in the event of a design basis loss-of-coolant accident (LOCA) so that offsite consequences are within LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-31 Section 2 -Scoping and Screening Methodology and Results acceptable limits. 10 CFR 54.4(a)(1)
: 5. Provides sufficient air and water volumes to absorb the energy released to the containment in the event of design basis events so that the pressure is within acceptable limits. 10 CFR 54.4(a)(1)
: 6. Provides a source of water for emergency core cooling systems. 10 CFR 54.4(a)(1)
: 7. Provides physical support, shelter, and protection for nonsafety-related systems, structures, and components (SSCs) whose failure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
10 CFR 54.4(a)(2)
: 8. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulation for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
: 9. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulation for Environmental Qualification (10 CFR 50.49).10 CFR 54.4(a)(3)
: 10. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulation for Anticipated Transients Without Scram (10 CFR 50.62). 10 CFR 54.4(a)(3)
: 11. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulation for Station Blackout (10 CFR 50.63). 10 CFR 54.4(a)(3)
UFSAR References Table 3.6-6 Figure 3.6-27 3.8.1 3.8.2 3.8.3 Table 3.8-1 Figure 3.8-1 through 3.8-38 5.3.3.1.4 Table 6.1-1 6.2.1 Table 6.2-1 E.3 E.4 E.5 E.6 E.7 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-32 Section 2 -Scoping and Screening Methodology and Results License Renewal Boundary Drawings LR-M-3 LR-LAS-M-92, Sheet 2 LR-LAS-M-1 38, Sheet 2 Table 2.4-7 Primary Containment Components Subject to Aging Management Review Component Type Intended Function Bolting (Containment Closure) Structural Pressure Barrier Structural Support Bolting (Structural)
Structural Support Bolting (Vacuum Relief Line Pipe Structural Pressure Barrier Flanges) Structural Support Concrete Anchors Structural Support Concrete Embedments Structural Pressure Barrier Structural Support Water retaining boundary Concrete:
Containment Wall (accessible Missile Barrier areas -includes Buttresses)
Shelter, Protection Shielding Structural Pressure Barrier Structural Support Concrete:
Containment Wall (inaccessible Missile Barrier areas -includes Buttresses)
Shelter, Protection Shielding Structural Pressure Barrier Structural Support Concrete:
Foundation, Subfoundation, Shelter, Protection Basemat (accessible areas -Tendon Structural Pressure Barrier Access Tunnel Ceiling) Structural Support Concrete:
Foundation, Subfoundation, Flood Barrier Basemat (inaccessible areas) Shelter, Protection Structural Pressure Barrier Structural Support Concrete:
Interior (Drywell Floor and Direct Flow Cavity Floor) Structural Pressure Barrier Structural Support Concrete:
Interior (Pedestal)
Direct Flow Structural Pressure Barrier Structural Support Concrete:
Interior (Suppression Pool Structural Support Columns)Concrete:
Reactor Cavity Contiguous Shielding Fuel Pool Walls with Tendons LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-33 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function Concrete:
Reactor Cavity Contiguous Structural Support Fuel Pool Walls with Tendons Doors (Reactor Shield Wall Doors) Shielding Structural Support Downcomer Jet Deflectors Direct Flow Shelter, Protection Electrical Penetration Assemblies Shelter, Protection (includes Penetration Sleeves and Structural Pressure Barrier Closure Plates)Hatches/Plugs Missile Barrier Shelter, Protection Structural Pressure Barrier Mechanical Penetrations (includes Shelter, Protection Penetration Sleeves, Flued Heads, and Structural Pressure Barrier Closure Plates for Pipe and Instrument Structural Support Penetrations)
Metal Components (Permanent Drywell Shielding Shielding)
Structural Support Penetration Sleeves: Drywell Floor Structural Pressure Barrier (including Closure Rings, Plates, and Structural Support Caps)Personnel Airlock, Equipment Hatch: Missile Barrier CRD Hatch Shelter, Protection Structural Pressure Barrier Personnel Airlock, Equipment Hatch: Shelter, Protection Locks, Hinges, and Closure Mechanisms Structural Pressure Barrier Pipe Whip Restraints and Jet Pipe Whip Restraint Impingement Shields Prestressing System: Anchorage Structural Support Components Prestressing System: Grease Cap at Shelter, Protection Tendon Anchorage Prestressing System: Tendons Structural Support Seals and Gaskets Structural Pressure Barrier Service Level I Coatings (Containment Maintain Adhesion Boundary)Service Level I Coatings (Internal Maintain Adhesion Structures)
Sliding Surfaces (Support)
Structural Support LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-34 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function Steel Components: (Reactor Shield Wall) Shelter, Protection Shielding Structural Support Steel Components: (Reactor Stabilizer Structural Support Bracket Assembly)Steel Components:
Reactor Stabilizer Structural Support Structure (Stabilizer Truss)Steel Components:
Structural Steel Structural Support Steel Elements: (Grating)
Structural Support Steel Elements: (Refueling Bellows Flood Barrier Assembly)
Shelter, Protection Structural Support Water retaining boundary Steel Elements:
Downcomer Bracing Structural Support (Stiffeners)
Steel Elements:
Downcomers Direct Flow Steel Elements:
Drywell Floor and Cavity Direct Flow Floor Liner, Liner Anchors, Integral Structural Pressure Barrier Attachments Steel Elements:
Drywell Head Missile Barrier Shielding Structural Pressure Barrier Steel Elements:
Drywell Liner, Liner Structural Pressure Barrier Anchors, Integral Attachments Structural Support (accessible areas)Steel Elements:
Drywell Liner, Liner Structural Pressure Barrier Anchors, Integral Attachments Structural Support (inaccessible areas)Steel Elements:
Liner for Concrete Shelter, Protection Columns, Liner Anchors, Integral Attachments Steel Elements:
Liner, Liner Anchors, Direct Flow Integral Attachments (Sump) Water retaining boundary Steel Elements:
Pedestal Liner, Liner Direct Flow Anchors, and Integral Attachments Shelter, Protection Structural Pressure Barrier Steel Elements:
Ring Girder Adapter (Unit Structural Support 1 Vessel Skirt)Steel Elements:
Ring Girder Assembly Flood Barrier (includes Cone Skirt)LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-35 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function Steel Elements:
Ring Girder Assembly Structural Pressure Barrier (includes Cone Skirt) Structural Support Water retaining boundary Steel Elements:
Seal Plate Flood Barrier Structural Support Water retaining boundary Steel Elements:
Suppression Chamber Structural Pressure Barrier Liner, Liner Anchors, Integral Structural Support Attachments (accessible areas) Water retaining boundary Steel Elements:
Suppression Chamber Structural Pressure Barrier Liner, Liner Anchors, Integral Structural Support Attachments (inaccessible areas) Water retaining boundary Steel Elements:
Vacuum Breaker Valves, Pressure Relief Isolation Valves, and Piping Structural Pressure Barrier Tunnel (tendon access tunnel walls and Shelter, Protection floor)The aging management review results for these components are provided in: Table 3.5.2-7 Primary Containment Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-36 Section 2 -Scoping and Screening Methodology and Results 2.4.8 Radwaste Building Description The Radwaste Building, which is also called the solid radwaste building, contains both the solid and liquid processing portions of the Radwaste System. The Radwaste Building is a multi-story structure with above and below grade areas. The structure is a part of the power generation complex which includes several contiguous buildings.
The Radwaste Building is located west of the Turbine Building.
The shear walls for the Reactor Building, Auxiliary Building, Turbine Building, Radwaste Building, Diesel Generator Buildings, and Off-gas Filter Building are interconnected.
These shear walls have been considered to act together to resist lateral loads applied to these buildings.
Therefore, the shear walls for these buildings are Seismic Category I. The Radwaste Building is designed to preclude accidental release of radioactive materials to the environment.
The Radwaste Building does not contain any safety-related equipment.
The Radwaste Building shell is reinforced concrete with the interior walls being made of reinforced concrete and concrete block. The structure is supported on a reinforced concrete mat foundation on soil. The Radwaste Building includes sump(s) to collect waste water, tank rooms with metal liners to retain liquid wastes in event of a spill, a control room, pipe tunnel, truck bay, stainless lined decontamination pit, and a dry waste storage area.The reinforced concrete walls and floors meet structural, as well as radiation shielding requirements.
At certain locations, concrete block masonry walls are used to provide better access for installation and maintenance of equipment.
The purpose of the Radwaste Building is to provide structural support, shelter and protection for nonsafety-related systems, structures, and components that collect, monitor, process, package, and provide temporary storage facilities for radioactive wastes during the operation of the plant. Additionally, the purpose of the Radwaste Building is to prevent liquid radwaste from being released to the environment.
The Radwaste Building is classified as a Seismic Category II, nonsafety-related structure.
However, the Radwaste Building shear walls are designed to act together with the other power generation complex shear walls and are classified as Seismic Category I, and additionally its walls protect against exterior floods. The Radwaste Building also provides physical support, shelter and protection to portions of the Fire Protection System. The Radwaste Building is therefore in scope for license renewal.Included in the boundary of the Radwaste Building and determined to be within the scope of license renewal are the reinforced concrete elements, concrete embedments, concrete anchors, equipment supports and foundations, hatches and plugs, masonry walls, steel components and steel elements of the radwaste building.
Also included within the boundary is structural bolting associated with specific in scope components evaluated as part of the Radwaste Building.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Radwaste Building.Not included within the boundary of the Radwaste Building are the fire barriers, component supports, and structural commodities.
Fire barriers are evaluated separately with the Fire Protection System. Component supports, including their respective bolting, are evaluated with LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-37 Section 2 -Scoping and Screening Methodology and Results the Component Supports Commodity Group. Structural commodities, including their respective bolting, are evaluated with the Structural Commodity Group. The Structural Commodity Group evaluates components such as bird screens; cable trays; compressible joints and seals; conduit; doors; piping and component insulation and insulation jacketing; louvers; miscellaneous structural steel including platforms, stairs, ladders; panels, racks, cabinets, and other enclosures for electrical equipment and instrumentation; penetration seals;penetration sleeves including end caps; roofing; structural sealants, seismic gap seals, gaskets, flashing and other sealants and gap seals; and tube track. In addition, mechanical and electrical systems and components housed in or located within the Radwaste Building are evaluated with their respective mechanical and electrical license renewal system or commodity group.For more detailed information, see UFSAR Sections 1.1, 3.1.2.6.2.3, 3.4.1.3, 3.8.4.1.7.1, and Table 3.2-1.Reason for Scope Determination The Radwaste Building is not in scope under 10 CFR 54.4(a)(1) because no portions of the structure are safety-related and relied upon to remain functional during and following design basis events. The Radwaste Building meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Radwaste Building also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Radwaste Building is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provides physical support, shelter, and protection for nonsafety-related systems, structures, and components whose failure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
10 CFR 54.4(a)(2)
: 2. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
UFSAR References 1.1 1.2.2.2.i 3.1.2.6.2.3 Table 3.2-1 3.4.1.3 3.8.4.1 3.8.4.1.7.1 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-38 Section 2 -Scoping and Screening Methodology and Results 3.11.1.2 7.7.11.2.2 9.1.3.1.2 9.4.3.4.2 11.2.1.9.1 11.4.2.7 12.3.1.6.1 12.3.2.4 15.7.3.1 15.7.3.2 Appendix E -Construction Material License Renewal Boundary Drawinas LR-M-3 Table 2.4-8 Radwaste Building Components Subject to Aging Management Review Component Type Intended Function Bolting (Structural)
Structural Support Concrete Anchors Structural Support Concrete Curbs Direct Flow Concrete Embedments Structural Support Concrete:
Above-grade Exterior Flood Barrier (accessible areas) Shelter, Protection Shielding Structural Support Concrete:
Above-grade Exterior Flood Barrier (inaccessible areas) Shelter, Protection Shielding Structural Support Concrete:
Below-grade Exterior Flood Barrier (inaccessible areas) Shelter, Protection Structural Support Water retaining boundary Concrete:
Foundation, Subfoundation Flood Barrier (inaccessible areas) Shelter, Protection Structural Support Water retaining boundary Concrete:
Interior Shelter, Protection Shielding Structural Support Water retaining boundary Equipment Supports and Foundations Structural Support Hatches/Plugs Shelter, Protection Shielding Structural Support LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-39 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function Masonry Walls: Above-grade Exterior Shelter, Protection Shielding Structural Support Masonry Walls: Interior Shelter, Protection Shielding Structural Support Steel Components:
Structural Steel Structural Support Steel Elements:
Liner, Liner Anchors, Water Retaining Boundary Integral Attachments (Sump or Pit Liners)Steel Elements:
Liner, Liner Anchors, Water Retaining Boundary Integral Attachments (Tank Room or Compartment Liner)The aging management review results for these components are provided in: Table 3.5.2-8 Radwaste Building Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-40 Section 2 -Scoping and Screening Methodology and Results 2.4.9 Reactor Building Description The Reactor Building is a Seismic Category I safety-related structure which includes the equipment access building.
Portions of the multi-level structure are constructed above and below grade. The Reactor Building is comprised of an integral structure divided into separate Unit 1 and Unit 2 Reactor Building(s) which share a common foundation, common walls dividing the Unit 1 and Unit 2 portions, common refueling floor area, equipment access building, and a common roof.The structure is a part of the power generation complex which includes several contiguous buildings.
The Reactor Building is located east of the Seismic Class I safety-related Auxiliary Building, and west of the Offgas Building.
The Diesel Generator Buildings are located north and south of the Reactor and Auxiliary Buildings.
The shear walls for the Reactor Building, Auxiliary Building, Turbine Building, Radwaste Building, Diesel Generator Buildings, and Off-gas Filter Building are interconnected.
These shear walls have been considered to act together to resist lateral loads applied to these buildings.
Therefore, the shear walls for these buildings are Seismic Category I.The Reactor Building consists of poured-in-place, reinforced concrete exterior walls up to the refueling floor. Above this level, the building structure is steel frame with insulated metal siding with sealed joints. The Reactor Building is supported on a reinforced concrete mat foundation on soil that is continuous under the Primary Containment structure, Auxiliary Building, Diesel Generator Buildings, and Turbine Buildings.
The Reactor Building metal siding is designed to blow-off during tornado winds. The roof consists of galvanized metal decking with built-up roofing. Reactor Building floors are supported by shear walls, containment and pool walls, and by a beam and column framing system. Diagonal flood walls are provided to isolate the residual heat removal and core spray pumps and to prevent other areas of the Reactor Building from being flooded. The exterior walls of the Reactor Building are designed to carry a negative pressure of 0.25 psig and will serve as the containment during shutdown when the primary containment vessel is open for refueling or maintenance.
Normal access to the Reactor Building for equipment is through an air lock located in the equipment access building.
The refueling pools are located below the operating floor in the Reactor Building and include the spent fuel and dryer-separator pools. The pools are integrally connected to, and supported by, the containment vessel and exterior Reactor Building walls. The inside surfaces of the pools are lined with 1/4-inch thick stainless steel plate which serves as a leakage barrier.The Reactor Building includes a reinforced concrete main steam chase which connects the primary containment to the main steam tunnel. It protects the main steam line piping from external missiles and protects the other Seismic Category I components in the Reactor Building from the effect of steam in the unlikely event of a pipe rupture inside the chase.The equipment access building is located at the grade level on the east side of the Reactor Building, north of, and contiguous with, the Offgas Building.
It provides controlled access to the Reactor Building for equipment, including a rail car, by means of an air lock equipped with inner bulkhead doors that are flood and missile proof. The air lock, and the equipment access building are an extension of the Reactor Building envelope and are therefore addressed as part of the Reactor Building.
The equipment access building is Seismic Category I and LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-41 Section 2 -Scoping and Screening Methodology and Results consists of reinforced concrete walls and roof. The majority of the south wall of the equipment access building is common with the north wall of the Offgas Building.At certain locations within the Reactor Building concrete block masonry walls are used to provide better access for erecting and installing equipment.
The block walls also meet the structural and radiation shielding requirements.
The Reactor Building completely encloses the Primary Containment.
The purpose of the Reactor Building is to provide secondary containment when the Primary Containment is in service and to provide primary containment during reactor refueling and maintenance operations when the Primary Containment is open. The Reactor Building provides structural support, shelter, and protection to systems, structures, and components housed within, during normal plant operation, and during and following postulated design basis accidents and extreme environmental conditions.
The Reactor Building is a safety-related Seismic Category I reinforced concrete structure designed to maintain structural integrity during and following postulated design basis accidents and extreme environmental conditions.
The Reactor Building houses refueling and reactor servicing equipment, new and spent fuel storage facilities, and other reactor safety and auxiliary systems.The Reactor Building is provided with various types of doors which allow personnel and equipment access to and from plant compartments.
Personnel access openings into the buildings are provided with an interlocked double door airlock system to minimize Reactor Building air leakage. The doors are addressed with the Structural Commodity Group. Safety-related systems and components are protected against failures of high energy lines by concrete walls. Pipe whip restraints are provided in the primary containment and in the portion of the main steam tunnel located in the auxiliary building and are evaluated with those structures.
The ECCS pumps and their associated components are located in individual compartments within a Reactor Building to provide physical separation.
Compartment walls may also in some cases provide flood protection and function as missile barriers.
Protection against over pressurization of the various essential equipment compartments in the Reactor Building as a result of line breaks is provided by. steam venting paths between the various compartments and by blowout panels leading to adjacent spaces or the outside atmosphere.
Included in the boundary of the Reactor Building are bearing pads, blow out panels, bolting, concrete elements of the building, concrete anchors, curbs, concrete embedments, equipment foundations, hatches, plugs, masonry walls, metal decking, metal panels, metal siding, steel components, steel elements including sump liners. Also included in the boundary of the Reactor Buildings are the spent fuel pool liner, spent fuel pool gates, cask loading pit liner, reactor cavity liner, and the steam dryer and moisture separator storage pool liner.The components in the boundary of the Reactor Building are in the scope of license renewal and subject to aging management review.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Reactor Buildings.
Not included in the boundary of the Reactor Buildings are the Primary Containments and associated refueling bellows and seals, the ventilation systems components, other mechanical and electrical systems and components housed within the building, fire barriers, the refueling LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-42 Section 2 -Scoping and Screening Methodology and Results platform, new fuel storage racks and spent fuel storage racks, miscellaneous cranes, including reactor building crane and hoists, building elevators, component supports, and piping and component insulation.
Mechanical and electrical systems and components housed inside the structure are separately evaluated with their respective mechanical systems, electrical systems, or commodities.
Fire barriers are evaluated with the Fire Protection System and the refueling platform, new fuel storage racks, and spent fuel storage racks and the reactor building crane and the miscellaneous cranes and hoists are evaluated with the Cranes, Hoists and Refueling Equipment System. Component supports are evaluated with the Component Supports Commodity Group. Structural commodities, including their respective bolting, are evaluated with the Structural Commodity Group. The Structural Commodity Group evaluates components such as bird screens; cable trays; compressible joints and seals; conduit; doors;piping and component insulation and insulation jacketing; louvers; miscellaneous structural steel including platforms, stairs, ladders; panels, racks, cabinets, and other enclosures for electrical equipment and instrumentation; penetration seals; penetration sleeves including end caps; roofing; structural sealants, seismic gap seals, gaskets, flashing and other sealants and gap seals; and tube track.For more detailed information, see UFSAR Section 3.8.4.1.1.
Reason for Scope Determination The Reactor Building meets 10 CFR 54.4(a)(1) because it is a safety-related structure that is relied upon to remain functional during and following design basis events. The Reactor Building meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Reactor Building also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provides physical support, shelter, and protection for safety-related systems, structures, and components (SSCs). 10 CFR 54.4(a)(1)
: 2. Controls the potential release of fission products to the external environment so that offsite consequences of design basis events are within acceptable limits. 10 CFR 54.4(a)(1)
: 3. Provides protection for safe storage of new and spent fuel. 10 CFR 54.4(a)(1)
: 4. Provides physical support, shelter, and protection for nonsafety-related systems, structures, and components (SSCs) whose failure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
10 CFR 54.4(a)(2)
: 5. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulation for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-43 Section 2 -Scoping and Screening Methodology and Results 6. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulation for Environmental Qualification (10 CFR 50.49).10 CFR 54.4(a)(3)
: 7. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulation for Anticipated Transients Without Scram (10 CFR 50.62). 10 CFR 54.4(a)(3)
: 8. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulation for Station Blackout (10 CFR 50.63). 10 CFR 54.4(a)(3)
UFSAR References 1.1 1.2.2.2 1.2.2.4.2 Figure 2.5-51 3.1.2.2.7 3.1.2.6.2 Table 3.2-1 with note 22 and 34 3.3.2.2.2 3.3.2.3 3.4.2 3.5.2.2 Figure 3.5-3 3.8.4 3.8.4.1.1 3.8.4.1.3 3.8.4.1.6.2 3.8.4.1.6.3 3.8.4.3 3.8.5 3.11.1.1 6.2.3 9.1.2 9.5.1.2.2 License Renewal Boundary Drawings LR-M-3 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-44 Section 2 -Scoping and Screening Methodology and Results Table 2.4-9 Reactor Building Components Subject to Aging Management Review Component Type Intended Function Bearing Pads Structural Support Blowout Panels Pressure Relief Shelter, Protection Bolting (Structural)
Structural Support Concrete Anchors Structural Support Concrete Curbs Direct Flow Concrete Embedments Structural Support Concrete:
Above-grade Exterior Flood Barrier (accessible areas) Missile Barrier Shelter, Protection Shielding Structural Pressure Barrier Structural Support Concrete:
Above-grade Exterior Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Shielding Structural Pressure Barrier Structural Support Concrete:
Below-grade Exterior Flood Barrier (accessible areas) Missile Barrier Shelter, Protection Shielding Structural Pressure Barrier Structural Support Concrete:
Below-grade Exterior Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Structural Pressure Barrier Structural Support Concrete:
Foundation, Subfoundation Flood Barrier (inaccessible areas) Missile Barrier Shelter, Protection Structural Pressure Barrier Structural Support Concrete:
Interior Flood Barrier HELB/MELB Shielding Missile Barrier LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-45 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function Concrete:
Interior Shelter, Protection Shielding Structural Pressure Barrier Structural Support Equipment Supports and Foundations Structural Support Hatches/Plugs Flood Barrier HELB/MELB Shielding Missile Barrier Shelter, Protection Shielding Structural Support Masonry Walls: Interior Missile Barrier Shelter, Protection Shielding Structural Support Metal Decking Structural Support Metal Panels (Includes Steel and Lead- Shielding Filled Steel Shield Panels) Structural Support Metal Siding Pressure Relief Shelter, Protection Structural Pressure Barrier Spent Fuel Pool Gates Water retaining boundary Steel Components:
Structural Steel Structural Support Steel Elements:
Fuel Pool Liner, Liner Structural Support Anchors, and Integral Attachments Water retaining boundary Steel Elements:
Plates: includes Structural Support Checkered Plate Covers Steel Elements:
Reactor Well, Dryer and Structural Support Separator Pool, and Cask Loading Pit Water Retaining Boundary Liner, Liner Anchors, and Integral Attachments Steel Elements:
Sump Liners and Integral Water Retaining Boundary Attachments The aging management review results for these components are provided in: Table 3.5.2-9 Reactor Building Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-46 Section 2 -Scoping and Screening Methodology and Results 2.4.10 Structural Commodity Group Description The Structural Commodity Group shares material and environment properties allowing common programs across all in scope structures to manage their aging effects. Structural Commodities include bird screens; cable trays; compressible joints and seals; conduit; doors;insulation and insulation jacketing; louvers; spray shields; miscellaneous steel (catwalks, stairs, handrails, ladders, platforms, etc.); panels, racks, cabinets, and other enclosures; penetration seals and sleeves; roofing, seals, gaskets, and moisture barriers; tube track; and structural bolting and concrete anchors associated with these commodities.
Structural commodities are located in the structures that are within the scope of license renewal.Bird Screens: Bird screens within the scope of license renewal include those bird screens attached to stationary louvers that are within the scope of license renewal and perform a license renewal intended function for filtering.
Cable Trays: Cable trays within the scope of license renewal include cable trays that provide license renewal intended functions of structural support and shelter/protection for various electrical and control system power, control, and instrumentation cables that are within the scope of license renewal.Compressible Joints and Seals: Compressible joints and seals within the scope of license renewal include those items that perform a license renewal intended function of shelter/protection or water retaining boundary for structures or structural components which are within the scope of license renewal. This commodity group also includes flexible sections of iso-phase and non-segregated bus ductwork.Conduit: Conduit within the scope of license renewal include conduit that provide license renewal intended functions of structural support and shelter/protection for various electrical and control system power, control and instrumentation cables that are within the scope of license renewal.Doors: Doors within the scope of license renewal include those doors that perform various license renewal intended functions for shelter/protection, flood barrier, structural pressure barrier, radiation shielding, and HELB shielding for structures which are within the scope of license renewal. Not included in the boundary for this commodity are fire barrier doors that perform an intended function for fire protection and containment airlocks and equipment hatches. Fire barrier doors are identified and evaluated with the license renewal Fire Protection System.Containment airlocks and equipment hatches are identified and evaluated with the license renewal Primary Containment structure.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-47 Section 2 -Scoping and Screening Methodology and Results Insulation and Insulation Jacketing:
Insulation and insulation jacketing within the scope of license renewal includes the insulation and associated jacketing and straps for all insulated piping and components that are within the scope of license renewal.Metallic insulation consists of stainless steel mirror insulation.
Nonmetallic insulation consists of fiberglass, calcium silicate, ceramic or glass fiber, polymers, and foamed plastic.Metallic insulation jacketing consists of aluminum, and stainless steel held in place by metallic straps, clips or bolts.The purpose of the insulation is to improve thermal efficiency, minimize heat loads on the HVAC systems, provide for personnel protection, or prevent freezing of heat traced piping and sweating of cold piping and components.
The insulation jacketing maintains the integrity of the underlying insulation and prevents water intrusion.
Piping and component insulation located inside of structures that are within the scope of license renewal can be required to resist seismic loading conditions and therefore, is within the scope of license renewal since failure of this insulation could impact a function defined for 10 CFR 54.4(a)(1).
Nonsafety-related piping and component insulation located inside structures that are within the scope of license renewal can be required to protect nearby safety-related components from overheating and therefore, is within the scope of license renewal since its failure could impact a function defined for 10 CFR 54.4(a)(2).
Nonsafety-related piping and component insulation which performs a function for freeze protection of heat traced piping and components is also within the scope of license renewal under 10 CFR 54.4(a)(2).
Thermal piping and component insulation located inside structures that are not within the scope of license renewal is not within the scope of license renewal since failure of this insulation will not impact intended safety-related functions.
Louvers: Louvers within scope of license renewal include those louvers that perform a license renewal intended function for shelter and protection and are located in structures that are within the scope of license renewal.Spray Shields: Spray Shields within the scope of license renewal, includes metal shielding that performs a license renewal intended function of shelter/protection and is located on components that are within the scope of license renewal and whose failure could impact a function defined for 10 CFR 54.4(a)(1).
Miscellaneous Steel (catwalks, stairs, handrails, ladders, and platforms, etc.): Miscellaneous steel (catwalks, stairs, handrails ladders, and platforms, etc.) components that perform license renewal intended functions for structural support are located within structures that are in scope of license renewal or whose failure of a miscellaneous steel component LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-48 Section 2 -Scoping and Screening Methodology and Results during a seismic event could impact a function defined for 10 CFR 54.4(a)(2).
Included in this commodity group are the structural bolts associated with these steel structures described previously in this document.Panels, Racks, Cabinets, and Other
 
==Enclosures:==
 
Panels, Racks, Cabinets, and Other Enclosures within the scope of license renewal include those items that perform license renewal intended functions for shelter/protection and structural support for equipment and components within the scope of license renewal.Penetration Seals: Penetration Seals within the scope of license renewal include penetrations in walls, floors and ceilings that perform license renewal intended functions for shelter/protection, structural pressure boundary, structural support, flood barrier, radiation shielding, and HELB shielding for structures and components which are within the scope of license renewal. Not included in the boundary for this commodity are Primary Containment penetration seals and fire barrier penetration seals. Primary Containment penetration seals are identified and evaluated with the Primary Containment Structure.
Fire barrier penetration seals are identified and evaluated with the license renewal Fire Protection System.Penetration Sleeves: Penetration Sleeves within the scope of license renewal include those items that perform license renewal intended functions for structural support, flood barrier, shielding, HELB shielding, pipe whip restraint, structural pressure barrier, and shelter/protection for structures and components which are within the scope of license renewal. Not included in the boundary for this commodity are Primary Containment penetration sleeves and fire barrier penetration sleeves. Primary Containment penetration sleeves are identified and evaluated with the Primary Containment structure.
Fire barrier penetration sleeves are identified and evaluated with the Fire Protection System.Roofing: Roofing within the scope of license renewal include those roofs that perform license renewal intended functions for shelter/protection for structures which are within the scope of license renewal. The roofing material consists of the roofing outer membrane.
Not included in the boundary for this commodity are the structural components that support the roofs. Structural components that support the roofs are identified and evaluated with the associated structures.
Seals, Gaskets, and Moisture Barriers (caulking, flashing, and other sealants):
Seals, gaskets, and moisture barriers (caulking, flashing, and other sealants) within the scope of license renewal include those items that perform license renewal intended functions for shelter/protection, flood barrier, structural pressure barrier, radiation shielding, and HELB shielding for structures and components which are within the scope of license renewal. Not included in the boundary for this commodity are seals, gaskets, and moisture barriers (caulking, flashing, and other sealants) used for Primary Containment pressure boundary integrity and seals, gaskets, and moisture barriers (caulking, flashing, and other sealants)used for fire protection.
Seals, gaskets, and moisture barriers (caulking, flashing, and other LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-49 Section 2 -Scoping and Screening Methodology and Results sealants) used for Primary Containment pressure boundary integrity are identified and evaluated in the Primary Containment Structure.
Seals, gaskets, and moisture barriers (caulking, flashing, and other sealants) used for fire protection are identified and evaluated with the license renewal Fire Protection System.Tube Track: Tube track within the scope of license renewal includes tube track that performs license renewal intended functions for structural support and shelter/protection for various instrumentation tubing that is within the scope of license renewal.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Structural Commodity Group.For more detailed information regarding structural commodities see UFSAR Sections 3.4.1.3, 3.4.1, 3.5.2.2, 3.8.4.1.7.2, Table 3.2-1, 5.2.3.1, 5.2.4.2, 5.3.3.1.4, 6.1.1.1, Table 6.1-2, 8.3.1.4.3, 9.4.2.2, and 9.5.8.2.Reason for Scope Determination The Structural Commodity Group meets 10 CFR 54.4(a)(1) because it is a safety-related structure that is relied upon to remain functional during and following design basis events. The Structural Commodity Group meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Structural Commodity Group also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63). The Structural Commodity Group is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).Intended Functions 1. Provides physical support, shelter, and protection for safety-related systems, structures, and components.
10 CFR 54.4(a)(1)
: 2. Provides physical support, shelter, and protection for nonsafety-related systems, structures, and components whose failure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
10 CFR 54.4(a)(2)
: 3. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
: 4. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transients Without Scram (10 CFR 50.62). 10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-50 Section 2 -Scoping and Screening Methodology and Results 5. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). 10 CFR 54.4(a)(3)
UFSAR References 3.4.1.3 3.4.1 3.5.2.2 3.8.4.1.7.2 Table 3.2-1 5.2.3.1 5.2.4.2 5.3.3.1.4 6.1.1.1 Table 6.1-2 8.3.1.4.3 9.4.2.2 9.5.8.2 License Renewal Boundary Drawings LR-M-3 Table 2.4-10 Structural Commodity Group Components Subject to Aging Management Review Component Type Intended Function Bird Screen Filter Bolting (Structural)
Structural Support Cable Trays Shelter, Protection Structural Support Compressible Joints and Seals Shelter, Protection Water retaining boundary Conduit Shelter, Protection Structural Support Doors Flood Barrier HELB/MELB Shielding Shelter, Protection Shielding Structural Pressure Barrier Insulation Thermal Insulation Insulation Jacketing (includes Clamps, Thermal Insulation Jacket Integrity Bands, and Fasteners)
Louver Shelter, Protection Metal Components (Spray Shields) Shelter, Protection LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-51 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function Miscellaneous Steel (Catwalks, Stairs, Handrails, Ladders, Platforms, etc.) Structural Support Panels, Racks, Frames, Cabinets, and Shelter, Protection Other Enclosures Structural Support Penetration Seals Flood Barrier HELB/MELB Shielding Pressure Boundary Shelter, Protection Shielding Structural Support Penetration Sleeves (includes Sleeve Flood Barrier Head Plates) HELB/MELB Shielding Pressure Boundary Shelter, Protection Shielding Structural Support Roofing Shelter, Protection Seals, Gaskets, and Moisture Barriers Flood Barrier (Caulking, Flashing and Other Sealants)
HELB/MELB Shielding Pressure Boundary Shelter, Protection Tube Track Shelter, Protection Structural Support The aging management review results for these components are provided in: Table 3.5.2-10 Structural Commodity Group Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-52 Section 2 -Scoping and Screening Methodology and Results 2.4.11 Switchyard Structures Description The Switchyard Structures include the 345-kV switchyard, the switchyard relay house and the switchyard maintenance building.
The Switchyard Structures support connection between the offsite transmission network and the onsite distribution, including unit generators.
The 345-kV switchyard is located east-southeast of the power block.The foundations within the 345-kV switchyard consist of reinforced concrete bearing on soil.The switchyard relay house is a single story masonry wall structure above grade, with reinforced concrete walls below grade supported on a reinforced concrete foundation slab on soil. The roof is comprised of a precast concrete with built-up roofing. The switchyard maintenance building is of similar construction and its foundation is reinforced concrete slab on grade with reinforced concrete footings around the perimeter.
The Switchyard Structures are nonsafety-related.
The purpose of the Switchyard Structures is to provide physical support, shelter, and protection for Offsite Power System components, as well as, serving as the electrical transmission terminals for each unit. The Offsite Power System is relied upon to provide offsite power during plant shutdown and in the event of a site emergency.
The foundations and supports for four breakers located in the Switchyard Structures are relied on to provide physical support and the switchyard relay house provides physical support and shelter and protection for components relied upon to provide offsite power during station blackout (SBO) and fire safe shutdown and are therefore, in scope for license renewal. The remainder of the Switchyard Structures, including the switchyard maintenance building are not in scope for license renewal.Included in the boundary of the Switchyard Structures and determined to be within scope of license renewal are structural bolting, concrete, concrete anchors, concrete curbs and concrete embedments, concrete foundations, hatches, plugs, masonry walls, and steel components.
Switchyard Structures that provide structural support, shelter, and protection for the Offsite Power System components are in scope for license renewal. Other components and structures including the switchyard maintenance building and the wood lighting poles do not perform an intended function and are therefore, not in the scope of license renewal.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Substation.
Not included in the evaluation boundary of the Switchyard Structures are structural commodities, and component supports other than the substation equipment supports, fire barriers, the transmission and takeoff towers, and components and commodities which are evaluated separately under the respective system or commodity grouping.
Other component supports are identified and evaluated separately with the Component Supports Commodity Group. Structural commodities are identified and separately evaluated within the Structural Commodity Group. The fire barriers are evaluated with the Fire Protection System. The transmission and takeoff towers are evaluated within the Yard Structures package. The 138-kV portion of the switchyard is not in scope and only provides power to the not inscope river screen house and the on-the site 12-kV distribution system. Mechanical and electrical systems and components housed or located in the vicinity of the Switchyard Structures are evaluated with their respective mechanical and electrical license renewal system or LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-53 Section 2 -Scoping and Screening Methodology and Results component groups.For more detailed information see UFSAR Section 1.2.3.2.1, 8.1.2, 8.2, and 8.3.Reason for Scope Determination The Switchyard Structures are not in scope under 10 CFR 54.4(a)(1) because no portions of the structure is safety-related or relied upon to remain functional during and following design basis events. The Switchyard Structures are not in scope under 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure would not prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Switchyard Structures meet 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48) and Station Blackout (10 CFR 50.63). The Switchyard Structures is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49) and Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
: 2. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). 10 CFR 54.4(a)(3)
UFSAR References 1.2.3.2.1 8.1.2 8.2 8.3 Figure 8.1-1 Figure 8.1-2 Figure 8.1-3 Appendix H, Fire Protection Report License Renewal Boundary Drawings LR-M-3 LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-54 Section 2 -Scoping and Screening Methodology and Results Table 2.4-11 Switchyard Structures Components Subject to Aging Management Review Component Type Intended Function Bolting (Structural)
Structural Support Concrete Anchors Structural Support Concrete Curbs Direct Flow Concrete Embedments Structural Support Concrete:
Above-grade Exterior Structural Support (accessible areas)Concrete:
Below-grade Exterior Shelter, Protection (inaccessible areas) Structural Support Concrete:
Foundation, Subfoundation Structural Support (inaccessible areas)Concrete:
Interior Shelter, Protection Structural Support Equipment Supports and Foundations Structural Support Hatches/Plugs Shelter, Protection Structural Support Manholes, Handholes, and Duct Banks Shelter, Protection (Trough)Masonry Walls: Above-grade Exterior Shelter, Protection Structural Support Masonry Walls: Interior Shelter, Protection Structural Support Steel Components:
Structural Steel Structural Support The aging management review results for these components are provided in: Table 3.5.2-11 Switchyard Structures Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-55 Section 2 -Scoping and Screening Methodology and Results 2.4.12 Tank Foundations and Dikes Description Tank Foundations and Dikes consist of the cycled condensate storage tank foundations and dikes, clean condensate tank foundation, demineralized water tank foundation, well water storage tank foundation, and demineralizer regenerative solution tank foundation.
The Unit 1 and Unit 2 cycled condensate storage tank foundations and dikes are located on the south-west side of the power block. The dike (also known as a berm) for each tank is composed of reinforced concrete with a liner system. The cycled condensate tanks are supported by a circular reinforced concrete ring foundation pad. The remainder of the tank bottom is supported by a layer of clean sand on top of compacted structural backfill.
The dike areas also contain galvanized steel valve enclosures which shelter RCIC valves and piping.The dike was installed for spill mitigation.
The dike does not perform an intended function, and therefore is not in scope for license renewal. The Unit 1 and Unit 2 cycled condensate storage tanks are credited to support fire protection (fire safe shutdown), and therefore their foundations perform an intended function and are in scope for license renewal. The tank is separated from safety-related systems, structures, and components such that its failure would not impact a safety-related function.
The tanks are evaluated with their respective mechanical system. The steel valve enclosures, contained within the dike area, shelter and protect safety-related and nonsafety-related valves and piping connected to the cycled condensate tanks and is therefore in scope for license renewal.The well water storage tank for the domestic water system is located south-west of the power block. The tank is supported on a circular concrete ring foundation pad. The remainder of the tank bottom is supported by a layer of clean sand on top of compacted structural backfill.
The tank is separated from safety-related systems, structures, and components such that its failure would not impact a safety-related function.
The well water storage tank foundation does not perform an intended function and is therefore, not in scope of license renewal.The demineralizer water storage tank for the domestic water system is located south-west of the power block. The tank is supported on a circular concrete ring foundation pad. The remainder of the tank bottom is supported by a layer of clean sand on top of compacted structural backfill.
The tank is separated from safety-related systems, structures, and components such that its failure would not impact a safety-related function.
The demineralizer water storage tank foundation does not perform an intended function and is therefore, not in scope of license renewal.The demineralizer regenerative solution tank is located south-west of the power block and consists of a circular concrete ring foundation pad on grade. The remainder of the tank bottom is supported by a layer of clean sand on top of compacted structural backfill.
It is separated from safety-related systems, structures, and components such that its failure would not impact a safety-related function.
The demineralizer regenerative storage tank foundation does not perform an intended function and is therefore, not in scope of license renewal.The clean condensate tank is located south-west of the power block. The tank is supported on a circular concrete ring foundation pad. The remainder of the tank bottom is supported by a layer of clean sand on top of compacted structural backfill.
The tank is separated from safety-related systems, structures, and components such that its failure would not impact a safety-LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-56 Section 2 -Scoping and Screening Methodology and Results related function.
The clean condensate tank foundation does not perform an intended function and is therefore, not in scope of license renewal.The purpose of the Tank Foundation and Dikes is to provide structural support, shelter, and protection for safety-related and nonsafety-related components and commodities including systems and components which support fire safe shutdown.
The purpose of the dikes around the Cycled Condensate Tanks is for spill mitigation.
Included in the boundary of the Tank Foundation and Dikes and determined to be in scope are bolting, concrete anchors, concrete elements, and steel elements (valve enclosures) associated with the cycled condensate storage tanks. Other structures and components within the Tank Foundation and Dikes evaluation boundary do not perform a license renewal intended function and are not in scope for license renewal.Refer to "Components Subject to Aging Management Review" table for a complete list of components included in the boundary of the Tank Foundation and Dikes.Not included in the boundary of the Tank Foundation and Dikes are component supports, piping and component insulation.
Component supports, including their respective bolting, are evaluated with the Component Supports Commodity Group. Other structural commodities, including insulation are evaluated with the Structural Commodity Group. In addition, the tanks and associated mechanical and electrical systems and components located in the vicinity of these tanks are evaluated with their respective mechanical and electrical license renewal system or component groups. Miscellaneous structures are evaluated within the Miscellaneous Not in Scope Structures group.For more detailed information, see UFSAR Sections 1.2.2.3.10, 3.1.2.4.6, Table 3.2-1, 9.2.7.2, and 9.2.7.3.Reason for Scope Determination The Tank Foundations and Dikes is not in scope under 10 CFR 54.4(a)(1) because no portions of the structure are safety-related and relied upon to remain functional during and following design basis events. The Tank Foundations and Dikes is not in scope under 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure would not prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Tank Foundations and Dikes also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). The Tank Foundations and Dikes is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions 1. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48).LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-57 Section 2 -Scoping and Screening Methodology and Results UFSAR References 1.2.2.3.10 3.1.2.4.6 Table 3.2-1 4.6.1.1.2.1 4.6.1.1.2.4.2.1 5.4.6.2.3 5.4.6.3 5.4.6.5 6.1.1.2 9.2.7.2 9.2.7.3 License Renewal Boundary Drawings LR-M-3 Table 2.4-12 Tank Foundations and Dikes Components Subject to Aging Management Review Component Type Intended Function Bolting Structural Support Concrete Anchors Structural Support Concrete:
Foundation, Subfoundation Structural Support (accessible areas -Cycled Condensate Tank Foundation)
Concrete:
Foundation, Subfoundation Structural Support (inaccessible areas -Cycled Condensate Tank Foundation)
Seals, Gaskets, and Moisture Barriers Shelter, Protection (Caulking, Flashing and Other Sealants)Steel Elements (Cycled Condensate Tank Shelter, Protection Valve Enclosures)
The aging management review results for these components are provided in: Table 3.5.2-12 Tank Foundations and Dikes Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-58 Section 2 -Scoping and Screening Methodology and Results 2.4.13 Turbine Building Description The Turbine Building is divided into two units with a common operating floor. The Turbine Building is a steel framed and reinforced concrete structure enclosed with metal siding above grade. The structure is a part of the power generation complex which includes several contiguous buildings.
The Turbine Building is located west of the Auxiliary Building.
The shear walls for the Reactor Building, Auxiliary Building, Turbine Building, Radwaste Building, Diesel Generator Buildings, and Off-gas Filter Building are interconnected.
These shear walls have been considered to act together to resist lateral loads applied to these buildings.
Therefore, the shear walls for these buildings are Seismic Category I.The Turbine Building is a multi-story structure comprised of a reinforced concrete substructure supported on a reinforced concrete mat foundation on soil with a steel frame above the grade floor. The below grade portion of the Turbine Building includes a pipe tunnel, valve pits, decontamination pits, and sump pits. The exterior walls above grade are insulated metal siding. Structural steel columns support the Turbine Building crane and the roof. The two 210 ton overhead cranes, one for each unit service the turbine-generators.
The roof is galvanized metal decking with insulation and built-up roofing. The concrete turbine pedestal foundation is isolated from the turbine building floors above grade. The heater bay area, located on the west side of the Turbine Building, is included within the boundary of the Turbine Building.
The heater bay area consists of a monolithic concrete substructure supported on a mat foundation with steel framing above grade. Exterior walls are reinforced concrete.
The major portion of the heater bay area roof is poured concrete and the balance consists of galvanized metal decking with insulation and built-up roofing. Structural steel floor framing and grating is provided around the heaters.The Turbine Building houses the turbine-generators, condensing equipment, moisture separator-reheaters, and feedwater heaters.The Turbine Building superstructure is designed to withstand the tornado loads on the exposed structural frame so that collapse is prevented.
The turbine room siding and roof decking is designed to blow off in an approaching tornado, to ensure venting of the structure.
The Turbine Building is classified as a Seismic Category II, nonsafety-related structure.
However, the Turbine Building foundation shear walls are designed to act together with the other power generation complex shear walls and are Seismic Category I.The purpose of the Turbine Building is to provide structural support, shelter, and protection for nonsafety-related systems, structures, and components during normal plant operation and certain safety-related system components during both normal operations and during and following the SSE seismic event. The Turbine Building contains steam and power conversion systems components and the support systems and components necessary to support fire protection, and station blackout.Included in the boundary of the Turbine Building and determined to be within the scope of license renewal are the blowout panels, concrete anchors, concrete embedments, curbs, equipment supports and foundations, hatches, plugs, masonry walls, metal decking, metal siding, pipe whip restraints, reinforced concrete elements of the building, steel components, steel elements, and structural bolting, The Turbine Building is in scope for license renewal in LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-59 Section 2 -Scoping and Screening Methodology and Results its entirety except that architectural elements in the miscellaneous operational and maintenance support areas that include furniture, drywall partitions and soffits, storage enclosures and suspended ceilings do not perform an intended function for license renewal and are not in scope.Refer to the "Components Subject to Aging Management Review" table below for a complete list of components included in the boundary of the Turbine Building.Not included within the evaluation boundary of the Turbine Building are the fire barriers, component supports, and structural commodities.
Fire barriers are evaluated separately with the Fire Protection System. Component supports, including their respective bolting, are evaluated with the Component Supports Commodity Group. Structural commodities, including their respective bolting, are evaluated with the Structural Commodity Group. The Structural Commodity Group evaluates components such as bird screens; cable trays; compressible joints and seals; conduit; doors; piping and component insulation and insulation jacketing; louvers; miscellaneous structural steel including platforms, stairs, ladders; panels, racks, cabinets, and other enclosures for electrical equipment and instrumentation; penetration seals;penetration sleeves including end caps; roofing; structural sealants, seismic gap seals, gaskets, flashing and other sealants and gap seals; and tube track. In addition, mechanical and electrical systems and components housed in or located within the Turbine Building are evaluated with their respective mechanical and electrical license renewal system or commodity group.For more detailed information, see UFSAR Sections 3.3.2.3, 3.4.1.3, 3.4.1.4, and 3.8.5.1.1.
Reason for Scope Determination The Turbine Building is not in scope under 10 CFR 54.4(a)(1) because no portions of the structure are safety-related and relied upon to remain functional during and following design basis events. The Turbine Building meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Turbine Building also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63).The Turbine Building is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provides structural support or restraint to SSCs in the scope of license renewal. 10 CFR 54.4(a)(2)
: 2. Provides physical support, shelter, and protection for nonsafety-related systems, structures, and components whose failure could prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
10 CFR 54.4(a)(2)
: 3. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates LaSalle County Station, Units I and 2 License Renewal Application Page 2.4-60 Section 2 -Scoping and Screening Methodology and Results compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
: 4. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49).10 CFR 54.4(a)(3)
: 5. Provides physical support, shelter, and protection for systems structures and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). 10 CFR 54.4(a)(3)
UFSAR References 1.1 1.2.2.2.c 2.4.12 Figure 2.5-51 Table 3.2-1 3.3.2.3 3.4.1.3 3.8.5.1.1 7.7.11.2.2 9.4.4.2.f 11.2.1.8 12.3.1.6.1 12.3.2.3 Appendix J; J.4 License Renewal Boundary Drawings LR-M-3 Table 2.4-13 Turbine Building Components Subject to Aging Management Review Component Type Intended Function Blowout Panels Pressure Relief Bolting (Structural)
Structural Support Concrete Anchors Structural Support Concrete Curbs Flood Barrier Concrete Embedments Structural Support Concrete:
Above-grade Exterior Flood Barrier (accessible areas) Shelter, Protection Structural Support Concrete:
Above-grade Exterior Flood Barrier (inaccessible areas) Shelter, Protection Structural Support LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-61 Section 2 -Scoping and Screening Methodology and Results Component Type Intended Function Concrete:
Below-grade Exterior Flood Barrier (inaccessible areas) Shelter, Protection Structural Support Concrete:
Foundation, Subfoundation Flood Barrier (inaccessible areas) Shelter, Protection Structural Support Concrete:
Interior Flood Barrier Shelter, Protection Shielding Structural Support Equipment Supports and Foundations Structural Support Hatches/Plugs Shelter, Protection Shielding Structural Support Masonry Walls: Above-grade Exterior Shelter, Protection Shielding Structural Support Masonry Walls: Interior Shelter, Protection Shielding Structural Support Metal Decking Shelter, Protection Structural Support Metal Siding Pressure Relief Shelter, Protection Pipe Whip Restraints Pipe Whip Restraint Steel Components:
Structural Steel Structural Support Steel Elements:
Liner, Liner Anchors, Water Retaining Boundary Integral Attachments (Sump Liner)The aging management review results for these components are provided in: Table 3.5.2-13 Turbine Building Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-62 Section 2 -Scoping and Screening Methodology and Results 2.4.14 Yard Structures Description Yard Structures include transformer foundations, trenches, light poles, transmission towers, fire hose storage foundations, manholes, valve pits, duct banks, yard drainage, miscellaneous yard structures, and the meteorological tower.Transformer foundations:
The transformer foundations consist of reinforced concrete slabs which are located north and south of the power block. The transformer foundations are supported by compacted soil fill.The system auxiliary transformers are used to supply safety-related equipment during normal and emergency plant operating conditions, and they provide power to equipment relied upon for post fire safe shutdown and for recovery from station blackout.
These transformer foundations are therefore in scope for license renewal.Manholes, Handholes, Valve Pits and Duct Banks: Manholes, handholes and valve pits consist of reinforced concrete structures buried underground with a reinforced concrete roof. These structures have a removable opening cover to allow for plant personnel access. Manholes, handholes, and valve pits serve as intermediate access point(s) for electrical, telephone or control cables and lines routed in the yard area and for access to valves for buried piping. The manholes, handholes and valve pits located in the yard area are nonsafety-related.
The handholes and valve pits do not perform an intended function and are therefore, not in scope for license renewal. The four electrical manholes that contain power cables for the service water pumps and for the MCC that feeds fire pumps and associated equipment in the Lake Screen House are in scope for license renewal.Duct banks are comprised of multiple conduits containing electrical cables in an excavated trench in the yard that are encased in concrete and then backfilled with soil. The duct banks are used to route nonsafety-related cables between structures and within the switchyard areas. The duct banks that contain power cables for the service water pumps and for the MCC supplying fire pumps and equipment located in the Lake Screen House are in scope for license renewal.Light Poles: Light poles are metal poles that are mounted on concrete foundations located in the yard area.The light poles provide area lighting and are nonsafety-related.
Light poles do not perform an intended function and are therefore, not in scope for license renewal.Transmission Towers: Transmission towers which include take-off towers, are metal structures supported by reinforced concrete foundations located in the yard. The transmission towers provide support for transmission conductors which connect LSCS to the switchyard and from the switchyard to offsite substations.
Transmission towers provide essential power for normal plant, emergency operations, equipment relied upon for post fire safe shutdown, and for recovery from station LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-63 Section 2 -Scoping and Screening Methodology and Results blackout.
The transmission towers and take-off towers associated with the system auxiliary transformers and their foundations are in scope for license renewal.Fire Hose Storage foundations:
The fire hydrant hose storage foundation pads are reinforced concrete pads on grade and provide level support for the storage of outdoor fire hose and firefighting equipment.
These foundations are located around the perimeter of the power block and at various other locations within the yard area. The fire hose storage foundation pads do not perform an intended function and are therefore, not in scope of license renewal.Site Drainage System: The site drainage system includes drainage ditches, culverts and storm sewer system consisting of inlets and manholes.
The ditches, culverts and storm sewer drainage systems are comprised of buried corrugated metal pipe or reinforced concrete pipe. It also contains at grade reinforced concrete manholes or catch basins and oil interceptor pits and tanks. The storm water inlets are typically covered with grating to allow inflow of storm water. The oil interceptor tanks within the oil interceptor pits are used to separate oily waste from waste water prior to discharge.
The underground storm and waste drainage system is not relied upon to prevent flooding at the plant. The site drainage system does not perform an intended function and is therefore, not in scope for license renewal.Miscellaneous Yard Structures:
Miscellaneous yard structures are comprised of civil features located in the yard area that are not uniquely tied to any structure.
These miscellaneous yard structures include roadways, sidewalks, and bollards and may include small storage structures.
The miscellaneous yard structures also include the Independent spent fuel storage installation (ISFSI), gas bottle storage facility, hydrogen tank storage area, and miscellaneous small storage structures.
These miscellaneous yard structures are nonsafety-related and separated from safety-related systems, structures, and components such that their failure would not impact a safety-related function.
These miscellaneous yard structures do not perform an intended function and are therefore, not in scope for license renewal.The independent spent fuel storage installation (ISFSI) contains the spent fuel storage casks supported on a reinforced concrete pad. The ISFSI is located in the northeast corner of the protected area. The structure is separated from safety-related systems, structures, and components such that its failure would not impact a safety-related function.
The ISFSI is separately licensed and is therefore, not in scope for license renewal.The gas bottle storage facility contains portable gas bottles used at LaSalle in an aboveground segregated walled structure with a steel roof. The gas bottle storage facility is located north of the power block within the protected area. The structure is separated from safety-related systems, structures, and components such that its failure would not impact safety-related function and is therefore, not in scope for license renewal.The hydrogen storage area consists of concrete pad installed over granular fill supporting the hydrogen tank, nitrogen tanks and tube trailers.
The hydrogen storage area is located west of the power block and within the protected area. The structure is separated from safety-related LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-64 Section 2 -Scoping and Screening Methodology and Results systems, structures, and components such that its failure would not impact a safety-related function and is therefore, not in scope for license renewal.Meteorological Tower: The meteorological tower includes the adjacent equipment building.
The tower is located southwest of the power block and is approximately 400 feet tall. The meteorological tower consists of a guy wire supported steel tower founded on a concrete foundation.
The equipment enclosure is a commercial grade metal enclosure on a concrete foundation.
The purpose of the meteorological tower is to provide support, shelter, and protection for the meteorological instrumentation which is utilized to obtain data for both Unit 1 and Unit 2. The meteorological tower is nonsafety-related and separated from safety-related systems, structures, and components such that its failure would not impact a safety-related function.The meteorological tower does not perform an intended function for license renewal and is therefore, not in the scope of license renewal.The purpose of the Yard Structures is to provide structural support, shelter, and protection for nonsafety-related components and commodities including components which supply power to safety-related equipment during emergency plant operating conditions, and power to equipment relied upon for post fire safe shutdown or recovery from station blackout.
The yard drainage system provides for collection and routing of ground water away from the power block.Included in the boundary of the Yard Structures are trenches, light poles, fire hose house foundations, manholes, handholes valve pits, duct banks, transformer foundations, transmission towers, miscellaneous yard structures, meteorological tower, and the yard drainage system. Included within the boundary of Yard Structures and determined to be in scope are bolting, concrete anchors, electrical manholes and duct banks, concrete foundations (system auxiliary transformer foundations and associated transmission and takeoff tower foundations), and steel components (transmission and takeoff towers). The components included in scope are reinforced concrete foundations, concrete anchor bolts, and tower steel.Other structures and components within the Yard Structures evaluation boundary do not perform a license renewal intended function and are not in scope for license renewal.Refer to "Components Subject to Aging Management Review" table for a complete list of components included in the boundary of the Yard Structures.
Not included in the boundary of the Yard Structures are component supports, tanks, tank foundations and dikes, piping and component insulation, security structures, fire protection, miscellaneous not in scope structures, buried piping and piping components, switchyard.
Component supports, including their respective bolting, are evaluated with the Component Supports Commodity Group. Structural commodities, including their respective bolting, are evaluated with the Structural Commodity Group. In addition, mechanical and electrical systems and components housed in or located in the Yard Facility are evaluated with their respective mechanical and electrical license renewal system or component groups. The tanks and foundations are evaluated within the Tank Foundations and Dikes structure group.Miscellaneous structures are evaluated within the Miscellaneous Not in Scope Structures group. The fire protection components are evaluated separately within the Fire Protection System. Buried piping and piping components in valve pits are evaluated with their respective mechanical systems. The components in the 345-kV switchyard and certain transmission LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-65 Section 2 -Scoping and Screening Methodology and Results towers are evaluated with the Switchyard Structures license renewal scoping and screening package.For more detailed information, see UFSAR Sections 1.2.3.6.1, 2.4.2.4, 2.4.4, 3.1.2.6.2.2, Table 3.2-1, 8.2, 9.1.2.3, 9.5.1.2.1, and 9.5.3.2.1.
Reason for Scope Determination The Yard Structures is not in scope under 10 CFR 54.4(a)(1) because no portions of the structures are safety-related or relied upon to remain functional during and following design basis events. The Yard Structures is not in scope under 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure would not prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Yard Structures also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48) and Station Blackout (10 CFR 50.63). The Yard Structures is not relied upon in any safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49) and Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions 1. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR 54.4(a)(3)
: 2. Provides physical support, shelter, and protection for systems, structures, and components relied upon in safety analysis or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Station Blackout (10 CFR 50.63). 10 CFR 54.4(a)(3)
UFSAR References 1.2.3.6.1 2.4.2.4 2.4.4 3.1.2.6.2.2 Table 3.2-1 8.2 Table 8.3-5 9.1.2.3 9.1.4.2.2 9.5.1.2.1 9.5.3.2.1 License Renewal Boundary Drawings LR-M-3 LaSalle County Station, Units 1 and 2 Page 2.4-66 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Table 2.4-14 Yard Structures Components Subject to Aging Management Review Component Type Intended Function Bolting (Structural)
Structural Support Concrete Anchors Structural Support Concrete:
Foundation, Subfoundation Structural Support (accessible areas -Transformers, Transmission and Take Off Towers)Concrete:
Foundation, Subfoundation Structural Support (inaccessible areas -Transformers, Transmission and Take Off Towers)Manholes, Handholes, and Duct Banks Shelter, Protection Structural Support Transmission Towers (includes Take Off Structural Support Towers)The aging management review results for these components are provided in: Table 3.5.2-14 Yard Structures Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 License Renewal Application Page 2.4-67 This Page Intentionally Left Blank Section 2 -Scoping and Screening Methodology and Results 2.5 SCOPING AND SCREENING RESULTS: ELECTRICAL The determination of electrical systems that fall within the scope of license renewal is made through the application of the process described in Section 2.1. The results of the electrical systems scoping review are contained in Section 2.2.Subsection 2.1.6.1 provides the screening methodology for determining which electrical components and commodity groups within the scope of 10 CFR 54.4 meet the requirements contained in 10 CFR 54.21 (a)(1). The electrical commodity groups that meet those screening requirements are identified in this section. These identified electrical commodity groups consequently require an aging management review.As described in Subsection 2.1.6.1, the screening was performed on a commodity group basis for the in scope electrical and I&C systems as well as the electrical and I&C component types associated with in scope mechanical systems listed in Table 2.2-1.Components which support or interface with electrical and I&C components, for example, cable trays, conduits, instrument racks, panels and enclosures, are assessed as part of the Component Supports Commodity Group in Section 2.4.2.2.5.1 ELECTRICAL SYSTEMS The results of the electrical system scoping review are contained in Section 2.2. Additional system details are included in the UFSAR Sections 7 and 8. In addition to the electrical and I&C systems and components, certain switchyard components are credited to restore offsite power following a station blackout (SBO). The boundary for offsite power restoration following an SBO is shown in a simplified diagram in Figure 2.1-2.2.5.2 ELECTRICAL COMMODITIES 2.5.2.1 Identification of Electrical Commodities The first step of the screening process for electrical commodities is to use plant documentation to identify the electrical components and commodities within the electrical, I&C and mechanical systems based on plant design documentation, drawings, and the Passport equipment database, as well as by interfacing with the parallel mechanical and civil screening efforts. The electrical components and commodities identified at LSCS are listed below. This list includes electrical components and commodities identified in NEI 95-10 Appendix B in addition to components and commodities added per NUREG-1 800 Table 2.1-5.LaSalle County Station, Units 1 and 2 2.5-1 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Electrical Components and Commodities for In Scope Systems:-Alarm Units-Analyzers-Annunciators
-Batteries-Cable Connections (Metallic Parts)-Cable Tie Wraps-Chargers-Circuit Breakers-Communication Equipment-Converters
-Electric Heaters-Electrical Controls and Panel Internal Assemblies
-Electrical Penetrations
-Elements, RTDs, Sensors, Thermocouples, Transducers
-Fuse Holders-Fuses-Generators, Motors-Heat Trace-High Voltage Insulators
-Indicators
-Insulated Cables and Connections
-Inverters-Isolators-Light Bulbs-Loop Controllers
-Metal Enclosed Bus-Meters-Motor Generator Sets-Power Supplies-Radiation Monitors-Recorders-Regulators
-Relays-Signal Conditioners
-Solenoid Operators-Solid State Devices-Splices-Surge Arresters-Switches-Switchgear, Load Centers, Motor Control Centers, Distribution Panels-Switchyard Bus and Connections
-Terminal Blocks-Transformers
-Transmission Conductors
-Transmission Connectors
-Transmitters
-Uninsulated Ground Conductors LaSalle County Station, Units 1 and 2 2.5-2 License Renewal Application Section 2 -Scoping and Screening Methodology and Results 2.5.2.2 Application of Screening Criterion 10 CFR 54.21 (a)(1)(i) to the Electrical Components and Commodities Following the identification of the electrical components and commodities, the criteria of 10 CFR 54.21 (a)(1)(i) were applied to identify components and commodities that perform their functions without moving parts or without a change in configuration or properties.
The following electrical commodities were determined to meet the screening criteria of 10 CFR 54.21 (a)(1)(i):
-Cable Connections (Metallic Parts)-Cable Tie Wraps-Electrical Penetrations
-Fuse Holders-High Voltage Insulators
-Insulated Cables and Connections
-Metal Enclosed Bus-Splices-Switchyard Bus and Connections
-Terminal Blocks-Transmission Conductors
-Transmission Connectors
-Uninsulated Ground Conductors 2.5.2.3 Elimination of Electrical Commodity Groups With No License Renewal Intended* Functions The following electrical commodities were determined to not have a license renewal intended function: Cable Tie Wraps Tie wraps are used in cable installations as cable ties. Cable ties hold groups of cables together for restraint and ease of maintenance.
Cable ties are used to bundle wires and cables together to keep the wire and cable runs neat and orderly. Cable ties are used to restrain wires and cables within raceways to facilitate cable installation.
There are no current license basis requirements for LSCS that cable tie wraps remain functional during and following design basis events. Cable ties are not credited for maintaining cable ampacity, ensuring maintenance of cable minimum bending radius, or maintaining cables within vertical raceways at LSCS. The seismic qualification of cable trays does not credit the use of cable ties. Cable tie wraps are not credited in the LSCS design basis in terms of any 10 CFR 54.4 intended function.
Therefore, cable tie wraps are not within the scope of license renewal and therefore, are not subject to aging management review.Fuse Holders (Not Part of Active Equipment):
Metallic Clamps The fuse holder commodity includes both the insulation portion of the fuse holder and the metallic clamp portion of the fuse holder. The insulation portion of the fuse holders was scoped as part of the insulation material for electrical cables and connections commodity.
The metallic clamp portion of the fuse holders was scoped as a Fuse Holders (Not Part of Active Equipment):
Metallic Clamps commodity.
A systematic review was performed to LaSalle County Station, Units 1 and 2 2.5-3 License Renewal Application Section 2 -Scoping and Screening Methodology and Results determine if there were metallic clamp portions of fuse holders that were in scope for LSCS license renewal. The review used plant documents, controlled drawings, and the plant equipment database to identify individual Fuse Holders (Not Part of Active Equipment):
Metallic Clamps. A comprehensive fuse holder list was assembled.
A scoping determination was made considering if the fuse holder:* was installed in active equipment, or" performed a license renewal intended function.The review determined that LSCS Fuse Holders (not part of active equipment):
Metallic Clamps were either installed in active equipment, or did not perform a license renewal intended function.
Therefore, there are no LSCS Fuse Holders (not part of active equipment):
Metallic Clamps in scope for LSCS license renewal and therefore, are not subject to aging management review.Uninsulated Ground Conductors The uninsulated ground conductor commodity is comprised of grounding cable and associated connectors.
Ground conductors are provided for equipment and personnel protection.
They do not perform an intended function for license renewal. Therefore, uninsulated ground conductors are not within the scope of license renewal and therefore, are not subject to aging management review.2.5.2.4 Application of Screening Criteria 10 CFR 54.21 (a)(1)(ii) to Electrical Commodities The 10 CFR 54.21 (a)(1)(ii) screening criterion was applied to the specific commodities that remained following application of the 10 CFR 54.21 (a)(1)(i) criterion.
10 CFR 54.21 (a)(1)(ii) allows the exclusion of those commodities that are subject to replacement based on a qualified life or specified time period. The only electrical commodities identified for exclusion by the criteria of 10 CFR 54.21 (a)(1)(ii) are electrical and I&C components and commodities included in the Environmental Qualification (EQ) Program. This is because electrical and I&C components and commodities included in the EQ Program have defined qualified lives and are replaced prior to the expiration of their qualified lives. No electrical and I&C components and commodities within the EQ Program are subject to aging management review in accordance with the screening criteria of 10 CFR 54.21 (a)(1)(ii).
See Section 4.4 for the TLAA evaluation of the Environmental Qualification (EQ) of Electric Components program. The remaining commodities, all or part of which are not in the EQ Program, require aging management review and are discussed below.LaSalle County Station, Units 1 and 2 2.5-4 License Renewal Application Section 2 -Scoping and Screening Methodology and Results O 2.5.2.5 Electrical Commodities Subject to Aging Management Review The electrical commodities subject to aging management review are identified in Table 2.5.2-1, along with the associated intended functions.
These electrical commodities are further described below.2.5.2.5.1 Cable Connections (Metallic Parts)The Cable Connectors (Metallic Parts) commodity includes metallic portions of cable connections that are not included in the EQ Program. The metallic connections evaluated include splices, threaded connectors, compression type termination lugs, and terminal blocks.Therefore, Cable Connections (Metallic Parts) meet the screening criterion of 10 CFR 54.21(a)(1)(ii) and are subject to aging management review.2.5.2.5.2 Electrical Penetrations Electrical penetrations at LSCS are environmentally qualified.
They are evaluated as a time-limited aging analysis, Section 2.5.2.4, and ultimately managed by the Environmental Qualification (EQ) of Electric Components (B.3.1.3) program. The electrical continuity of electrical penetration pigtails that could potentially be exposed to an adverse localized environment is included in the evaluation for Insulation Material for Electrical Cables and Connections, Section 2.5.2.5.4.
The shelter, protection and pressure boundary intended functions of electrical penetrations are included in the evaluation for Primary Containment, Section 2.4.7..2.5.2.5.3 High Voltage Insulators The High Voltage Insulators provide physical support for Switchyard Bus, Transmission Conductors, and switchyard active components that are part of the circuits that supply power from the electric utility transmission system to plant buses. These circuits provide power to in scope license renewal components used for recovery from a station blackout event. High Voltage Insulators are not included in the EQ program. Therefore, High Voltage Insulators meet the screening criterion of 10 CFR 54.21 (a)(1)(ii) and are subject to an aging management review.2.5.2.5.4 Insulation Material for Electrical Cables and Connections The insulated cables and connections commodities are separated for aging management review into subcategories based on their treatment in NUREG-1 801: Insulation Material for Electrical Cables and Connections Insulation Material for Electrical Cables and Connections Used in Instrumentation Circuits Conductor Insulation for Inaccessible Power Cables Greater Than or Equal to 400 Volts.Insulated cables and connections included in this review are:-Electrical Penetration Pigtails-Splices-Terminal Blocks* InsulatingPortions of Fuse Holders.LaSalle County Station, Units 1 and 2 2.5-5 License Renewal Application Section 2 -Scoping and Screening Methodology and Results Numerous insulated cables and connections are included in the EQ Program and, therefore, are not subject to an aging management review in accordance with the screening criteria of 10 CFR 54.21 (a)(1)(ii).
Insulated cables and connections not included in the EQ Program meet the criterion of 10 CFR 54.21 (a)(1)(ii) and are subject to an aging management review.Insulated cables and connections inside the enclosure of an active device (e.g., motor leads and connections, cables and connections internal to relays, chargers, switchgear, transformers, power supplies) are maintained along with the other subcomponents inside the enclosure and are not subject to an aging management review.2.5.2.5.5 Metal Enclosed Bus The metal enclosed buses distribute 4 kV power from the safeguard transformers and the emergency diesel generators to the 4 kV Class 1 E switchgear utilizing non-segregated bus work. The metal enclosed buses also provide crossties between units. These portions of the power distribution system are in the scope of license renewal. The metal enclosed buses distribute electrical power to safety-related 4 kV switchgear during recovery from a station blackout event. The metal enclosed buses are not in the EQ Program. Therefore, metal enclosed bus meets the screening criterion of 10 CFR 54.21 (a)(1)(ii) and is subject to aging management review.2.5.2.5.6 Switchyard Bus and Connections, Transmission Conductors, and Transmission Connectors The Switchyard Bus and Connections are part of the switchyard circuits that supply power from the utility transmission system to plant buses. These circuits provide power to in scope license renewal components used for recovery from a station blackout.
The Switchyard Bus and Connections are not included in the EQ program. Therefore, Switchyard Bus and Connections meet the screening criterion of 10 CFR 54.21 (a)(1)(ii) and are subject to an aging management review.The Transmission Conductors and Connectors are part of the switchyard circuits that supply power from the electric transmission system to plant buses. These circuits provide power to in scope license renewal components used for recovery from a station blackout.
The Transmission Conductors and Connectors are not included in the EQ program. Therefore, Transmission Conductors and Connectors meet the screening criterion of 10 CFR 54.21 (a)(1)(ii) and are subject to an aging management review.LaSalle County Station, Units 1 and 2 2.5-6 License Renewal Application Section 2 -Scoping and Screening Methodology and Results.Table 2.5.2-1 Electrical Commodities Subject to Aging Management Review Commodity Intended Function Cable Connections (Metallic Parts) Electrical Continuity High Voltage Insulators Insulate (Electrical)
Insulation Material for Electrical Cables Insulate (Electrical) and Connections Metal Enclosed Bus Electrical Continuity Insulate (Electrical)
Shelter, Protection Switchyard Bus and Connections, Electrical Continuity Transmission Conductors, and Transmission Connectors The aging management review results for these commodities are provided in Table 3.6.2-1 Electrical Commodities
-Summary of Aging Management Evaluation.
LaSalle County Station, Units 1 and 2 License Renewal Application 2.5-7 This Page Intentionally Left Blank Section 3 -Aging Management Review Results 3.0 AGING MANAGEMENT REVIEW RESULTS This section provides the results of the aging management review for those structures and components identified in Section 2.0 as being subject to aging management review.Descriptions of the service environments that were used in the aging management review to determine aging effects requiring management are included in Table 3.0-1, LaSalle Service Environments.
The environments used in the aging management reviews are listed in the LaSalle AMR Environment column. The third column identifies one or more of the NUREG-1 801 environments that were used when comparing the LaSalle Aging Management Review results to the NUREG-1801 results.Most of the Aging Management Review (AMR) results information in Section 3 is presented in the following two tables:* Table 3.x.1 -where '3' indicates the LRA section number, 'x' indicates the subsection number from NUREG-1 800, and '1' indicates that this is the first table type in Section 3. For example, in the Reactor Vessel, Internals, and Reactor Coolant System subsection, this table would be number 3.1.1; in the Engineered Safety Features subsection, this table would be 3.2.1; and so on. For ease of discussion, this table will hereafter be referred to in this Section as "Table 1."* Table 3.x.2-y -where '3' indicates the LRA section number, 'x' indicates the subsection number from NUREG-1 800, and '2' indicates that this is the second table type in Section 3; and 'y' indicates the table number for a specific system. For example, for the Reactor Vessel, within the Reactor Vessel, Internals, and Reactor Coolant System subsection, this table would be 3.1.2-2 and for the Reactor Vessel Internals, it would be table 3.1.2-3. For the High Pressure Core Spray System, within the Engineered Safety Features (ESF) subsection, this table would be 3.2.2-1.For the next system within the ESF subsection, it would be table 3.2.2-2. For ease of discussion, this table will hereafter be referred to in this section as "Table 2." TABLE DESCRIPTION NUREG-1 801, "Generic Aging Lessons Learned (GALL) Report," contains the generic evaluation of existing plant programs.
It documents the technical basis for determining where existing programs are adequate without modification, and where existing programs should be augmented for the extended period of operation.
The evaluation results documented in NUREG-1 801 indicate that many of the existing programs are adequate to manage the aging effects for particular structures or components, within the scope of license renewal, without change. NUREG-1801 also contains recommendations on specific areas for which existing programs should be augmented for license renewal. In order to take full advantage of NUREG-1 801, a comparison between the LSCS AMR results and the tables of NUREG-1 801 has been performed.
The results of that comparison are provided in Table 1 and Table 2.Table I The purpose of Table 1 is to provide a summary comparison of how the facility aligns with the corresponding tables of NUREG-1800.
The table is essentially the same as LaSalle County Station, Units 1 and 2 Page 3.0-1 License Renewal Application Section 3 -Aging Management Review Results Tables 3.1-1 through 3.6-1 provided in NUREG-1800, except that the "ID" and "Type" columns have been replaced by an "Item Number" column and the "Rev2 Item" and 0"Revl Item" columns have been replaced by a "Discussion" column.The "Item Number" column provides the reviewer with a means to cross-reference from Table 2 to Table 1.The "Discussion" column is used to provide clarifying or amplifying information.
The following are examples of information that might be contained within this column: " "Further Evaluation Recommended" information or reference to where that information is located" The name of a plant-specific aging management program being used, if applicable" Exceptions to the NUREG-1 800 assumptions, if applicable
* A discussion of how the line is consistent with the corresponding line item in NUREG-1 800, when that may not be intuitively obvious" A discussion of how the item is different than the corresponding line item in NUREG-1800 when it may appear to be consistent (e.g., when there is exception taken to an aging management program that is listed in NUREG-1800), if applicable The format of Table 1 provides the reviewer with a means of aligning a specific Table 1 row with the corresponding NUREG-1 800 table row, thereby allowing for the ease of checking consistency.
Table 2 Table 2 provides the detailed results of the aging management reviews for those components identified in LRA Section 2 as being subject to aging management review.There will be a Table 2 for each of the systems within a Chapter 3 Section grouping.
For example, for LaSalle, the Engineered Safety Features System Group contains table's specific to the High Pressure Core Spray (HPCS) System, Low Pressure Core Spray (LPCS) System, Reactor Core Isolation Cooling (RCIC) System, Residual Heat Removal (RHR) System, and Standby Gas Treatment (SGT) System.Table 2 consists of the following nine columns:* Component Type" Intended Function" Material* Environment
* Aging Effect Requiring Management
* Aging Management Programs* NUREG-1801 Item* Table 1 Item LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.0-2 Section 3 -Aging Management Review Results* Notes Component Type -The first column identifies all of the component types from Section 2 of the LRA that are subject to aging management review. They are listed in alphabetical order.Intended Function -The second column contains the license renewal intended functions for the listed component types. Definitions of intended functions are contained in Table 2.1-1.Material -The third column lists the particular materials of construction for the component type.Environment
-The fourth column lists the environments to which the component types are exposed. Service environments are indicated and a list of these environments is provided in Table 3.0-1.Aging Effect Requiring Management
-As part of the aging management review process, the aging effects that are required to be managed in order to maintain the intended function of the component type are identified for the material and environment combination.
These aging effects requiring management are listed in the fifth column.Aging Management Programs -The aging management programs used to manage the aging effects requiring management are listed in the sixth column of Table 2. Aging management programs are described in Appendix B.NUREG-1801 Item -Each combination of component type, material, environment, aging effect requiring management, and aging management program that is listed in Table 2, is compared to NUREG-1801, with consideration given to the standard notes, to identify consistency.
Consistency is documented by noting the appropriate NUREG-1801 item number in the seventh column of Table 2. If there is no corresponding item number in NUREG-1 801, this field in column seven is left blank. Thus, a reviewer can readily identify the correlation between the plant-specific tables and the NUREG-1 801 tables.Table 1 Item -Each combination of component, material, environment, aging effect requiring management, and aging management program that has an identified NUREG-1801 item number must also have a Table 3.x.1 line item reference number. The corresponding line item from Table 1 is listed in the eighth column of Table 2. If there is no corresponding item in NUREG-1 801, this field in column eight is left blank. The Table 1 Item allows correlation of the information from the two tables.Notes -The notes provided in each Table 2 describe how the information in the table aligns with the information in NUREG-1 801. Each Table 2 contains standard lettered notes and, if applicable, plant-specific numbered notes.The standard lettered notes (e.g., A, B, C) provide standard information regarding comparison of the LaSalle aging management review results with the NUREG-1 801 Aging Management Table line item identified in the seventh column. In addition to the standard lettered notes, numbered plant-specific notes provide additional clarifying information when appropriate.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.0-3 Section 3 -Aging Management Review Results TABLE USAGE Table 1 The reviewer evaluates each row in Table 1 by moving from left to right across the table.Since the Component, Aging Effect, Aging Management Programs and Further Evaluation Recommended information is taken directly from NUREG-1800, no further analysis of those columns is required.
The information intended to help the reviewer the most in this table is contained within the Discussion column. Here the reviewer will be given plant-specific information necessary to determine, in summary, how the LaSalle evaluations and programs align with NUREG-1800.
This may be in the form of descriptive information within the Discussion column, or the reviewer may be referred to other locations within the LRA for further information.
Table 2 Table 2 contains all of the Aging Management Review information for the plant, whether or not it aligns with NUREG-1 801. For a given row within the table, the reviewer is able to see the intended function, material, environment, aging effect requiring management and aging management program combination for a particular component type within a system. In addition, if there is a correlation between the combination in Table 2 and a combination in NUREG-1801, this will be identified by a referenced item number in column seven, NUREG-1 801 Item. The reviewer can refer to the item number in NUREG-1 801, if desired, to verify the correlation.
If the column is blank, no corresponding combination in NUREG-1 801 was found. As the reviewer continues across the table from left to right, within a given row, the next column is labeled Table 1 Item. If there is a reference number in this column, the reviewer is able to use that reference number to locate the corresponding row in Table 1 and see how the aging management program for this particular combination aligns with NUREG-1801.
Table 2 provides the reviewer with a means to navigate from the components subject to Aging Management Review (AMR) in LRA Section 2 all the way through the evaluation of the programs that will be used to manage the effects of aging of those components.
A listing of the acronyms used in this section is provided in Section 1.6.Cumulative Fatigue Damage and TLAAs in Table 2 A fatigue analysis is considered to be a time-limited aging analysis (TLAA) as defined in 10 CFR 54.3 when it is within the current licensing basis and is based upon transient cycle assumptions associated with 40 years of plant operation.
TLAAs are required to be evaluated in accordance with 10 CFR 54.21 (c)(1).Table 1 and Table 2 include an entry in the Aging Management Program column indicating "TLAA" for each line item that has a component for which a fatigue TLAA has been identified.
See LRA Section 4.3 for details regarding the LSCS fatigue design bases, fatigue TLAAs identified, and TLAA evaluations for the period of extended operation.
LaSalle County Station, Units 1 and 2 Page 3.0-4 License Renewal Application Section 3 -Aging Management Review Results Table 3.0-1 -LaSalle Service Environments LaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Adverse The Adverse Localized Environment represents Adverse localized environment Localized conditions with excessive heat, radiation, caused by heat, radiation, or Environment moisture, or voltage, sometimes in the presence moisture of oxygen. The effect can be concentrated or Adverse localized environment applicable to a general plant area. caused by heat, radiation, oxygen, moisture, or voltage Adverse localized environment caused by significant moisture Air -Indoor, The Air -Indoor, Controlled environment is one Air -indoor, controlled or Controlled in which the specified internal or external surface Uncontrolled of the component or structure is exposed to a Air -indoor, controlled or humidity-controlled (i.e., air conditioned)
Airo-tindoorrcontroloed dor environment.
For electrical purposes, control must be sufficient to eliminate the cited aging effects of contamination and oxidation without affecting the resistance.
Air -Indoor, The Air -Indoor Uncontrolled environment is for Air Uncontrolled indoor locations that are sheltered or protected from weather. It is associated with systems with Air -indoor, uncontrolled temperatures higher than the dew point (i.e. Air -indoor, uncontrolled or Air -condensation can occur, but only rarely); outdoor equipment and surfaces are normally dry. Air -indoor, uncontrolled or Air -outdoor or Ground water/soil System temperature up to 288&deg;C (550&deg;F)Any environment Various LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.0-5 Section 3 -Aging Management Review Results LaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Air -Outdoor The Air -Outdoor environment includes Air -outdoor atmospheric air with ambient temperatures and a Air -indoor, uncontrolled or Air -relative humidity up to 100%. This environment outdoor may be subject to periodic wetting and wind.The Air-Outdoor (External) environment is Air -indoor, uncontrolled or Air -considered bounding for situations where piping outdoor or Ground water/soil and components are located in below grade Air -indoor, uncontrolled or Air -enclosed vaults, tunnels or pits. outdoor or Water -flowing or standing Condensation, air-outdoor Soil or Concrete, or the following external environments:
air-outdoor, air-indoor uncontrolled, Any environment Various Air with Reactor The Air with Reactor Coolant Leakage Air with reactor coolant leakage Coolant Leakage environment is applicable to closure bolting only Air which is located in the vicinity of the RPV. The Air with reactor coolant or steam leakage Air with steam or water leakage environment is a high temperature leakage System temperature up to 288 0 C environment.
(5500F Air/Gas-Dry The Air/Gas-Dry environment includes air with a Air -dry very limited percentage of moisture present that has been treated to reduce the dewpoint well below the system operating temperature.
This includes air within air-conditioned spaces and it also includes commercial grade gases (such as nitrogen, freon, etc.) that are provided as a high quality product with little if any external contaminants (bottled gas).This environment does not include air within piping systems downstream of dryers because these dryers require a program to assure they remain functional.
For these systems, the Condensation environment is used.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.0-6 Section 3 -Aging Management Review Results LaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Closed Cycle Closed Cycle Cooling Water includes treated Closed-cycle cooling water Cooling Water water subject to the Closed Treated Water Systems program, which is Aging Management Program XI.M21A in NUREG-1801.
The Closed Treated Water Systems program relies on maintenance of system corrosion inhibitor concentrations within specified limits of Electric Power Research Institute TR-107396 and Technical Report 1007820 to minimize corrosion.
Demineralized water is treated with corrosion inhibitors, pH control agents, or biocides, as needed.Closed Cycle The Closed Cycle Cooling Water >140&deg;F Closed-cycle cooling water Cooling Water environment is the same as the Closed Cycle>140&deg;F Cooling Water environment, except the Closed Closed-cycle cooling water >60&deg;C Cycle Cooling Water >140&deg;F environment is (>140 0 F)used for components with an operating temperature
>140&deg;F that are constructed of stainless steel.Concrete The Concrete environment is one where Concrete components are embedded in concrete.
This Soil or concrete environment is considered aggressive if the concrete pH <11.5 or chlorides concentration
>500 ppm.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.0-7 Section 3 -Aging Management Review Results LaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Condensation The Condensation environment is an air Condensation environment containing warm or moist air where condensation may occur and periodically wet the Condensation, air-outdoor component surface. This environment includes Moist air or condensation air with enough moisture to facilitate loss of Air-indoor controlled, air-indoor material caused by pitting and crevice corrosion uncontrolled, air-outdoor, moist for most common materials.
Although air condensation, raw water, condensation may occur, it is not expected to be ated water significant enough to result in ponding and treated water pooling that can pose a spatial interaction Soil or Concrete, or the following concern. Ponding and pooling to this degree, as external environments:
air-would expected to be found in HVAC drip pans outdoor, air-indoor uncontrolled, and drains lines, is considered Waste Water.The condensation air environment is used for air drawn inside ventilation systems and air spaces within tanks. Certain components reside inside larger components such that their external surfaces are exposed to the internal environment of the larger component (e.g., tubes in air coolers).
For these situations, Condensation is designated as the external environment.
The Condensation environment is also used for certain insulated components.
Because of air in-leakage through minor gaps in insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dew point of the air on the external surfaces of the insulation.
Diesel Exhaust The Diesel Exhaust environment represents the Diesel Exhaust exhaust from diesel engines. It is considered to have the potential to concentrate contaminants and be subject to wetting through condensation.
Encased in Steel Concrete encased in steel is protected from Environment not addressed in environments that promote age-related NUREG-1801 degradation.
Concrete which is totally enclosed and contained within the inner, outer, sleeve, and cover steel plates of the Reactor Shield is an example of where the "encased in steel" environment is applied. The concrete which is encased in steel is protected from other environments that promote age-related degradation.
S LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.0-8 Section 3 -Aging Management Review Results LaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Fuel Oil The Fuel Oil environment includes fuel oil for the Fuel oil emergency diesel generators, diesel-driven auxiliary feedwater pumps, diesel-driven fire pumps, etc. Water contamination of fuel oil is assumed.Groundwater/Soil The Groundwater/Soil environment is the Ground water/soil external environment for structural components Air -indoor, uncontrolled or Air -buried in the soil where there is groundwater outdoor or Ground water/soil present.Soil Any environment Various Lubricating Oil Lubricating oils are low to medium viscosity Lubricating oil hydrocarbons used for bearing, gear, and engine lubrication; also functionally encompasses hydraulic oil (non water based). Water contamination of lubricating oil is assumed.Raw Water The cooling lake and river water to the cooling Raw water lake, as well as ground water from wells, provide Raw water, waste water the sources of raw water utilized by LSCS. Raw water is also rain or ground water. Raw water is Air-indoor controlled, air-indoor water that has not been demineralized or treated uncontrolled, air-outdoor, moist to any significant extent. This can include water air, condensation, raw water, for use in open-cycle cooling water and fire treated water protection systems. Potable water, water that is used for drinking or other personal use, is Any environment considered raw water. Raw water in plant systems may have been rough filtered to remove large particles and may contain a biocide additive for control of micro- and macro-organisms.
Reactor Coolant The Reactor Coolant environment is Reactor coolant demineralized water used within the reactor coolant system to transfer heat from the fuel inside the reactor vessel core. The Reactor Reactor coolant >250 0 C (>482 0 F)Coolant environment also includes Steam. The and neutron flux temperature of the Reactor Coolant environment Reactor coolant and neutron flux is assumed to be >482 'F. The Reactor Coolant environment has been selected for the following systems for consistency with the NUREG-1 801 terminology:
Reactor Vessel, Reactor Vessel Internals, and Reactor Coolant Pressure Boundary System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.0-9 Section 3 -Aging Management Review Results LaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Reactor Coolant The Reactor Coolant and Neutron Flux Reactor coolant and Neutron Flux environment is used for components within the Reactor coolant >250 0 C (>482 0 F)reactor vessel and reactor vessel internals systems that are in contact with reactor coolant and are exposed to neutron fluence projected to Reactor coolant and neutron flux exceed 1.0 x 1017 n/cm2 (E >0.1 MeV) within 60 years. The temperature of the Reactor Coolant and Neutron Flux environment is always assumed to be >482&deg;F.Sodium The Sodium Pentaborate Solution environment is Sodium Pentaborate solution Pentaborate treated water that contains sodium pentaborate.
Solution This is confined to the Standby Liquid Control system at LaSalle which is contained within a limited area of the secondary containment.
Soil The Soil environment is the external environment Soil for components buried in the soil, and it includes Soil or concrete ground water in the soil.Steam The Steam environment is the internal Steam environment associated with dry steam, such as Steam or Treated water main steam up to the main turbine. The Water Chemistry Program is used for managing aging Reactor coolant effects in dry steam environments, but the One-Time Inspection Program is not required by NUREG-1 801.Wet steam environments for LSCS are typically described as either Treated Water or Reactor Coolant, depending upon location, but may use the NUREG-1 801 steam environment for cumulative fatigue damage or loss of material aging effects.Treated Water Treated water is demineralized water or Treated water chemically purified water and is the base water Treated water or Treated borated for all clean systems. Depending on the system, water treated water may require further processing.
Treated water may be deaerated and include Treated water <60C (<140 F)corrosion inhibitors, biocides, or some combination of these treatments.
The treated Steam or Treated water water environment includes all wet steam Air -indoor, uncontrolled or environments.
Treated water Air -indoor, uncontrolled or Air -outdoor'Any environment S LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.0-10 Section 3 -Aging Management Review Results LaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Treated Water The Treated Water >140 0 F environment is the Treated water >60 0 C (>140 0 F)>140&deg;F same as the Treated Water environment, except Treated water the Treated Water >140&deg;F environment is used for systems operating at temperatures
>140&deg;F that are constructed of stainless steel. For materials other than stainless steel, the Treated Water environment is used. The Treated Water>140&deg;F environment includes wet steam. Dry steam, such as main steam, is addressed as its own environment.
Waste Water Waste Water includes radioactive, potentially Waste water radioactive, or non-radioactive waters that are collected from equipment and floor drains, vent Raw water, Waste water system drains, and waters processed by the radwaste system. Waste water may contain contaminants, including oil and boric acid, depending on location, as well as originally treated water that is not monitored by a chemistry program.Water -Flowing The Water -Flowing environment is water that is Water -flowing refreshed, thus having larger impact on leaching; Wat this can be raw water, groundwater, groundwater er- flowing or standing intrusion, or flowing water under a foundation.
Air -indoor, uncontrolled or Air -outdoor or Water -flowing or standing Any environment Water -Standing The Water -Standing environment is water that Water -flowing or standing is stagnant and unrefreshed, thus possibly Air -indoor, uncontrolled or Air -resulting in increased ionic strength of solution Aridoor uncontrolled or up to saturation.
This can be raw water or otdo a w groundwater.
: 1. This environmental alignment is only utilized for TLAA related line items.Differences between the NUREG-1 801 environment and the LSCS AMR environment do not affect aging management of the cumulative fatigue damage aging effect for the applicable components.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.0-11 This Page Intentionally Left Blank Section 3 -Aging Management Review Results 3.1 AGING MANAGEMENT OF REACTOR VESSEL, INTERNALS.
AND REACTOR COOLANT SYSTEM 3.
 
==1.1 INTRODUCTION==
 
This section provides the results of the aging management review for those components identified in Section 2.3.1, Reactor Vessel, Internals, and Reactor Coolant System, as being subject to aging management review. The systems, or portions of systems, which are addressed in this section are described in the indicated sections.* Reactor Coolant Pressure Boundary System (2.3.1.1)* Reactor Vessel (2.3.1.2)* Reactor Vessel Internals (2.3.1.3)3.1.2 RESULTS The following tables summarize the results of the aging management review for the Reactor Vessel, Internals, and Reactor Coolant System: Table 3.1.2-1 Reactor Coolant Pressure Boundary System -Summary of Aging Management Evaluation Table 3.1.2-2 Reactor Vessel -Summary of Aging Management Evaluation Table 3.1.2-3 Reactor Vessel Internals
-Summary of Aging Management Evaluation 3.1.2.1 Materials, Environments, Aging Effects Requiring Management And Aging Management Programs 3.1.2.1.1 Reactor Coolant Pressure Boundary System Materials The materials of construction for the Reactor Coolant Pressure Boundary System components are:* Aluminum Alloy* Carbon Steel* Carbon and Low Alloy Steel Bolting* Cast Austenitic Stainless Steel (CASS)* Copper Alloy with 15% Zinc or More* Copper Alloy with less than 15% Zinc* Glass* Gray Cast Iron LaSalle County Station, Units 1 and 2 Page 3.1-1 License Renewal Application Section 3 -Aging Management Review Results* High Strength Low Alloy Steel Bolting with Yield Strength of 150 ksi or Greater* Stainless Steel* Stainless Steel Bolting Environments The Reactor Coolant Pressure Boundary System components are exposed to the following environments:
* Air -Indoor Uncontrolled" Air with Reactor Coolant Leakage" Closed Cycle Cooling Water* Lubricating Oil* Reactor Coolant* Steam" Treated Water* Treated Water > 140 F* Waste Water Aging Effects Requiring Management The following aging effects associated with the Reactor Coolant Pressure Boundary System components require management:
* Cracking* Cumulative Fatigue Damage* Loss of Fracture Toughness* Loss of Material* Loss of Preload* Wall Thinning Aging Management Programs The following aging management programs manage the aging effects for the Reactor Coolant Pressure Boundary System components: " ASME Section XI Inservice Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)" BWR Stress Corrosion Cracking (B.2.1.7)* Bolting Integrity (B.2.1.11)
* Closed Treated Water Systems (B.2.1.13)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-2 Section 3 -Aging Management Review Results" Flow-Accelerated Corrosion (B.2. 1.10)" Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* Lubricating Oil Analysis (B.2.1.26)
* One-Time Inspection (B.2.1.21)
* One-time Inspection of ASME Code Class 1 Small-Bore Piping (B.2.1.23)
* TLAA* Water Chemistry (B.2.1.2)3.1.2.1.2 Reactor Vessel Materials The materials of construction for the Reactor Vessel components are:* Carbon Steel* Carbon and Low Alloy Steel Bolting" Carbon or Low Alloy Steel with Nickel Alloy Cladding* Carbon or Low Alloy Steel with Stainless Steel Cladding* High Strength Low Alloy Steel Bolting with Yield Strength of 150 ksi or Greater* Low Alloy Steel* Nickel Alloy* Stainless Steel Environments The Reactor Vessel components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Air with Reactor Coolant Leakage* Reactor Coolant* Reactor Coolant and Neutron Flux" Steam* Treated Water Aging Effects Requiring Management The following aging effects associated with the Reactor Vessel components require management:
* Cracking LaSalle County Station, Units 1 and 2 Page 3.1-3 License Renewal Application Section 3 -Aging Management Review Results* Cumulative Fatigue Damage* Loss of Fracture Toughness* Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Reactor Vessel components:
* ASME Section XI Inservice Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)* BWR Control Rod Drive Return Line Nozzle (B.2.1.6)* BWR Feedwater Nozzle (B.2.1.5)" BWR Penetrations (B.2.1.8)* BWR Stress Corrosion Cracking (B.2.1.7)* BWR Vessel ID Attachment Welds (B.2.1.4)" BWR Vessel Internals (B.2.1.9)" Bolting Integrity (B.2.1.11)" External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* One-Time Inspection (B.2.1.21)
* Reactor Head Closure Stud Bolting (B.2.1.3)* Reactor Vessel Surveillance (B.2.1.20)
* TLAA* Water Chemistry (B.2.1.2)3.1.2.1.3 Reactor Vessel Internals Materials The materials of construction for the Reactor Vessel Internals components are:* Cast Austenitic Stainless Steel (CASS)" Nickel Alloy" Stainless Steel* Stainless Steel Bolting* X-750 alloy LaSalle County Station, Units 1 and 2 Page 3.1-4 License Renewal Application Section 3 -Aging Management Review Results Environments The Reactor Vessel Internals components are exposed to the following environments:
* Air/Gas -Dry" Reactor Coolant* Reactor Coolant and Neutron Flux Aging Effects Requiring Management The following aging effects associated with the Reactor Vessel Internals components require management: " Cracking* Cumulative Fatigue Damage* Loss of Fracture Toughness" Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Reactor Vessel Internals components:
* BWR Vessel Internals (B.2.1.9)* TLAA* Water Chemistry (B.2.1.2)LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-5 Section 3 -Aging Management Review Results 3.1.2.2 AMR Results for Which Further Evaluation is Recommended by the GALL Report NUREG-1801 provides the basis for identifying those programs that warrant further evaluation by the reviewer in the license renewal application.
For the Reactor Vessel, Internals, and Reactor Coolant System, those programs are addressed in the following subsections.
3.1.2.2.1 Cumulative Fatigue Damage Fatigue is a time-limited aging analysis (TLAA) as defined in 10 CFR 54.3. TLAAs are required to be evaluated in accordance with 10 CFR 54.21(c).
The evaluation of metal fatigue as a TLAA for the Reactor Vessel, Reactor Vessel Internals, and Reactor Coolant Pressure Boundary System is discussed in Section 4.3.3.1.2.2.2 Loss of Material due to General, Pitting, and Crevice Corrosion 1. Loss of material due to general, pitting, and crevice corrosion could occur in the steel PWR steam generator upper and lower shell and transition cone exposed to secondary feedwater and steam. The existing program relies on control of water chemistry to mitigate corrosion and Inservice Inspection (ISI) to detect loss of material.
The extent and schedule of the existing steam generator inspections are designed to ensure that flaws cannot attain a depth sufficient to threaten the integrity of the welds. However, according to NRC Information Notice (IN) 90-04, the program may not be sufficient to detect pitting and crevice corrosion, if general and pitting corrosion of the shell is known to exist.The GALL Report recommends augmented inspection to manage this aging effect. Furthermore, the GALL Report clarifies that this issue is limited to Westinghouse Model 44 and 51 Steam Generators, where a high-stress region exists at the shell to transition cone weld. Acceptance criteria are described in Branch Technical Position RLSB-1 (Appendix A. 1 of this SRP-LR).Item Number 3.1.1-12 is applicable to PWRs only and is not used for LaSalle.2. Loss of material due to general, pitting, and crevice corrosion could occur in the steel PWR steam generator shell assembly exposed to secondary feedwater and steam. The existing program relies on control of secondary water chemistry to mitigate corrosion.
However, some applicants have replaced only the bottom part of their recirculating steam generators, generating a cut in the middle of the transition cone, and, consequently, a new transition cone closure weld. The GALL Report recommends volumetric examinations performed in accordance with the requirements of ASME Code Section X1 for upper shell-to and lower shell-to transition cones with gross structural discontinuities for managing loss of material due to general, pitting, and crevice corrosion in the welds for Westinghouse Model 44 and 51 Steam Generators, where a high-stress region exists at the shell to transition cone weld.The new continuous circumferential weld, resulting from cutting the transition cone as discussed above, is a different situation from the SG transition cone LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-6 Section 3 -Aging Management Review Results welds containing geometric discontinuities.
Control of water chemistry does not preclude loss of material due to pitting and crevice corrosion at locations of stagnant flow conditions.
The new transition area weld is a field-weld as opposed to having been made in a controlled manufacturing facility, and the surface conditions of the transition weld may result in flow conditions more conducive to initiation of general, pitting, and crevice corrosion than those of the upper and lower transition cone welds. Crediting of the ISI program for the new SG transition cone weld may not be an effective basis for managing loss of material in this weld, as the ISI criteria would only perform a VT-2 visual leakage examination of the weld as part of the system leakage test performed pursuant to ASME Section X1 requirements.
In addition, ASME Section Xl does not require licensees to remove insulation when performing visual examination on non-borated treated water systems. Therefore, the effectiveness of the chemistry control program should be verified to ensure that loss of material due to general, pitting and crevice corrosion is not occurring.
For the new continuous circumferential weld, the GALL Report recommends further evaluation to verify the effectiveness of the chemistry control program.A one-time inspection at susceptible locations is an acceptable method to determine whether an aging effect is not occurring or an aging effect is progressing very slowly, such that the component's intended function will be maintained during the period of extended operation.
Furthermore, the GALL Report clarifies that this issue is limited to replacement recirculating steam generators with a new transition cone closure weld.Item Number 3.1.1-12 is applicable to PWRs only and is not used for LaSalle.3.1.2.2.3 Loss of Fracture Toughness due to Neutron Irradiation Embrittlement
: 1. Neutron irradiation embrittlement is a TLAA to be evaluated for the period of extended operation for all ferritic materials that have a neutron fluence greater than 1017 n/cm2 (E >1 MeV) at the end of the license renewal term. Certain aspects of neutron irradiation embrittlement are TLAAs as defined in 10 CFR 54.3. TLAAs are required to be evaluated in accordance with 10 CFR 54.21(c)(1).
This TLAA is addressed separately in Section 4.2, "Reactor Vessel Neutron Embrittlement Analysis," of this SRP-LR.The evaluation of neutron irradiation embrittlement for all ferritic reactor vessel components that have a neutron fluence greater than 1 x 10 17 n/cm 2 (E>1 MeV) at the end of the license renewal term is performed as a TLAA as discussed in Section 4.2.2. Loss of fracture toughness due to neutron irradiation embrittlement could occur in BWR and PWR reactor vessel beltline shell, nozzle, and welds exposed to reactor coolant and neutron flux. A reactor vessel materials surveillance program monitors neutron irradiation embrittlement of the reactor vessel. The reactor vessel surveillance program is plant-specific, depending on matters such as the composition of limiting materials, availability of surveillance capsules, and projected fluence levels. In accordance with 10 CFR Part 50, Appendix H, an applicant is required to submit its proposed withdrawal LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-7 Section 3 -Aging Management Review Results schedule for approval prior to implementation.
Untested capsules placed in storage must be maintained for future insertion.
Thus, further staff evaluation is required for license renewal. Specific recommendations for an acceptable AMP are provided in Chapter X1, Section M31 of the GALL Report.The Reactor Vessel Surveillance (B.2.1.20) aging management program will be implemented to manage the loss of fracture toughness of the reactor vessel beltline components and welds exposed to a reactor coolant and neutron flux environment.
The program meets the requirements of 10 CFR 50, Appendix H.The program evaluates neutron embrittlement by projecting Upper-Shelf Energy (USE) for reactor materials and impact on Adjusted Reference Temperature for the development of pressure-temperature limit curves. Embrittlement evaluations are performed in accordance with Regulatory Guide 1.99, Rev. 2. The schedule for removing surveillance capsules is in accordance the timetable specified in BWRVIP-86-A for the current license term and in accordance with BWRVIP-1 16 for the period of extended operation.
: 3. Ductility
-Reduction in Fracture Toughness is a plant-specific TLAA for Babcock and Wilcox (B&W) reactor internals to be evaluated for the period of extended operation in accordance with the staff's safety evaluation concerning"Demonstration of the Management of Aging Effects for the Reactor Vessel Internals," Babcock and Wilcox Owners Group report number BAW-2248, which is included in BAW-2248A, March 2000. Plant-specific TLAAs are addressed in Section 4.7, "Other Plant-Specific Time-Limited Aging Analyses," of this SRP-LR.Item Number 3.1.1-15 is applicable to PWRs only and is not used for LaSalle.3.1.2.2.4 Cracking due to Stress Corrosion Cracking and Intergranular Stress Corrosion Cracking 1. Cracking due to stress corrosion cracking (SCC) and intergranular stress corrosion cracking (IGSCC) could occur in the stainless steel and nickel alloy BWR top head enclosure vessel flange leak detection lines. The GALL Report recommends that a plant-specific AMP be evaluated because existing programs may not be capable of mitigating or detecting cracking due to SCC and IGSCC. Acceptance criteria are described in Branch Technical Position RLSB- 1 (Appendix A. 1 of this SRP-LR).Item Number 3.1.1-16 is not used. The top head enclosure vessel flange leak detection line is carbon steel piping and is therefore not susceptible to stress corrosion cracking (SCC) or intergranular stress corrosion cracking (IGSCC).2. Cracking due to SCC and IGSCC could occur in stainless steel BWR isolation condenser components exposed to reactor coolant. The existing program relies on control of reactor water chemistry to mitigate SCC and on ASME Section X1 ISI to detect cracking.
However, the existing program should be augmented to detect cracking due to SCC and IGSCC. The GALL Report recommends an augmented program to include temperature and radioactivity LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-8 Section 3 -Aging Management Review Results monitoring of the shell-side water and eddy current testing of tubes to ensure that the component's intended function will be maintained during the period of extended operation.
Acceptance criteria are described in Branch Technical Position RLSB- I (Appendix A. I of this SRP-LR).Item Number 3.1.1-17 is not used since the LaSalle BWR design does not include an isolation condenser.
3.1.2.2.5 Crack Growth due to Cyclic Loading Crack growth due to cyclic loading could occur in reactor vessel shell forgings clad with stainless steel using a high-heat-input welding process. Growth of intergranular separations (underclad cracks) in the heat-affected zone under austenitic stainless steel cladding is a TLAA to be evaluated for the period of extended operation for all the SA-508-CI-2 forgings where the cladding was deposited with a high heat input welding process. The methodology for evaluating the underclad flaw should be consistent with the flaw evaluation procedure and criterion in the ASME Section X1 Code, 2004 edition'.
See the SRP-LR, Section 4.7, "Other Plant-Specific Time-Limited Aging Analysis, " for generic guidance for meeting the requirements of 10 CFR 54.21(c).Item Number 3.1.1-18 is applicable to PWRs only and is not used for LaSalle.3.1.2.2.6 Cracking due to Stress Corrosion Cracking 1. Cracking due to SCC could occur in the PWR stainless steel reactor vessel flange leak detection lines and bottom-mounted instrument guide tubes exposed to reactor coolant. The GALL Report recommends further evaluation to ensure that these aging effects are adequately managed. The GALL Report recommends that a plant-specific AMP be evaluated to ensure that this aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RLSB-1 (Appendix A. 1 of this SRP-LR).Item Number 3.1.1-19 is applicable to PWRs only and is not used for LaSalle.2. Cracking due to SCC could occur in Class 1 PWR cast austenitic stainless steel (CASS) reactor coolant system piping, piping components, and piping elements exposed to reactor coolant. The existing program relies on control of water chemistry to mitigate SCC; however, SCC could occur for CASS components that do not meet the NUREG-0313 guidelines with regard to ferrite and carbon content. The GALL Report recommends further evaluation of a plant-specific program for these components to ensure that this aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RLSB- 1 (Appendix A. 1 of this SRP-LR).Item Number 3.1.1-20 is applicable to PWRs only and is not used for LaSalle.1 Refer to the GALL Report, Chapter I, for applicability of other editions of the ASME Code, Section X1.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-9 Section 3 -Aging Management Review Results 3.1.2.2.7 Cracking due to Cyclic Loading Cracking due to cyclic loading could occur in steel and stainless steel BWR isolation condenser components exposed to reactor coolant. The existing program relies on ASME Section X1 ISI. However, the existing program should be augmented to detect cracking due to cyclic loading. The GALL Report recommends an augmented program to include temperature and radioactivity monitoring of the shell-side water and eddy current testing of tubes to ensure that the component's intended function will be maintained during the period of extended operation.
Acceptance criteria are described in Branch Technical Position RLSB-1 (Appendix A. 1 of this SRP-LR).Item Number 3.1.1-21 is not used since the LaSalle BWR design does not include an isolation condenser.
3.1.2.2.8 Loss of Material due to Erosion Loss of material due to erosion could occur in steel steam generator feedwater impingement plates and supports exposed to secondary feedwater.
The GALL Report recommends further evaluation of a plant-specific AMP to ensure that this aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RLSB-1 (Appendix A. I of this SRP-LR).Item Number 3.1.1-22 is applicable to PWRs only and is not used for LaSalle.Loss of material due to erosion for Reactor Vessel, Internals, and Reactor Coolant System is addressed in Item Number 3.1.1-110.
3.1.2.2.9 Cracking due to Stress Corrosion Cracking and Irradiation-Assisted Stress Corrosion Cracking Cracking due to SCC and irradiation-assisted stress corrosion cracking (IASCC)could occur in inaccessible locations for stainless steel and nickel-alloy Primary and Expansion PWR reactor vessel internal components.
If aging effects are identified in accessible locations, the GALL Report recommends further evaluation of the aging effects in inaccessible locations on a plant-specific basis to ensure that this aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RLSB-1 (Appendix A. I of this SRP-LR).This paragraph for further evaluation from NUREG-1 800 was removed by LR-ISG-2011-04.3.1.2.2.10 Loss of Fracture Toughness due to Neutron Irradiation Embrittlement, Change in Dimension due to Void Swelling, Loss of Preload due to Stress Relaxation, or Loss of Material due to Wear Loss of fracture toughness due to neutron irradiation embrittlement, change in dimension due to void swelling, loss of preload due to stress relaxation, or loss of material due to wear could occur in inaccessible locations for stainless steel and nickel-alloy Primary and Expansion PWR reactor vessel internal components.
If aging effects are identified in accessible locations, the GALL Report recommends LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-10 Section 3 -Aging Management Review Results further evaluation of the aging effects in inaccessible locations on a plant-specific basis to ensure that this aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RLSB-1 (Appendix A. 1 of this SRP-LR).This paragraph for further evaluation from NUREG-1 800 was removed by LR-ISG-2011-04.3.1.2.2.11 Cracking due to Primary Water Stress Corrosion Cracking 1. Foreign operating experience in steam generators with a similar design to that of Westinghouse Model 51 has identified extensive cracking due to primary water stress corrosion cracking (PWSCC) in steam generator (SG) divider plate assemblies fabricated of Alloy 600 and/or the associated Alloy 600 weld materials, even with proper primary water chemistry (EPRI TR-1014982).
Cracks have been detected in the stub runner, adjacent to the tubesheet/stub runner weld and with depths of almost a third of the divider plate thickness.
Therefore, the water chemistry program may not be effective in managing the aging effect of cracking due to PWSCC in SG divider plate assemblies.
This is of particular concern for steam generators where the tube-tubesheet welds are considered structural welds and/or where the divider plate assembly contributes to the mechanical integrity of the tubesheet.
Although these SG divider plate cracks may not have a significant safety impact in and of themselves, these cracks could impact adjacent items, such as the tubesheet and the channel head, if they propagate to the boundary with these items. For the tubesheet, PWSCC cracks in the divider plate could propagate to the tubesheet cladding with possible consequences to the integrity of the tube/tubesheet welds. For the channel head, the PWSCC cracks in the divider plate could propagate to the SG triple point and potentially affect the pressure boundary of the SG channel head.The existing program relies on control of reactor water chemistry to mitigate cracking due to PWSCC. The GALL Report recommends that a plant-specific AMP be evaluated, along with the primary water chemistry program, because the existing primary water chemistry program may not be capable of mitigating cracking due to PWSCC. Acceptance criteria are described in Branch Technical Position RLSB- 1 (Appendix A. I of this SRP-LR).Item Number 3.1.1-25 is applicable to PWRs only and is not used for LaSalle.2. Cracking due to PWSCC could occur in steam generator nickel alloy tube-to-tubesheet welds exposed to reactor coolant. Unless the NRC has approved a redefinition of the pressure boundary in which the tube-to-tubesheet weld is no longer included, the effectiveness of the primary water chemistry program should be verified to ensure cracking is not occurring:
For plants with Alloy 600 steam generator tubes that have not been thermally treated and for which an alternate repair criteria such as C*, F*or W* has been permanently approved, the weld is no longer part of the LaSalle County Station, Units 1 and 2 Page 3.1-11 License Renewal Application Section 3 -Aging Management Review Results pressure boundary and no plant specific aging management program is required;For plants with Alloy 600 steam generator tubes that have not been thermally treated and for which there is no permanently approved alternate repair criteria such as C*, F* or W*, a plant-specific AMP is required;For plants with Alloy 600TT steam generator tubes and for which an alternate repair criteria such as H* has been permanently approved, the weld is no longer part of the pressure boundary and no plant specific aging management program is required;For plants with Alloy 600TT steam generator tubes and for which there is no alternate repair criteria such as H* permanently approved, a plant-specific AMP is required;For plants with Alloy 690TT steam generator tubes with Alloy 690 tubesheet cladding, the water chemistry is sufficient, and no further action or plant-specific aging management program is required;For plants with Alloy 690TT steam generator tubes and with Alloy 600 tubesheet cladding, either a plant-specific program or a rationale for why such a program is not needed is required.The existing program relies on control of reactor water chemistry to mitigate cracking due to PWSCC. The GALL Report recommends that a plant-specific AMP be evaluated, along with the primary water chemistry program, because the existing primary water chemistry program may not be capable of mitigating cracking due to PWSCC. Acceptance criteria are described in Branch Technical Position RLSB- I (Appendix A. I of this SRP-LR).Item Number 3.1.1-20 is applicable to PWRs only and is not used for LaSalle.3.1.2.2.12 Cracking due to Fatigue EPRI 1016596, Materials Reliability Program: Pressurized Water Reactor Internals Inspection and Evaluation Guidelines (MRP-227-Rev.
: 0) identifies cracking due to fatigue as an aging effect that can occur for the lower flange weld in the core support barrel assembly, fuel alignment plate in the upper internals assembly, and core support plate lower support structure in PWR internals designed by Combustion Engineering.
The GALL Report recommends that inspection for cracking in this component be performed if acceptable fatigue life cannot be demonstrated by TLAA through the period of extended operation as defined in 10 CFR 54.3.This paragraph for further evaluation from NUREG-1 800 was removed by LR-ISG-2011-04.3.1.2.2.13 Cracking due to Stress Corrosion Cracking and Fatigue Cracking due to stress corrosion cracking and fatigue could occur in nickel alloy control rod guide tube assemblies, guide tube support pins exposed to reactor LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-12 Section 3 -Aging Management Review Results coolant, and neutron flux. The GALL Report, AMR Item IV.B2.RP-355, recommends further evaluation of a plant-specific AMP to ensure this aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RLSB-1 (Appendix A. 1 of this SRP-LR).This paragraph for further evaluation from NUREG-1 800 was removed by LR-ISG-2011-04.3.1.2.2.14 Loss of Material due to Wear Loss of material due to wear could occur in nickel alloy control rod guide tube assemblies, guide tube support pins and in Zircaloy-4 incore instrumentation lower thimble tubes exposed to reactor coolant, and neutron flux. The GALL Report, AMR Items IV. B2. RP-356 and IV.B3.RP-357, recommends further evaluation of a plant-specific AMP to ensure this aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RLSB- I (Appendix A. 1 of this SRP-LR).This paragraph for further evaluation from NUREG-1 800 was removed by LR-ISG-2011-04.3.1.2.2.15 Quality Assurance for Aging Management of Nonsafety-Related Components QA provisions applicable to License Renewal are discussed in Section B.1.3..3.1.2.2.16 Ongoing Review of Operating Experience Ongoing review of operating experience is addressed in Appendix A, Section A. 1.6 and Appendix B, Section B.1.4.LaSalle County Station, Units 1 and 2 Page 3.1-13 License Renewal Application Section 3 -Aging Management Review Results 3.1.2.3 Time-Limited Aging Analysis The time-limited aging analyses identified below are associated with the Reactor Vessel, Internals, and Reactor Coolant System components:
* Section 4.2, Reactor Vessel and Internals Neutron Embrittlement Analyses* Section 4.2.1, Neutron Fluence Analyses* Section 4.2.2, Upper-Shelf Energy Analyses" Section 4.2.3, Adjusted Reference Temperature Analyses* Section 4.2.4, Pressure -Temperature Limits* Section 4.2.5, Axial Weld Failure Probability Assessment Analyses* Section 4.2.6, Circumferential Weld Failure Probability Assessment Analyses" Section 4.2.7, Reactor Pressure Vessel Reflood Thermal Shock Analyses* Section 4.2.8, RPV Core Plate Rim Hold-Down Bolt Loss of Preload Analysis* Section 4.2.9, Jet Pump Riser Brace Clamp Loss of Preload Analysis* Section 4.2.10, Jet Pump Slip Joint Repair Clamp Loss of Preload Analysis* Section 4.3, Metal Fatigue Analyses* Section 4.3.1, ASME Section III, Class 1 Fatigue Analyses* Section 4.3.2, ASME Section III, Class 2 and 3 and ANSI B31.1 Allowable Stress Analyses* Section 4.3.3, Environmental Fatigue Analyses for RPV and Class 1 Piping" Section 4.3.4, Reactor Vessel Internals Fatigue Analyses* Section 4.3.5, High-Energy Line Break (HELB) Analyses Based on Fatigue* Section 4.7, Other Plant-Specific Analyses 0 Section 4.7.2, Main Steam Line Flow Restrictors Erosion Analysis 3.
 
==1.3 CONCLUSION==
 
The Reactor Vessel, Internals, and Reactor Coolant System piping fittings, and components that are subject to aging management review have been identified in accordance with the requirements of 10 CFR 54.4. The aging management programs selected to manage aging effects for the Reactor Vessel, Internals, and Reactor Coolant System components are identified in the summaries in Section 3.1.2.1 above.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-14 Section 3 -Aging Management Review Results A description of these aging management programs is provided in Appendix B, along with the demonstration that the identified aging effects will be managed for the period of extended operation.
Therefore, based on the conclusions provided in Appendix B, the effects of aging associated with the Reactor Vessel, Internals, and Reactor Coolant System components will be adequately managed so that there is reasonable assurance that the intended functions are maintained consistent with the current licensing basis during the period of extended operation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-15 This Page Intentionally Left Blank O O Section 3 -Aging Managerne eew Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number EffectlMechanism Programs Evaluation Recommended 3.1.1-1 High strength, low-alloy Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation is steel top head closure damage due to evaluated for the period documented in Subsection 3.1.2.2.1.
stud assembly exposed fatigue of extended operation to air with potential for (See SRP, Sec 4.3 reactor coolant leakage "Metal Fatigue," for acceptable methods to comply with 10 CFR 54.21 (c)(1))3.1.1-2 PWR only 3.1.1-3 Stainless steel or nickel Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation is alloy reactor vessel damage due to evaluated for the period documented in Subsection 3.1.2.2.1.
internal components fatigue of extended operation exposed to reactor (See SRP, Sec 4.3 coolant and neutron flux "Metal Fatigue," for acceptable methods to comply with 10 CFR 54.21 (c)(1))3.1.1-4 Steel pressure vessel Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation is support skirt and damage due to evaluated for the period documented in Subsection 3.1.2.2.1.
attachment welds fatigue of extended operation (See SRP, Sec 4.3"Metal Fatigue," for acceptable methods to comply with 10 CFR 54.21 (c)(1))LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-16 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-5 PWR only 3.1.1-6 Steel (with or without Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation is nickel-alloy or stainless damage due to evaluated for the period documented in Subsection 3.1.2.2.1.
steel cladding), or fatigue of extended operation, stainless steel; or nickel and for Class 1 alloy reactor coolant components pressure boundary environmental effects on components:
piping, fatigue are to be piping components, and addressed. (See SRP, piping elements exposed Sec 4.3 "Metal Fatigue," to reactor coolant for acceptable methods to comply with 10 CFR 54.21 (c)(1))3.1.1-7 Steel (with or without Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation is nickel-alloy or stainless damage due to evaluated for the period documented in Subsection 3.1.2.2.1.
steel cladding), or fatigue of extended operation, stainless steel; or nickel and for Class 1 alloy reactor vessel components components:
flanges; environmental effects on nozzles; penetrations; fatigue are to be safe ends; thermal addressed. (See SRP, sleeves; vessel shells, Sec 4.3 "Metal Fatigue," heads and welds for acceptable methods exposed to reactor to comply with 10 CFR coolant 54.21(c)(1))
3.1.1-8 PWR only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-17 0 0 0 Section 3-Aging Manageme #iew Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-9 PWR only 3.1.1-10 PWR only 3.1.1-11 Steel or stainless steel Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation is pump and valve closure damage due to evaluated for the period documented in Subsection 3.1.2.2.1.
bolting exposed to high fatigue of extended operation; temperatures and check ASME Code limits thermal cycles for allowable cycles (less than 7000 cycles) of thermal stress range.(SRP Sec 4.3 "Metal Fatigue," for acceptable methods to comply with 10 CFR 54.21 (c)(1))3.1.1-12 PWR only 3.1.1-13 Steel (with or without Loss of fracture TLAA is to be evaluated Yes, TLAA Consistent with NUREG-1 801. TLAA will stainless steel cladding) toughness due to in accordance with be used to manage loss of fracture reactor vessel beltline neutron irradiation Appendix G of 10 CFR toughness of carbon or low alloy steel with shell, nozzles, and welds embrittlement Part 50 and RG 1.99. stainless steel cladding reactor vessel shell, exposed to reactor The applicant may nozzles, and welds within the beltline that coolant and neutron flux choose to demonstrate are exposed to reactor coolant and neutron that the materials of the flux.nozzles are not controlling for the TLAA See subsection 3.1.2.2.3.1.
evaluations LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-18 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1,1-14 Steel (with or without Loss of fracture Chapter XI.M31, "Reactor Yes, plant-specific Consistent with NUREG-1801.
The cladding) reactor vessel toughness due to Vessel Surveillance" or integrated Reactor Vessel Surveillance (B.2.1.20) beltline shell, nozzles, neutron irradiation surveillance program will be used to manage loss of and welds; safety embrittlement program fracture toughness of the carbon or low injection nozzles alloy steel with stainless steel cladding reactor vessel shell, nozzle, and welds within the beltline that are exposed to reactor coolant and neutron flux.See subsection 3.1.2.2.3.2.
3.1.1-15 PWR only 3.1.1-16 Stainless steel and nickel Cracking due to A plant-specific aging Yes, plant-specific Not Applicable.
alloy top head enclosure stress corrosion management program is There are no stainless steel or nickel alloy vessel flange leak cracking, to be evaluated because top head enclosure vessel flange leak detection line intergranular stress existing programs may detection piping components in the Reactor corrosion cracking not be capable of Vessel, Internals, and Reactor Coolant mitigating or detecting System. The top head enclosure vessel crack initiation and flange leak detection line is carbon steel growth due to SCC in the piping that is not susceptible to stress vesselflange leak corrosion cracking (SCC) or intergranular detection line stress corrosion cracking (IGSCC).See subsection 3.1.2.2.4.1.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-19 0 O Section 3 -Aging Managementeview Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-17 Stainless steel isolation Cracking due to Chapter XI.M1, "ASME Yes, detection of Not Applicable.
condenser components stress corrosion Section XI Inservice aging effects is to The LaSalle BWR design does not include exposed to reactor cracking, Inspection, Subsections be evaluated an lation condeses.coolant intergranular stress IWB, IWC, and IWD" for an isolation condenser.
corrosion cracking Class 1 components, and See subsection 3.1.2.2.4.2.
Chapter XI.M2, 'Water Chemistry" for BWR water, and a plant-specific verification program 3.1.1-18 PWR only 3.1.1-19 PWR only 3.1.1-20 PWR only 3.1.1-21 Steel and stainless steel Cracking due to cyclic Chapter XI.M1, "ASME Yes, detection of Not Applicable.
isolation condenser loading Section XI Inservice aging effects is to The LaSalle BWR design does not include components exposed to Inspection, Subsections be evaluated an lation condeses.reactor coolant IWB, IWC, and IWD" for an isolation condenser.
Class 1 components The See subsection 3.1.2.2.7.
ISI program is to be augmented by a plant-specific verification program LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-20 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-22 PWR only 3.1.1-23 There is no Item Number 3.1.1-23 listed in NUREG-1 800 or subsequent ISGs.3.1.1-24 There is no Item Number 3.1.1-24 listed in NUREG-1 800 or subsequent ISGs.3.1.1-25 PWR only 3.1.1-26 There is no Item Number 3.1.1-26 listed in NUREG-1 800 or subsequent ISGs.3.1.1-27 There is no Item Number 3.1.1-27 listed in NUREG-1800 or subsequent ISGs.3.1.1-28 PWR only LaSalle County Station, Units 1 and 2 License Renewal Application 0 Page 3.1-21 0 0 Section 3 -Aging Managementeview Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-29 Nickel alloy core shroud Cracking due to Chapter XI.M1, "ASME No The BWR Vessel Internals (B.2.1.9)and core plate access stress corrosion Section XI Inservice program has been substituted for the hole cover (welded cracking, Inspection, Subsections ASME Section XI Inservice Inspection, covers) exposed to intergranular stress IWB, IWC, and IWD," and Subsections IWB, IWC, and IWD (B.2.1.1)reactor coolant corrosion cracking, Chapter XI.M2, 'Water program, and will be used with the Water irradiation-assisted Chemistry," and for Chemistry (B.2.1.2) program to manage stress corrosion BWRs with a crevice in cracking of the nickel alloy core shroud and cracking the access hole covers, core plate access hole cover (welded augmented inspection covers) exposed to reactor coolant and using UT or other neutron flux in the Reactor Vessel Internals.
acceptable techniques An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.1.1-30 Stainless steel or nickel Cracking due to Chapter XI.M1, "ASME No Consistent with NUREG-1801 with alloy penetration:
drain stress corrosion Section XI Inservice exceptions.
The ASME Section XI line exposed to reactor cracking, Inspection, Subsections Inservice Inspection, Subsections IWB, coolant intergranular stress IWB, IWC, and IWD," and IWC, and IWD (B.2.1.1) program and Water corrosion cracking, Chapter XI.M2, 'Water Chemistry (B.2.1.2) program will be used to cyclic loading Chemistry" manage cracking of stainless steel, nickel alloy, and carbon and low alloy steel with stainless steel or nickel alloy cladding nozzles, penetrations, and vessel shell components exposed to reactor coolant and reactor coolant and neutron flux in the Reactor Vessel. The reactor vessel drain line is carbon steel and is therefore addressed in Item Number 3.1.1-31.An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-22 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-31 Steel and stainless steel Loss of material due Chapter XI.M1, "ASME No The One-Time Inspection (B.2.1.21) isolation condenser to general (steel Section XI Inservice program has been substituted for the components exposed to only), pitting, and Inspection, Subsections ASME Section XI Inservice Inspection, reactor coolant crevice corrosion IWB, IWC, and IWD," and Subsections IWB, IWC, and IWD (B.2.1.1)Chapter XI.M2, 'Water program, and will be used with the Water Chemistry" Chemistry (B.2.1.2) program to manage loss of material of the carbon steel RPV flange leak detection line, carbon steel Class 1 piping, fittings and branch connections
< 4-inch NPS, and carbon steel piping, piping components and piping elements exposed to reactor coolant in the Reactor Coolant Pressure Boundary System. The LaSalle BWR design does not include an isolation condenser.
An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.1.1-32 PWR only 3.1.1-33 PWR only 3.1.1-34 PWR only 3.1.1-35 PWR only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-23 Section 3-Aging Managementeiew Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-36 PWR only 3.1.1-37 PWR only 3.1.1-38 Cast austenitic stainless Loss of fracture Chapter XIM1, "ASME No Consistent with NUREG-1801.
The ASME steel Class 1 pump toughness due to Section XI Inservice Section XI Inservice Inspection, casings, and valve thermal aging Inspection, Subsections Subsections IWB, IWC, and IWD (B.2.1.1)bodies and bonnets embrittlement IWB, IWC, and IWD" for program will be used to manage loss of exposed to reactor Class 1 components.
For fracture toughness of the cast austenitic coolant >250 deg-C pump casings and valve stainless steel Class 1 pump casings and (>482 deg-F) bodies, screening for valve bodies and bonnets exposed to susceptibility to thermal reactor coolant >250 deg-C (>482 deg-F) in aging is not necessary.
the Reactor Coolant Pressure Boundary System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-24 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-39 Steel, stainless steel, or Cracking due to Chapter XI.M1, "ASME No Consistent with NUREG-1801 with steel with stainless steel stress corrosion Section XI Inservice exceptions.
The ASME Section XI cladding Class 1 piping, cracking, Inspection, Subsections Inservice Inspection, Subsections IWB, fittings and branch intergranular stress IWB, IWC, and IWD" for IWC, and IWD (B.2.1.1) program, Water connections
< NPS 4 corrosion cracking Class 1 components, Chemistry (B.2.1.2) program, and One-time exposed to reactor (for stainless steel Chapter XI.M2, 'Water Inspection of ASME Code Class 1 Small-coolant only), and thermal, Chemistry," and Bore Piping (B.2.1.23) program will be used mechanical, and XI.M35, "One-Time to manage cracking of the carbon steel and vibratory loading Inspection of ASME stainless steel Class 1 piping, fittings, and Code Class 1 Small-bore branch connections
< NPS 4 exposed to Piping" reactor coolant in the Reactor Coolant Pressure Boundary System.An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.1.1-40 PWR only 3.1.1-40x PWR only 3.1.1-41 Nickel alloy core shroud Cracking due to Chapter XI.M1, "ASME No Not Applicable.
and core plate access stress corrosion Section XI Inservice hole cover (mechanical cracking, Inspection, Subsections The core shroud and core plate access covers) exposed to intergranular stress IWB, IWC, and IWD" for hole covers are a welded design and are reactor coolant corrosion cracking, Class 1 components, and addressed in Item Number 3.1.1-29.irradiation-assisted Chapter XI.M2,  stress corrosion Chemistry" cracking LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-25 0 0 Section 3-Aging Manageme vniew Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-42 PWR only 3.1.1-43 Stainless steel and Loss of material due Chapter XI.M1, "ASME No The BWR Vessel Internals (B.2.1.9)nickel-alloy reactor to pitting and crevice Section XI Inservice program has been substituted for the vessel internals exposed corrosion Inspection, Subsections ASME Section XI Inservice Inspection, to reactor coolant IWB, IWC, and IWD" for Subsections IWB, IWC, and IWD (B.2.1.1)Class 1 components, and program, and will be used with the Water Chapter XI.M2, 'Water Chemistry (B.2.1.2) program to manage Chemistry" loss of material of stainless steel, nickel alloy, and X-750 alloy reactor vessel internals components exposed to reactor coolant and reactor coolant and neutron flux in the Reactor Vessel Internals.
An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.1.1-44 PWR only 3.1.1-45 PWR only 3.1.1-46 PWR only 3.1.1-47 PWR only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-26 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-48 PWR only 3.1.1-49 PWR only 3.1.1-50 Cast austenitic stainless Loss of fracture Chapter XI.M12, No Not Applicable.
steel Class 1 piping, toughness due to "Thermal Aging piping component, and thermal aging Embrittlement of Cast The LaSalle BWR design does not include piping elements and embrittlement Austenitic Stainless Steel piping, piping components, and piping control rod drive pressure (CASS)" pipints or compodt adr piping housings exposed to elements or control rod drive pressure reactor coolant >250 deg- housings exposed to reactor coolant >250 C cooldantF) deg-C (>482 deg-F) in Reactor Vessel, C(>482 eg-) Internals, and Reactor Coolant System.The CRD housings and flanges are stainless steel.3.1.1-51a PWR only 3.1.1-51b PWR only 3.1.1-52a PWR only 3.1.1-52b PWR only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-27 Section 3 -Aging Managemenreiew Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-52c PWR only 3.1.1-53a PWR only 3.1.1-53b PWR only 3.1.1-53c PWR only 3.1.1-54 PWR only 3.1.1-55a PWR only 3.1.1-55b PWR only 3.1.1-55c PWR only 3.1.1-56a PWR only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-28 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-56b PWR only 3.1.1-56c PWR only 3.1.1-57 There is no Item Number 3.1.1-57 listed in NUREG-1 800 or subsequent ISGs.3.1.1-58a PWR only 3.1.1-58b PWR only 3.1.1-59a PWR only 3.1.1-59b PWR only 3.1.1-59c PWR only LaSalle County Station, Units 1 and 2 License Renewal Application 0 Page 3.1-29 Section 3 -Aging Managementeview Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-60 Steel piping, piping Wall thinning due to Chapter XI.M17, "Flow- No Consistent with NUREG-1801.
The Flow-components, and piping flow-accelerated Accelerated Corrosion" Accelerated Corrosion (B.2.1.10) program elements exposed to corrosion will be used to manage wall thinning of reactor coolant carbon steel piping, piping components, and piping elements exposed to reactor coolant in the Reactor Coolant Pressure Boundary System.3.1.1-61 PWR only 3.1.1-62 PWR only 3.1.1-63 Steel or stainless steel Loss of material due Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Bolting closure bolting exposed to general (steel Integrity" Integrity (B.2.1.11) program will be used to to air with reactor coolant only), pitting, and manage loss of material of carbon and low leakage crevice corrosion or alloy steel and high strength low alloy steel wear closure bolting exposed to air with reactor coolant leakage in the Reactor Vessel and Reactor Coolant Pressure Boundary System.3.1.1-64 PWR only 3.1.1-65 PWR only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-30 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-66 PWR only 3.1.1-67 Steel or stainless steel Loss of preload due Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Bolting closure bolting exposed to thermal effects, Integrity" Integrity (B.2.1.11) program will be used to to air -indoor with gasket creep, and manage loss of preload of carbon and low potential for reactor self-loosening alloy steel, high strength low alloy steel, coolant leakage and stainless steel closure bolting exposed to air -indoor uncontrolled and air with the potential for reactor coolant leakage in the Reactor Vessel and Reactor Coolant Pressure Boundary System.3.1.1-68 PWR only 3.1.1-69 PWR only 3.1.1-70 PWR only 3.1.1-71 PWR only 3.1.1-72 PWR only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-31 0 Section 3 -Aging Management~eview Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-73 PWR only 3.1.1-74 PWR only 3.1.1-75 PWR only 3.1.1-76 PWR only 3.1.1-77 PWR only 3.1.1-78 PWR only 3.1.1-79 Stainless steel; steel with Loss of material due Chapter XI.M2, 'Water No Consistent with NUREG-1 801 with nickel-alloy or stainless to pitting and crevice Chemistry," and Chapter exceptions.
The One-Time Inspection steel cladding; and corrosion XI.M32, "One-Time (B.2.1.21) program and Water Chemistry nickel-alloy reactor Inspection" (B.2.1.2) program will be used to manage coolant pressure loss of material of stainless steel reactor boundary components coolant pressure boundary components exposed to reactor exposed to reactor coolant in the Reactor coolant Coolant Pressure Boundary System.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-32 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-80 PWR only 3.1.1-81 PWR only 3.1.1-82 PWR only 3.1.1-83 PWR only 3.1.1-84 Steel top head enclosure Loss of material due Chapter XL.M2, 'Water No Consistent with NUREG-1801 with (without cladding) top to general, pitting, Chemistry," and Chapter exceptions.
The One-Time Inspection head nozzles (vent, top and crevice corrosion XI.M32, "One-Time (B.2.1.21) program and Water Chemistry head spray or RCIC, and Inspection" (B.2.1.2) program will be used to manage spare) exposed to reactor loss of material of carbon steel and low coolant alloy steel top head nozzles and other reactor vessel nozzles, safe ends, and welds exposed to reactor coolant, steam, and reactor coolant and neutron flux in the Reactor Vessel.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-33 0 O Section 3 -Aging Managementeview Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1,1-85 Stainless steel, nickel- Loss of material due Chapter XI.M2, 'Water No Consistent with NUREG-1801 with alloy, and steel with to pitting and crevice Chemistry," and Chapter exceptions.
The Water Chemistry (B.2.1.2)nickel-alloy or stainless corrosion XI.M32, "One-Time program and One-Time Inspection steel cladding reactor Inspection" (B.2.1.21) program will be used to manage vessel flanges, nozzles, loss of material of stainless steel, nickel-penetrations, safe ends, alloy, and carbon or low alloy steel with vessel shells, heads and stainless steel or nickel cladding reactor welds exposed to reactor vessel flanges, nozzles, penetrations, safe coolant ends, thermal sleeves, internal attachments, vessel shells, heads and welds exposed to reactor coolant and reactor coolant and neutron flux in the Reactor Vessel.An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.1.1-86 PWR only 3.1.1-87 PWR only 3.1.1-88 PWR only 3.1.1-89 PWR only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-34 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-90 PWR only 3.1.1-91 High-strength low alloy Cracking due to Chapter XI.M3, "Reactor No Consistent with NUREG-1801 with steel closure head stud stress corrosion Head Closure Stud exceptions.
The Reactor Head Closure assembly exposed to air cracking; loss of Bolting" Stud Bolting (B.2.1.3) program will be used with potential for reactor material due to to manage cracking and loss of material of coolant leakage general, pitting, and high strength low alloy steel closure head crevice corrosion, or stud bolting assemblies exposed to air with wear (BWR) potential for reactor coolant leakage in the Reactor Vessel.Exceptions apply to the NUREG-1 801 recommendations for Reactor Head Closure Stud Bolting (B.2.1.3) program implementation.
3.1.1-92 PWR only 3.1.1-93 PWR only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-35 Section 3 -Aging Managementeview Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Component
[Aging Aging Management Further Discussion IEffect/Mechanism Programs Evaluation
____________________I
_________________
____________________Recommended
__________________________
Stainless steel and nickel alloy vessel shell attachment welds exposed to reactor coolant Cracking due to stress corrosion cracking, intergranular stress corrosion cracking Chapter XI.M4, "BWR Vessel ID Attachment Welds," and Chapter XI.M2, "Water Chemistry" No Consistent with NUREG-1801 with exceptions.
The BWR Vessel ID Attachment Welds (B.2.1.4) program and Water Chemistry (B.2.1.2) program will be used to manage cracking of nickel alloy and stainless steel vessel shell internal attachment welds exposed to reactor coolant and reactor coolant and neutron flux in the Reactor Vessel.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.1.1-95 Steel (with or without Cracking due to cyclic Chapter XI.M5, "BWR No Consistent with NUREG-1801.
The BWR stainless steel cladding) loading Feedwater Nozzle" Feedwater Nozzle (B.2.1.5) program will be feedwater nozzles used to manage cracking of the low alloy exposed to reactor steel feedwater nozzles exposed to reactor coolant coolant in the Reactor Vessel.3.1.1-96 Steel (with or without Cracking due to cyclic Chapter XL.M6, "BWR No Consistent with NUREG-1801.
The BWR stainless steel cladding) loading Control Rod Drive Return Control Rod Drive Return Line Nozzle control rod drive return Line Nozzle" (B.2.1.6) program will be used to manage line nozzles exposed to cracking of the carbon or low alloy steel reactor coolant with stainless steel cladding control rod drive return line nozzles exposed to reactor coolant in the Reactor Vessel.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-36 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-97 Stainless steel and nickel Cracking due to Chapter XI.M7, "BWR No Consistent with NUREG-1 801 with alloy piping, piping stress corrosion Stress Corrosion exceptions.
The BWR Stress Corrosion components, and piping cracking, Cracking," and Chapter Cracking (B.2.1.7) program and Water elements greater than or intergranular stress XI.M2, 'Water Chemistry" Chemistry (B.2.1.2) program will be used to equal to 4 NPS; nozzle corrosion cracking manage cracking of stainless steel and safe ends and associated nickel alloy piping, piping components, and welds piping elements, nozzle safe-ends and associated welds greater than or equal to 4-inch NPS that are exposed to reactor coolant and reactor coolant and neutron flux in the Reactor Vessel and Reactor Coolant Pressure Boundary System.The ASME Section Xl Inservice Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)program has been substituted for the BWR Stress Corrosion (B.2.1.7) program and will be used with the Water Chemistry (B.2.1.2)program to manage cracking of stainless steel valve bodies and pump casings in the Reactor Coolant Pressure Boundary System.An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-37 9 0 Section 3-Aging Managemen iew Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-98 Stainless steel or nickel Cracking due to Chapter XI.M8, "BWR No Consistent with NUREG-1801 with alloy penetrations:
stress corrosion Penetrations," and exceptions.
The BWR Penetrations instrumentation and cracking, Chapter Xl.M2, 'Water (B.2.1.8) program and Water Chemistry standby liquid control intergranular stress Chemistry" (B.2.1.2) program will be used to manage exposed to reactor corrosion cracking, cracking of stainless steel and nickel alloy coolant cyclic loading instrumentation, standby liquid control, and CRD and Incore Monitor vessel penetrations exposed to reactor coolant and reactor coolant and neutron flux in the Reactor Vessel.An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.1.1-99 Cast austenitic stainless Loss of fracture Chapter XI.M9, "BWR No Consistent with NUREG-1801.
The BWR steel; PH martensitic toughness due to Vessel Internals" Vessel Internals (B.2.1.9) program will be stainless steel; thermal aging and used to manage loss of fracture toughness martensitic stainless neutron irradiation of cast austenitic stainless steel and X-750 steel; X-750 alloy reactor embrittlement alloy reactor internal components exposed internal components to reactor coolant and reactor coolant and exposed to reactor neutron flux in the Reactor Vessel Internals.
coolant and neutron flux PH martensitic stainless steels and martensitic stainless steels are not used within the Reactor Vessel Internals.
3.1.1-100 Stainless steel reactor Loss of material due Chapter XI.M9, "BWR No Consistent with NUREG-1801.
The BWR vessel internals to wear Vessel Internals" Vessel Internals (B.2.1.9) program will be components (jet pump used to manage loss of material of wedge surface) exposed stainless steel jet pump assembly wedge to reactor coolant surfaces exposed to reactor coolant and neutron flux in the Reactor Vessel Internals.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-38 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-101 Stainless steel steam Cracking due to flow- Chapter XI.M9, "BWR No Consistent with NUREG-1801.
The BWR dryers exposed to reactor induced vibration Vessel Internals" for Vessel Internals (B.2.1.9) program will be coolant steam dryer used to manage cracking of stainless steel steam dryers exposed to reactor coolant in the Reactor Vessel Internals.
3.1.1-102 Stainless steel fuel Cracking due to Chapter XI.M9, "BWR No Consistent with NUREG-1801 with supports and control rod stress corrosion Vessel Internals," and exceptions.
The BWR Vessel Internals drive assemblies control cracking, Chapter XI.M2, 'Water (B.2.1.9) program and Water Chemistry rod drive housing intergranular stress Chemistry" (B.2.1.2) program will be used to manage exposed to reactor corrosion cracking cracking of stainless steel fuel supports, coolant control rod drive housings, and steam dryers exposed to reactor coolant and reactor coolant and neutron flux in the Reactor Vessel Internals.
An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-39 Section 3 -Aging Managemeneew Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-103 Stainless steel and nickel Cracking due to Chapter XI.M9, "BWR No Consistent with NUREG-1801 with alloy reactor internal stress corrosion Vessel Internals," and exceptions.
The BWR Vessel Internals components exposed to cracking, Chapter XI.M2, 'Water (B.2.1.9) program and Water Chemistry reactor coolant and intergranular stress Chemistry" (B.2.1.2) program will be used to manage neutron flux corrosion cracking, cracking of stainless steel and nickel alloy irradiation-assisted reactor internal components and thermal stress corrosion sleeves exposed to reactor coolant and cracking reactor coolant and neutron flux in the Reactor Vessel and Reactor Vessel Internals.
An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.1.1-104 X-750 alloy reactor Cracking due to Chapter XI.M9, "BWR No Consistent with NUREG-1801 with vessel internal intergranular stress Vessel Internals" for core exceptions.
The BWR Vessel Internals components exposed to corrosion cracking plate, and (B.2.1.9) program and Water Chemistry reactor coolant and Chapter XI.M2, "Water (B.2.1.2) program will be used to manage neutron flux Chemistry" cracking of X-750 alloy reactor internal components exposed to reactor coolant and neutron flux in the Reactor Vessel Internals.
An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-40 Section 3 -Aging Management Review Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-105 Steel piping, piping None None, provided 1) No, if conditions are Not Applicable.
components and piping attributes of the concrete met.element exposed to are consistent with ACI There are no steel piping, piping concrete 318 or ACI 349 (low components, and piping elements exposed water-to-cement ratio, to concrete in the Reactor Vessel, Internals, low permeability, and and Reactor Coolant System.adequate air entrainment) as cited in NUREG-1557, and 2)plant OE indicates no degradation of the concrete 3.1.1-106 Nickel alloy piping, piping None None NA -No AEM or Consistent with NUREG-1 801.components and piping AMP element exposed to air -indoor, uncontrolled, or air with borated water leakage 3.1.1-107 Stainless steel piping, None None NA -No AEM or Consistent with NUREG-1801.
piping components and AMP piping element exposed to gas, concrete, air with borated water leakage, air -indoors, uncontrolled 3.1.1-108 There is no Item Number 3.1.1-108 listed in NUREG-1800 or subsequent ISGs.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-41 Section 3 -Aging Managemen view Results Table 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-109 There is no Item Number 3.1.1-109 listed in NUREG-1800 or subsequent ISGs.3.1.1-110 Any material, piping, Wall thinning due to Chapter XI.M17, "Flow- No Not Applicable.
piping erosion Accelerated Corrosion" There are no piping, piping components, components, and piping and piping elements exposed to reactor reactor coolant coolant that have been identified as susceptible to wall thinning due to erosion in the Reactor Vessel, Internals, and Reactor Coolant System.Piping, piping components, and piping elements in the Reactor Vessel, Internals, and Reactor Coolant System exposed to reactor coolant that are susceptible to wall thinning due to flow-accelerated corrosion are managed by the Flow-Accelerated Corrosion (B.2.1.10) program as described in Item Number 3.1.1-60.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-42 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System Summary of Aging Management Evaluation Table 3.1.2-1 Reactor Coolant Pressure Boundary System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Accumulator Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 C (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 C (B.2.1.21)
Bolting Mechanical Closure Carbon and Low Air- Indoor Cumulative Fatigue TLAA IV.C1.RP-44 3.1.1-11 A, 3 Alloy Steel Uncontrolled (External)
Damage Bolting Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 A Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 A Air with Reactor Cumulative Fatigue TLAA IV.C1 .RP-44 3.1.1-11 A, 3 Coolant Leakage Damage (External)
Loss of Material Bolting Integrity (B.2.1.11)
IV.C1 .RP-42 3.1.1-63 A Loss of Preload Bolting Integrity (B.2.1.11)
IV.C1 .RP-43 3.1.1-67 A High Strength Air with Reactor Cracking Bolting Integrity (B.2.1.11)
V.E.E-03 3.2.1-12 A Low Alloy Steel Coolant Leakage Cumulative Fatigue TLAA IV.Cl RP-44 3.1.1-11 A, 3 Bolting with Yield (External)
Damage Strength of 150 ksi or Greater Loss of Material Bolting Integrity (B.2.1.11)
IV.C1.RP-42 3.1.1-63 A Loss of Preload Bolting Integrity (B.2.1.11)
IV.C1.RP-43 3.1.1-67 A LaSalle County~fton, Units 1 and 2 License Rene W lication.Page 3.1-43 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Stainless Steel Air -Indoor Cumulative Fatigue TLAA IV.C1.RP-44 3.1.1-11 A, 3 Bolting Uncontrolled (External)
Damage Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 A Loss of Preload Bolting Integrity (B.2.1.11)
IV.C1.RP-43 3.1.1-67 A Class 1 Piping, Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Fittings and Branch Uncontrolled (External)
Monitoring of Mechanical Connections
< Components (B.2.1.24)
NPS 4" Reactor Coolant Cracking ASME Section XI Inservice IV.C1.RP-230 3.1.1-39 A (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)One-time Inspection of IV.C1.RP-230 3.1.1-39 A ASME Code Class 1 Small-Bore Piping (B.2.1.23)
Water Chemistry (B.2.1.2)
IV.C1 .RP-230 3.1.1-39 B Cumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3 Damage Loss of Material One-Time Inspection IV.C1.RP-39 3.1.1-31 E, 1 (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.C1 .RP-39 3.1.1-31 D Wall Thinning Flow-Accelerated IV.C1.R-23 3.1.1-60 A Corrosion (B.2.1.10)
Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Uncontrolled (External)
Reactor Coolant Cracking ,SME Section XI Inservice IV.C1.RP-230 3.1.1-39 A (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)One-time Inspection of IV.C1.RP-230 3.1.1-39 A ASME Code Class 1 Small-Bore Piping (B.2.1.23)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-44 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Class I Piping, Pressure Boundary Stainless Steel Reactor Coolant Cracking Water Chemistry (B.2.1.2)
IV.C1.RP-230 3.1.1-39 B Fittings and Branch (Internal)
Cumulative Fatigue TAA IV.C1.R-220 3.1.1-6 A, 3 Connections
< Cum age NPS 4" Damage Loss of Material One-Time Inspection IV.C1.RP-158 3.1.1-79 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.C1 .RP-158 3.1.1-79 B Flow Device Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A (Instrumentation Uncontrolled (External)
Orifices)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Throttle Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Flow Device (Main Throttle Cast Austenitic Steam Cracking One-Time Inspection VIII.B2.SP-98 3.4.1-11 A Steam Line Flow Stainless Steel (B.2.1.21)
Restrictors) (CASS) Water Chemistry (B.2.1.2)
VIII.B2.SP-98 3.4.1-11 B Loss of Material TLAA H, 5 One-Time Inspection VIII.B2.SP-155 3.4.1-16 A, 4 (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-155 3.4.1-16 B Heat Exchanger
-Leakage Boundary Copper Alloy with Air- Indoor None None V.F.EP-10 3.2.1-57 C (EHC Fluid) Tube 15% Zinc or More Uncontrolled (External)
Side Components J LaSalle Countly on, Units 1 and 2 License Rene~ W lication O Page 3.1-45 0 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Leakage Boundary Copper Alloy with Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-76 3.2.1-50 C (EHC Fluid) Tube 15% Zinc or More (B.2.1.26)
Side Components One-Time Inspection V.D2.EP-76 3.2.1-50 C (B.2.1.21)
Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (Motor Oil Coolers) Uncontrolled (External)
Monitoring of Mechanical Shell Side Components (B.2.1.24)
Components Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 C (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 C (B.2.1.21)
Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (Motor Winding Uncontrolled (External)
Monitoring of Mechanical Coolers) Tube Side Components (B.2.1.24)
Components Closed Cycle Cooling Loss of Material Closed Treated Water V.D2.EP-92 3.2.1-30 A Water (Internal)
Systems (B.2.1.13)
Heat Exchanger-Leakage Boundary Copper Alloy with Air- Indoor None None V.F.EP-10 3.2.1-57 C (Motor Winding less than 15% Uncontrolled (External)
Coolers) Tubes Zinc Closed Cycle Cooling Loss of Material Closed Treated Water V.D2.EP-97 3.2.1-32 C Water (Internal)
Systems (B.2.1.13)
Hoses Leakage Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Uncontrolled (External)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D1 .EP-80 3.2.1-50 A (B.2.1.26)
One-Time Inspection V.D1.EP-80 3.2.1-50 A (B.2.1.21)
Piping, piping Leakage Boundary Aluminum Alloy Air- Indoor None None V.F.EP-3 3.2.1-56 A components, and Uncontrolled (External) piping elements LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-46 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item F Management Piping, piping components, and piping elements Leakage Boundary Aluminum Alloy Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis (B.2.1.26)
VII.H2.AP-162 3.3.1-99 A+ i i One-Time Inspection (B.2.1.21)
VII.H2.AP-162 3.3.1-99 A Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
V.E.E-44 3.2.1-40 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 A Corrosion (B.2.1.10)
-Waste Water (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII. E5.AP-281 3.3.1-91 A Copper Alloy with Air -Indoor None None V.F.EP-10 3.2.1-57 A 15% Zinc or More Uncontrolled (External)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-76 3.2.1-50 A (B.2.1.26)
One-Time Inspection V.D2.EP-76 3.2.1-50 A (B.2.1.21)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Lubricating Oil (Internal)
None None VII.J.AP-15 3.3.1-117 A Stainless Steel Air -Indoor Uncontrolled (External)
None None IV.E.RP-04 3.1.1-107 LaSalle Units 1 and 2 License Rene1 plication Page 3.1-47 i Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Leakage Boundary Stainless Steel Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis (B.2.1.26)
V.D1 .EP-80 3.2.1-50 A One-Time Inspection (B.2.1.21)
V.D1 .EP-80 3.2.1-50 A Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A Water Chemistry (B.2.1.2)V.D2.EP-73 3.2.1-17 B Pressure Boundary I Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
V.E.E-44 3.2.1-40 A Reactor Coolant Cumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3 (Internal)
Damage Loss of Material One-Time Inspection IV.C1.RP-39 3.1.1-31 E, 1 (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.C1 .RP-39 3.1.1-31 D Wall Thinning Flow-Accelerated IV.C1.R-23 3.1.1-60 A Corrosion (B.2.1.10)
Steam (Internal)
Cumulative Fatigue TLAA VIII.B2.S-08 3.4.1-1 A, 3 Damage Loss of Material One-Time Inspection VIII.B2.SP-160 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-160 3.4.1-14 B Wall Thinning Flow-Accelerated V.D2.E-07 3.2.1-11 A Corrosion (B.2.1.10)
Treated Water (Internal)
Cumulative Fatigue Damage TLAA V.D2.E-10 3.2.1-1 A, 3 Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11 A LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-48 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Pressure Boundary Stainless Steel Air -Indoor Uncontrolled (External)
None None IV.E.RP-04 3.1.1-107 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D1 .EP-80 3.2.1-50 A (B.2.1.26)
One-Time Inspection V.D1.EP-80 3.2.1-50 A (B.2.1.21)
Reactor Coolant Cracking BWR Stress Corrosion IV.C1 .R-20 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.C1 .R-20 3.1.1-97 B Cumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3 Damage Loss of Material One-Time Inspection IV.C1.RP-158 3.1.1-79 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.C1 .RP-158 3.1.1-79 B Treated Water (Internal)
Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 3 Damage Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Treated Water > 140 F (Internal)
Cracking BWR Stress Corrosion Cracking (B.2.1.7)V.D2.E-37 3.2.1-54 A Water Chemistry (B.2.1.2)V.D2.E-37 3.2.1-54 B Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 3 Damage I Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A+ i i _Water Chemistry (B.2.1 .2's V.D2.EP-73 3.2.1-17 B..... ........... (B ... ....D ..... ..3.2. 1 -17..Pump Casing Leakage Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (EHC Skid) Uncontrolled (External)
Monitoring of Mechanical CompoCnents (B.2.1.24)
LaSalle Countwion, Units 1 and 2 License ReneWV plication 0 Page 3.1-49 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing Leakage Boundary Gray Cast Iron Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (EHC Skid) (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Pump Casing Pressure Boundary Cast Austenitic Air- Indoor None None IV.E.RP-04 3.1.1-107 A (RRP) Stainless Steel Uncontrolled (External)(CASS) Reactor Coolant Cracking ASME Section Xl Inservice IV.C1.R-20 3.1.1-97 E, 2 (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.C1 .R-20 3.1.1-97 D Cumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3 Damage Loss of Fracture ASME Section Xl Inservice IV.C1.R-08 3.1.1-38 A Toughness Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Loss of Material One-Time Inspection IV.C1.RP-158 3.1.1-79 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.C1 .RP-158 3.1.1-79 B RPV Flange Leak Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Detection Line Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Reactor Coolant Cumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3 (Internal)
Damage Loss of Material One-Time Inspection IV.C1.RP-39 3.1.1-31 E, 1 (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.C1 .RP-39 3.1.1-31 D Tanks (EHC Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Reservoir)
Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-50 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Tanks (EHC Leakage Boundary Carbon Steel Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 C Reservoir) (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 C (B.2.1.21)
Valve Body Leakage Boundary Aluminum Alloy Air -Indoor Uncontrolled (External)
None None V.F.EP-3 3.2.1-56 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis (B.2.1.26)
VII.H2.AP-162 3.3.1-99 A One-Time Inspection (B.2.1.21)
VII.H2.AP-162 3.3.1-99 A I I I + I I Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Comoonents (B.2.1.24)
V.E.E-44 3.2.1-40 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16 A+ I I Water Chemistry (B.2.1.2)V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11 A Copper Alloy with Air -Indoor None None V.F.EP-10 3.2.1-57 A 15% Zinc or More Uncontrolled (External)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-76 3.2.1-50 A (B.2.1.26)
One-Time Inspection V.D2.EP-76 3.2.1-50 A (B.2.1.21) i Stainless Steel Air -Indoor Uncontrolled (External)
None None IV.E.RP-04 3.1.1-107 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis (B.2.1.26)
V.D1 .EP-80 3.2.1-50 A LaSalle Countyaiion, Units 1 and 2 License Rene W lication_M_ d Page 3.1-51 S Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Stainless Steel Lubricating Oil (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D1 .EP-80 3.2.1-50 A F 4 4 4 Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A Water Chemistry (B.2.1.2)V.D2.EP-73 i i 3.2.1-17 B+ 4 F + -- 3.2.-17 B Pressure Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
V.E.E-44 3.2.1-40 A Reactor Coolant Cumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3 (Internal)
Damage Loss of Material One-Time Inspection IV.C1.RP-39 3.1.1-31 E, 1 (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.C1 .RP-39 3.1.1-31 D Wall Thinning Flow-Accelerated IV.C1.R-23 3.1.1-60 A Corrosion (B.2.1.10)
Steam (Internal)
Cumulative Fatigue TLAA VIII.B2.S-08 3.4.1-1 A, 3 Damage Loss of Material One-Time Inspection VIII.B2.SP-160 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-160 3.4.1-14 B Wall Thinning Flow-Accelerated V.D2.E-07 3.2.1-11 A Corrosion (B.2.1.10)
Treated Water (Internal:
Cumulative Fatigue Damaae TLAA V.D2.E-10 3.2.1-1 A, 3 Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11 A Cast Austenitic Air -Indoor None None IV.E.RP-04 3.1.1-107 A Stainless Steel Uncontrolled (External)(CASS)LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-52 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Cast Austenitic Stainless Steel (CASS)Reactor Coolant (Internal)
Cracking ASME Section Xl Inservice Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)IV.C1 .R-20 3.1.1-97 E, 2 4 .1.Water Chemistry (B.2.1.2)IV.C1.R-20 3.1.1-97 B Cumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3 Damage Loss of Fracture ASME Section XI Inservice IV.C1.R-08 3.1.1-38 A Toughness Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)
I Loss of Material One-Time Inspection (B.2.1.21)
IV.C1 .RP-158 3.1.1-79 A Water Chemistry (B.2.1.2)IV.C1.RP-158 3.1.1-79 B Stainless Steel Air -Indoor Uncontrolled (External)
None None IV.E.RP-04 3.1.1-107 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D1 .EP-80 3.2.1-50 A (B.2.1.26)
One-Time Inspection V.D1.EP-80 3.2.1-50 A (B.2.1.21)
Reactor Coolant Cracking ASME Section Xl Inservice IV.C1.R-20 3.1.1-97 E, 2 (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.C1.R-20 3.1.1-97 B Cumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3 Damage Loss of Material One-Time Inspection IV.C1.RP-158 3.1.1-79 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.C1 .RP-158 3.1.1-79 B Treated Water (Internal)
Cumulative Fatigue Damaqe TLAA VII.E3.A-62 3.3.1-2 A, 3 LaSalle County on, Units 1 and 2 License Rene .W lication Page 3.1-53 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Stainless Steel Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-54 Section 3 -Aging Management Review Results Table 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1 801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The One-Time Inspection (B.2.1.21) program is substituted to manage the aging effects applicable to this component type, material and environment combination.
: 2. The ASME Section Xl Inservice Inspection, Subsections IWB, IWC and IWD (B.2.1.1) program is substituted to manage the aging effects applicable to this component type, material and environment combination.
: 3. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.4. The internal venturi section of each main steam line flow restrictor is fabricated from centrifugally cast low molybdenum content SA-351 Type CF8 CASS material.
Therefore, these components are not susceptible to loss of fracture toughness due to thermal aging embrittlement.
: 5. The TLAA designation in the Aging Management Program column indicates that erosion of the main steam line flow restrictors is evaluated in Section 4.7.LaSalle Countyiltion, Units 1 and 2 Page 3.1-55 License Rene lication Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel Summary of Aging Management Evaluation Table 3.1.2-2 Reactor Vessel Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting (Closure Mechanical Closure High Strength Air with Reactor Cracking Reactor Head Closure IV.A1.RP-51 3.1.1-91 B Studs -RPV) Low Alloy Steel Coolant Leakage Stud Bolting (B.2.1.3)Bolting with Yield (External)
Cumulative Fatigue TLAA IV.A1.RP-201 3.1.1-1 A, 2 Strength of 150 Damage FtuTIV .R231-1, ksi or Greater Loss of Material Reactor Head Closure IV.A1.RP-165 3.1.1-91 B Stud Bolting (B.2.1.3)Bolting (Head Mechanical Closure Carbon and Low Air with Reactor Cumulative Fatigue TLAA IV.C1.RP-44 3.1.1-11 A, 2 Spray, CRD Alloy Steel Coolant Leakage Damage Housing, Head Bolting (External)
Loss of Material Bolting Integrity (B.2.1.11)
IV.C1.RP-42 3.1.1-63 A Vent, Spare Nozzle) Loss of Preload Bolting Integrity (B.2.1.11)
IV.C1 .RP-43 3.1.1-67 A N-1 Nozzle Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 1, 1 (Recirculation Alloy Steel with Uncontrolled (External)
Outlet) Stainless Steel Reactor Coolant Cracking ,SME Section XI Inservice IV.A1.RP-371 3.1.1-30 C Cladding (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.Al .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-56 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N-1 Nozzle Pressure Boundary Carbon or Low Reactor Coolant Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (Recirculation Alloy Steel with (Internal) (B.2.1.21)
Outlet) Stainless Steel Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B Cladding N-1 Nozzle Safe Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 A Ends and Welds Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.Al .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.Al .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B Stainless Steel Air -Indoor None None IV.E.RP-04 3.1.1-107 A Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.Al.R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.A1.R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N-2 Nozzle Pressure Boundary Carbon or Low Air- Indoor None None V.E.E-44 3.2.1-40 1, 1 (Recirculation Inlet) Alloy Steel with Uncontrolled (External)
Stainless Steel Reactor Coolant Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 C Cladding (Internal)
Inspection, Subsections IWB, IWC, and IWD I__I (B.2.1.1)LaSalle Countvgton, Units 1 and 2 License Rene V P lication 0 Page 3.1-57 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N-2 Nozzle Pressure Boundary Carbon or Low Reactor Coolant Cracking Water Chemistry (B.2.1.2)
IV.A1.RP-371 3.1.1-30 D (Recirculation Inlet) Alloy Steel with (Internal)
Cumulative Fatigue TLAA lV.A1.R-04 3.1.1-7 A, 2 Stainless Steel Damage Cladding Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N-2 Nozzle Safe Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 A Ends and Welds Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.A1.R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.A1 .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.AI.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1 .RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.A1 .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.A1 .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1 .RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A .RP-157 3.1.1-85 B N-2 Nozzle Direct Flow Stainless Steel Reactor Coolant Cracking BWR Vessel Internals IV.B1 .R-100 3.1.1-103 C Thermal Sleeve (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 D LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-58 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N-2 Nozzle Direct Flow Stainless Steel Reactor Coolant Loss of Material One-Time Inspection IV.Al .RP-157 3.1.1-85 A Thermal Sleeve (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N-3 Nozzle (Steam Pressure Boundary Low Alloy Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1 Outlet) Uncontrolled (External)
Steam (Internal)
Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1 .RP-50 3.1.1-84 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-50 3.1.1-84 B N-3 Nozzle Safe Pressure Boundary Carbon Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1 Ends and Welds Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 (Internal)
Damage Loss of Material One-Time Inspection IV.A1 .RP-50 3.1.1-84 C (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-50 3.1.1-84 D N-4 Nozzle Pressure Boundary Low Alloy Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1 (Feedwater)
Uncontrolled (External)
Reactor Coolant Cracking BWR Feedwater Nozzle IV.Al.R-65 3.1.1-95 A (Internal) (B.2.1.5)Cumulative Fatigue TLAA IV.Al .R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.Al .RP-50 3.1.1-84 C (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-50 3.1.1-84 D N-4 Nozzle Safe Pressure Boundary Carbon Steel Air -Indoor None None V.E.E-44 3.2.1-40 I, 1 Ends and Welds Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 (Internal)
Damage Loss of Material One-Time Inspection IV.A1 .RP-50 3.1.1-84 C I_ (B.2.1.21)
LaSalle Count Units 1 and 2 License Rene plication Page 3.1-59 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N-4 Nozzle Safe Pressure Boundary Carbon Steel Reactor Coolant Loss of Material Water Chemistry (B.2.1.2)
IV.A1.RP-50 3.1.1-84 D Ends and Welds (Internal)
Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 I,'1 Alloy Steel with Uncontrolled (External)
Stainless Steel Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Cladding (Internal)
Damage Loss of Material One-Time Inspection IV.Al.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1 .RP-157 3.1.1-85 B Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.A1 .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.Al .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.Al.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N-4 Nozzle Direct Flow Stainless Steel Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 C Thermal Sleeve (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1.R-100 3.1.1-103 D Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N-5 Nozzle (Low Pressure Boundary Carbon or Low Air- Indoor None None V.E.E-44 3.2.1-40 I,1 Pressure Core Alloy Steel with Uncontrolled (External)
Spray) Stainless Steel I Cladding I I I I I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-60 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N-5 Nozzle (Low Pressure Boundary Carbon or Low Reactor Coolant Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 C Pressure Core Alloy Steel with (Internal)
Inspection, Subsections Spray) Stainless Steel IWB, IWC, and IWD Cladding (B.2.1.1)Water Chemistry (B.2.1.2)
IV.A1.RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N-5 Nozzle Safe Pressure Boundary Carbon Steel Air -Indoor None None V.E.E-44 3.2.1-40 1, 1 End Extension Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 (Internal)
Damage Loss of Material One-Time Inspection IV.A1 .RP-50 3.1.1-84 C (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-50 3.1.1-84 D N-5 Nozzle Safe Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 A Ends and Welds Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.Al .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.Al .R-68 3.1.1-97 B Cumulative Fatigue TLAA IVA1 .R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N-5 Nozzle Direct Flow Stainless Steel Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 C Thermal Sleeve (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1.R-100 3.1.1-103 D Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A I____ ___ (B.2.1.21)
I I I LaSalle Count lYIon, Units 1 and 2 License Renewplication Page 3.1-61 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N-5 Nozzle Direct Flow Stainless Steel Reactor Coolant Loss of Material Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B Thermal Sleeve N-5 Thermal Direct Flow Nickel Alloy Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 C Sleeve Extension (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 D Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N-6 Nozzle (RHR / Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 I, 1 LPCI) Alloy Steel with Uncontrolled (External)
Stainless Steel Reactor Coolant and Cracking ASME Section Xl Inservice IV.A1.RP-371 3.1.1-30 C Cladding Neutron Flux (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.A1.RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Fracture Reactor Vessel IV.A1.RP-227 3.1.1-14 A Toughness Surveillance (B.2.1.20)
TLAA IV.A1.R-67 3.1.1-13 A, 3 Loss of Material One-Time Inspection IV.Al.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1 .RP-1 57 3.1.1-85 B N-6 Nozzle Safe Pressure Boundary Carbon Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1 End Extensions Uncontrolled (External)
Reactor Coolant and Cumulative Fatigue TLAA IV.A1 .R-04 3.1.1-7 A, 2 Neutron Flux (Internal)
Damage Loss of Material One-Time Inspection IV.Al .RP-50 3.1.1-84 C (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-50 3.1.1-84 D LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-62 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N-6 Nozzle Safe Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 A Ends and Welds Uncontrolled (External)
Reactor Coolant and Cracking BWR Stress Corrosion IV.Al .R-68 3.1.1-97 A Neutron Flux (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.A1 .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1 .RP-157 3.1.1-85 B N-6 Nozzle Pressure Boundary Nickel Alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 C Thermal Sleeve Neutron Flux (B.2.1.9)Extension (Unit 2 Water Chemistry (B.2.1.2)
IV.B1.R-100 3.1.1-103 D Only)Loss of Material One-Time Inspection IV.A1 .RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N-6 Thermal Direct Flow Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-100 3.1.1-103 C Sleeve Neutron Flux (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 D Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1 .RP-157 3.1.1-85 B N-7 Nozzle (Top Pressure Boundary Low Alloy Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1 Head Spray / RCIC Uncontrolled (External)
-Flanged) Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 (Internal)
Damage Loss of Material One-Time Inspection IV.A .RP-50 3.1.1-84 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1 .RP-50 3.1.1-84 B LaSalle Countyl~ion, Units 1 and 2 License ReneW plication Page 3.1-63 0 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N-7 Nozzle Flange Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Uncontrolled (External)
Reactor Coolant Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 C (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.Al .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N-7 Nozzle Welds Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.Al .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.Al .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N-8 Nozzle (Top Pressure Boundary LowAlloy Steel Air- Indoor None None V.E.E-44 3.2.1-40 I,'1 Head Vent -Uncontrolled (External)
Flanged) Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 (Internal)
Damage Loss of Material One-Time Inspection IV.A1.RP-50 3.1.1-84 A (B.2.1.21)
I Water Chemistry (B.2.1.2)
IV.A1.RP-50 3.1.1-84 B N-8 Nozzle Flange Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A I_ __ Uncontrolled (External)
_LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-64 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N-8 Nozzle Flange Pressure Boundary Stainless Steel Reactor Coolant Cracking BWR Stress Corrosion IV.Al.R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.A1.R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1 .R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.Al .RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N-8 Nozzle Welds Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.Al .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.Al .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.AI.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N-9 Nozzle (Jet Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 1, 1 Pump Alloy Steel with Uncontrolled (External)
_Instrumentation)
Stainless Steel Reactor Coolant Cracking ,SME Section XI Inservice IV.A1.RP-371 3.1.1-30 C Cladding (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.Al .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.Al .R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.Al .RP-157 3.1.1-85 A (B.2.1.21)
_Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B LaSalle County, on, Units 1 and 2 License Rene~W lication Page 3.1-65 0 S Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N-9 Nozzle Safe Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 A End and Welds Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.Al .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.Al .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.A1 .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.A1 .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N10 Nozzle (CRD Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 I,1 Hydraulic System Alloy Steel with Uncontrolled (External)
Return Line -Stainless Steel Reactor Coolant Cracking BWR Control Rod Drive IV.Al .R-66 3.1.1-96 A Capped) Cladding (Internal)
Return Line Nozzle (B.2.1.6)ASME Section Xl Inservice IV.A1.RP-371 3.1.1-30 C Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (8.2.1.2)
IV.Al .RP-371 3.1.1-30 D LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-66 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N10 Nozzle (CRD Pressure Boundary Carbon or Low Reactor Coolant Cumulative Fatigue TLAA IV.AI.R-04 3.1.1-7 A, 2 Hydraulic System Alloy Steel with (Internal)
Damage Return Line -Stainless Steel Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A Capped) Cladding (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N10 Nozzle Cap Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 A and Welds Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.Al .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.A1.R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.Al.RP-1 57 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al.RP-157 3.1.1-85 B Nl1 Nozzle (Core Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 A Differential Uncontrolled (External)
Pressure and Reactor Coolant Cracking BWR Penetrations IV.Al.RP-369 3.1.1-98 A Liquid Control) (Internal) (B.2.1.8)Water Chemistry (B.2.1.2)
IV.A1.RP-369 3.1.1-98 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N11 Nozzle Welds Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A I_ Uncontrolled (External)
LaSalle Countv11110on, Units 1 and 2 License ReneW lication.Page 3.1-67 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management NI1 Nozzle Welds Pressure Boundary Nickel Alloy Reactor Coolant Cracking ASME Section XI Inservice IV.Al.RP-371 3.1.1-30 C (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.Al .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.Al.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N12 Nozzle (Water Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Level Uncontrolled (External)
Instrumentation
-Reactor Coolant and Cracking BWR Penetrations IV.Al.RP-369 3.1.1-98 A 366" Elevation)
Neutron Flux (Internal) (B.2.1.8)Water Chemistry (B.2.1.2)
IV.A1 .RP-369 3.1.1-98 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.Al.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N12 Nozzle Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Extension and Uncontrolled (External)
Welds Reactor Coolant and Cracking ,SME Section Xl Inservice IV.A1.RP-371 3.1.1-30 C Neutron Flux (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.Al.RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-68 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N12 Nozzle Pressure Boundary Nickel Alloy Reactor Coolant and Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A Extension and Neutron Flux (Internal) (B.2.1.21)
Welds Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Uncontrolled (External)
Reactor Coolant and Cracking ASME Section XI Inservice IV.Al .RP-371 3.1.1-30 C Neutron Flux (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.Al .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (8.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N13 Nozzle (Water Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Level Uncontrolled (External)
Instrumentation
-Reactor Coolant Cracking BWR Penetrations IV.Al.RP-369 3.1.1-98 A 517" Elevation) (Internal) (B.2.1.8)Water Chemistry (B.2.1.2)
IV.Al .RP-369 3.1.1-98 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
[Water Chemistry (B.2.1.2)
IVA1 .RP-157 3.1.1-85 B N13 Nozzle Pressure Boundary Stainless Steel Air -Indoor None None IV.E.RP-04 3.1.1-107 A Extension Uncontrolled (External)
LaSalle Countygftion, Units 1 and 2 License ReneW plication.Page 3.1-69 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N13 Nozzle Pressure Boundary Stainless Steel Reactor Coolant Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 C Extension (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.Al .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N13 Nozzle Welds Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Uncontrolled (External)
Reactor Coolant Cracking ASME Section XI Inservice IV.Al.RP-371 3.1.1-30 C (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.Al .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Uncontrolled (External)
Reactor Coolant Cracking ,SME Section XI Inservice IV.A1.RP-371 3.1.1-30 C (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.A1.RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-70 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N13 Nozzle Welds Pressure Boundary Stainless Steel Reactor Coolant Loss of Material Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B (Internal)
N14 Nozzle (Water Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Level Uncontrolled (External)
Instrumentation
-Reactor Coolant Cracking BWR Penetrations IV.A1.RP-369 3.1.1-98 A 599" Elevation) (Internal) (B.2.1.8)Water Chemistry (B.2.1.2)
IV.A1.RP-369 3.1.1-98 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.Al .RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N14 Nozzle Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Extension Uncontrolled (External)
Reactor Coolant Cracking ASME Section XI Inservice IV.Al .RP-371 3.1.1-30 C (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IVA1 .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.AI.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N14 Nozzle Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Extension Welds Uncontrolled (External)
Reactor Coolant Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 C (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.A1.RP-371 3.1.1-30 D LaSalle Countlifion, Units 1 and 2 License ReneW plication Page 3.1-71 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N14 Nozzle Pressure Boundary Nickel Alloy Reactor Coolant Cumulative Fatigue TLAA IV.Al .R-04 3.1.1-7 A, 2 Extension Welds (Internal)
Damage Loss of Material One-Time Inspection IV.A1 RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1 .RP-157 3.1.1-85 B N15 Nozzle Pressure Boundary Carbon Steel Air -Indoor None None V.E.E-44 3.2.1-40 1, 1 (Bottom Head Uncontrolled (External)
Drain) Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 (Internal)
Damage Loss of Material One-Time Inspection IV.A1 .RP-50 3.1.1-84 C (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-50 3.1.1-84 D Carbon or Low Air- Indoor None None V.E.E-44 3.2.1-40 1, 1 Alloy Steel with Uncontrolled (External)
Nickel Alloy Reactor Coolant Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 C Cladding (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.Al .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N16 Nozzle (High Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 1, 1 Pressure Core Alloy Steel with Uncontrolled (External)
Spray) Stainless Steel Cladding LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-72 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N16 Nozzle (High Pressure Boundary Carbon or Low Reactor Coolant Cracking ,SME Section XI Inservice IV.Al.RP-371 3.1.1-30 C Pressure Core Alloy Steel with (Internal)
Inspection, Subsections Spray) Stainless Steel IWB, IWC, and IWD Cladding (B.2.1.1)Water Chemistry (B.2.1.2)
IV.A1 .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1 .RP-157 3.1.1-85 B N16 Nozzle Safe Pressure Boundary Carbon Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1 End Extensions Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 (internal)
Damage Loss of Material One-Time Inspection IV.A1 .RP-50 3.1.1-84 C (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-50 3.1.1-84 D N16 Nozzle Safe Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Ends and Welds Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.A1 .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)CumulativeFatigueWater Chemistry (B.2.1.2)
IV.A1 .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N16 Thermal Direct Flow Stainless Steel Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 C Sleeve (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1.R-100 3.1.1-103 D Loss of Material One-Time Inspection IV.Al.RP-157 3.1.1-85 A I__ _(B.2.1.21)
I LaSalle Count.giion, Units 1 and 2 License ReneW plication 0 Page 3.1-73 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N16 Thermal Direct Flow Stainless Steel Reactor Coolant Loss of Material Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B Sleeve N16 Thermal Direct Flow Nickel Alloy Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 C Sleeve Extension (B.2.1.9)(Unit 2 Only) Water Chemistry (B.2.1.2)
IV.B1.R-100 3.1.1-103 D Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N17 Nozzle (Seal Pressure Boundary Carbon Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1 Leak Detection)
Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1 .R-04 3.1.1-7 A, 2 (Internal)
Damage Loss of Material One-Time Inspection IV.A1 .RP-50 3.1.1-84 C (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1 .RP-50 3.1.1-84 D Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Uncontrolled (External)
Reactor Coolant Cracking ,SME Section XI Inservice IV.A1.RP-371 3.1.1-30 C (Internal)
Inspection, Subsections IWB, IWC, and IWD (1.2.1.1)Water Chemistry (B.2.1.2)
IV.Al .RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1 .R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1 .RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1 .RP-157 3.1.1-85 B N18 (Top Head Pressure Boundary Low Alloy Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1 Spare -Flanged) Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2_ _ _ (Internal)
Damage LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-74 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N18 (Top Head Pressure Boundary Low Alloy Steel Reactor Coolant Loss of Material One-Time Inspection IV.AI.RP-50 3.1.1-84 C Spare -Flanged) (Internal) (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-50 3.1.1-84 D Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.Al .R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.Al .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.Al .R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.Al.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B N18 Nozzle Flange Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Uncontrolled (External)
Reactor Coolant Cracking BWR Stress Corrosion IV.A1.R-68 3.1.1-97 A (Internal)
Cracking (B.2.1.7)Water Chemistry (B.2.1.2)
IV.Al .R-68 3.1.1-97 B Cumulative Fatigue TLAA IV.AI.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N19 CRD Nozzle Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A (Housing and Uncontrolled (External)
Flange) Reactor Coolant Cracking BWR Penetrations IV.Al.RP-369 3.1.1-98 A (B.2.1.8)Water Chemistry (B.2.1.2)
IV.A .RP-369 3.1.1-98 B Cumulative Fatigue TLAA IV.Al .R-04 3.1.1-7 A, 2 Damage LaSalle Units 1 and 2 License Rene p lication.1111 A Page 3.1-75 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N19 CRD Nozzle Pressure Boundary Stainless Steel Reactor Coolant Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (Housing and (B.2.1.21)
Flange) Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N19 CRD Nozzle Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 A (Welds) Uncontrolled (External)
Reactor Coolant Cracking BWR Penetrations IV.Al .RP-369 3.1.1-98 A (B.2.1.8)Water Chemistry (B.2.1.2)
IV.A1.RP-369 3.1.1-98 B Cumulative Fatigue TLAA IV.Al.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.Al.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B N19 CRD Nozzles Pressure Boundary Nickel Alloy Reactor Coolant Cracking BWR Penetrations IV.Al.RP-369 3.1.1-98 A (Stub Tubes) (Internal) (B.2.1.8)Water Chemistry (B.2.1.2)
IV.A1.RP-369 3.1.1-98 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (8.2.1.2)
IV.A1.RP-157 3.1.1-85 B N20 Incore Monitor Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 A Nozzles (Housing Uncontrolled (External) and Flange) Reactor Coolant Cracking BWR Penetrations IV.Al .RP-369 3.1.1-98 A (B.2.1.8)Water Chemistry (B.2.1.2)
IV.Al .RP-369 3.1.1-98 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-76 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management N20 Incore Monitor Pressure Boundary Stainless Steel Reactor Coolant Loss of Material Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B Nozzles (Housing and Flange)Reactor Vessel Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 1, 1 (Bottom Head and Alloy Steel with Uncontrolled (External)
Welds) Stainless Steel Reactor Coolant Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 C Cladding (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.A1.RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B Reactor Vessel Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 I, 1 (Shell, Lower Alloy Steel with Uncontrolled (External)
Flange, and Welds) Stainless Steel Reactor Coolant and Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 C Cladding Neutron Flux (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.A1.RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Fracture Reactor Vessel IV.A1.RP-227 3.1.1-14 A Toughness Surveillance (B.2.1.20)
TLAA IV.A1.R-62 3.1.1-13 A, 3 Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A____ (B.2.1.21)
LaSalle Countv~ton, Units 1 and 2 License Rene lication.Page 3.1-77 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Reactor Vessel Pressure Boundary Carbon or Low Reactor Coolant and Loss of Material Water Chemistry (B.2.1.2)
IV.Al.RP-157 3.1.1-85 B (Shell, Lower Alloy Steel with Neutron Flux (Internal)
Flange, and Welds) Stainless Steel Cladding Reactor Vessel Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 I, 1 (Top Head, Upper Alloy Steel with Uncontrolled (External)
Flange, and Welds) Stainless Steel Reactor Coolant Cracking ASME Section Xl Inservice IV.A1.RP-371 3.1.1-30 C Cladding (Internal)
Inspection, Subsections IWB, IWC, and IWD (B.2.1.1)Water Chemistry (B.2.1.2)
IV.A1.RP-371 3.1.1-30 D Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A .RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 B Reactor Vessel Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A External Uncontrolled (External)
Monitoring of Mechanical Attachments Components (B.2.1.24)(Refueling Bellows Treated Water Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 C Support) (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 D Structural Support Carbon Steel Air- Indoor Cumulative Fatigue TLAA IV.A1.R-70 3.1.1-4 A, 2 Uncontrolled (External)
Damage Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Monitoring of Mechanical I_ I_ Components (B.2.1.24)_
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-78 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Reactor Vessel Structural Support Carbon Steel Air- Indoor Cumulative Fatigue TLAA IV.A1.R-70 3.1.1-4 A, 2 External Uncontrolled (External)
Damage Attachments Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (Support Skirt and Monitoring of Mechanical Stabilizer Bracket) Components (B.2.1.24)
Reactor Vessel Structural Support to Nickel Alloy Reactor Coolant Cracking BWR Vessel ID IV.A1.R-64 3.1.1-94 A Internal maintain core Attachment Welds Attachments configuration and (B.2.1.4)flow distribution Water Chemistry (B.2.1.2)
IV.A1 .R-64 3.1.1-94 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.Al.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A .RP-157 3.1.1-85 B Stainless Steel Reactor Coolant Cracking BWR Vessel ID IV.A1.R-64 3.1.1-94 A Attachment Welds (B.2.1.4)Water Chemistry (B.2.1.2)
IV.A1.R-64 3.1.1-94 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A .RP-157 3.1.1-85 B Reactor Coolant and Cracking BWR Vessel ID IV.A1.R-64 3.1.1-94 A Neutron Flux Attachment Welds (B.2.1.4)Water Chemistry (B.2.1.2)
IV.A1.R-64 3.1.1-94 B Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2 Damage LaSalle Countvjlon, Units 1 and 2 License Rene Iplication
.Page 3.1-79 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Reactor Vessel Structural Support to Stainless Steel Reactor Coolant and Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A Internal maintain core Neutron Flux (B.2.1.21)
Attachments configuration and flow distribution Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-80 Section 3 -Aging Management Review Results Table 3.1.2-2 Reactor Vessel (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. During power operation the insulated reactor vessel, nozzles, and safe end components have external temperature greater than 212 degrees F and are at a higher temperature than the air-indoor (uncontrolled) environment.
During plant shutdown the containment atmosphere is normally below the dewpoint temperature.
Therefore, wetting due to condensation and moisture accumulation will not occur during power operation or plant shutdown and loss of material due to general corrosion does not apply.2. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.3. The TLAA designation in the Aging Management Program column indicates loss of fracture toughness due to neutron embrittlement of this component is evaluated in Section 4.2.LaSalle Countvjion, Units 1 and 2 License ReneW plication O Page 3.1-81 Section 3 -Aging Management Review Results Table 3.1.2-3 Reactor Vessel Internals Summary of Aging Management Evaluation Table 3.1.2-3 Reactor Vessel Internals Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Core Shroud Structural Support to Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-92 3.1.1-103 A (Including Repairs) maintain core Neutron Flux (B.2.1.9)and Core Plate: configuration and Water Core Shroud flow distribution Chemistry (B.2.1.2)
IV.B1 .R-92 (Upper, Central, Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1 Lower) Damage Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Core Shroud Structural Support to Nickel Alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-96 3.1.1-103 A (Including Repairs) maintain core Neutron Flux (B.2.1.9)and Core Plate: configuration and Water Chemistry (B.2.1.2)
V.81.R-96 3.1.1-103 Shroud Support flow distribution Structure (Shroud Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1 Support Cylinder, Damage Shroud Support Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 Plate, Shroud (B.2.1.9)Support Legs and Gussets) Water Chemistry (B.2.1.2)
IV.B1.RP-26 3.1.1-43 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-82 Section 3 -Aging Management Review Results Table 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Core Shroud and Direct Flow Nickel Alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-94 3.1.1-29 E, 2 Core Plate: Neutron Flux (B.2.1.9)Access Hole Cover (Welded Covers) Water Chemistry (B.2.1.2)
IV.B1 .R-94 3.1.1-29 B Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1.RP-26 3.1.1-43 B Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-97 3.1.1-103 A Neutron Flux (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1.R-97 3.1.1-103 B Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1.RP-26 3.1.1-43 B Core Shroud and Structural Support to Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-93 3.1.1-103 A Core Plate: Core maintain core Neutron Flux (B.2.1.9)Plate, Core Plate configuration and Water Chemistry (B.2.1.2)
IV.B1 .R-93 3.1.1-103 B Bolts flow distribution Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1 Damage Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (8.2.1.9)Water Chemistry (B.2.1.2)
IV.B1.RP-26 3.1.1-43 B Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-93 3.1.1-103 A Bolting Neutron Flux (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .R-93 3.1.1-103 B Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Loss of Preload TLAA H, 3 LaSalle County ion, Units 1 and 2 License ReneW plication.Page 3.1-83 Section 3 -Aging Management Review Results Table 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Core Shroud and Direct Flow Cast Austenitic Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-93 3.1.1-103 A Core Plate: LPCI Stainless Steel Neutron Flux (B.2.1.9)Coupling (CASS) Water Chemistry (B.2.1.2)
IV.B1 .R-93 3.1.1-103 B Loss of Fracture BWR Vessel Internals IV.B1.RP-219 3.1.1-99 C Toughness (B.2.1.9)Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1.RP-26 3.1.1-43 B Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-97 3.1.1-103 A Neutron Flux (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .R-97 3.1.1-103 B Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1 Damage Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B X-750 alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1.RP-381 3.1.1-104 A Neutron Flux (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-381 3.1.1-104 B Loss of Fracture BWR Vessel Internals IV.B1 .RP-200 3.1.1-99 A Toughness (B.2.1.9)Loss of Material BWR Vessel Internals IV.B1 .RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1.RP-26 3.1.1-43 B Core Spray Lines Direct Flow Cast Austenitic Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-99 3.1.1-103 A and Spargers:
Stainless Steel Neutron Flux (B.2.1.9)Core Spray Lines (CASS)(Headers), Spray Water Chemistry (8.2.1.2)
IV.B1 .R-99 3.1.1-103 8 Rings, Spray Nozzles LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-84 Section 3 -Aging Management Review Results Table 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Core Spray Lines Direct Flow Cast Austenitic Reactor Coolant and Loss of Fracture BWR Vessel Internals IV.B1 .RP-219 3.1.1-99 C and Spargers:
Stainless Steel Neutron Flux Toughness (B.2.1.9)Core Spray Lines (CASS) Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (Headers), Spray (B.2.1.9)Rings, Spray Nozzles Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-99 3.1.1-103 A Neutron Flux (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .R-99 3.1.1-103 B Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1 Damage Loss of Material BWR Vessel Internals IV.B1 .RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Fuel Supports and Structural Support to Cast Austenitic Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-104 3.1.1-102 A Control Rod Drive maintain core Stainless Steel Neutron Flux (B.2.1.9)Assemblies:
configuration and (CASS) Water Chemistry (B.2.1.2)
IV.B1 .R-104 3.1.1-102 B Orificed Fuel flow distribution Support Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1 Damage Loss of Fracture BWR Vessel Internals IV.B1 .RP-220 3.1.1-99 A Toughness (B.2.1.9)Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (8.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Throttle Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-104 3.1.1-102 A Neutron Flux (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .R-104 3.1.1-102 B LaSalle Countvdtion, Units I and 2 License ReneW plication* Page 3.1-85 0 Section 3 -Aging Management Review Results Table 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Fuel Supports and Throttle Stainless Steel Reactor Coolant and Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 Control Rod Drive Neutron Flux (B.2.1.9)Assemblies:
Orificed Fuel Water Chemistry (B.2.1.2)
V.B1.RP-26 3.1.1-43 B Support Instrumentation:
Structural Support to Stainless Steel Air/Gas -Dry (Internal)
None None IV.E.RP-07 3.1.1-107 C Intermediate maintain core Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-105 3.1.1-103 A Range Monitor configuration and Neutron Flux (B.2.1.9)(IRM) Dry Tubes, flow distribution Source Range Water Chemistry (B.2.1.2)
IV.B1 .R-105 3.1.1-103 B Monitor (SRM) Dry Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1 Tubes, Incore Damage Neutron Flux Monitor Guide Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 Tubes (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Jet Pump Direct Flow Cast Austenitic Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-100 3.1.1-103 A Assemblies:
Stainless Steel Neutron Flux (B.2.1.9)Castings (CASS) Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 B Loss of Fracture BWR Vessel Internals IV.B1.RP-219 3.1.1-99 A Toughness (B.2.1.9)Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-86 Section 3 -Aging Management Review Results Table 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Jet Pump Direct Flow Nickel Alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-100 3.1.1-103 A Assemblies:
Inlet Neutron Flux (B.2.1.9)Riser and Brace, Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 B Holddown Beam, Diffuser, Tailpipe, Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 Wedges, and (B.2.1.9)Repair Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Components Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-100 3.1.1-103 A Neutron Flux (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 B Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1 Damage Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B BWR Vessel Internals IV.B1 .RP-377 3.1.1-100 A (B.2.1.9)Loss of Preload TLAA H, 4 X-750 alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .RP-381 3.1.1-104 A Neutron Flux (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-381 3.1.1-104 B Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1 Damage Loss of Fracture BWR Vessel Internals IV.B1 .RP-200 3.1.1-99 A Toughness (B.2.1.9)Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)
I I LaSalle Countition, Units 1 and 2 License ReneW plication 0 Page 3.1-87 Section 3 -Aging Management Review Results Table 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Jet Pump Direct Flow X-750 alloy Reactor Coolant and Loss of Material Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Assemblies:
Inlet Neutron Flux BWR Vessel Internals Riser and Brace, (B.2.1 .9)Holddown Beam, Diffuser, Tailpipe, Loss of Preload TLAA H, 4 Wedges, and Repair Components Reactor Vessel Structural Support to Cast Austenitic Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-104 3.1.1-102 A Internals maintain core Stainless Steel (B.2.1.9)Components:
configuration and (CASS) Water Chemistry (B.2.1.2)
IV.B1 .R-104 3.1.1-102 B Control Rod Drive flow distribution Guide Tube Loss of Fracture BWR Vessel Internals IV.B1.RP-220 3.1.1-99 A Toughness (B.2.1.9)Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1 .9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-104 3.1.1-102 C Neutron Flux (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .R-104 3.1.1-102 D Loss of Material BWR Vessel Internals IV.B1 .RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Reactor Vessel Direct Flow Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-99 3.1.1-103 C Internals Neutron Flux (B.2.1.9)Components:
Core Water Chemistry (B.2.1.2)
IV.B1 .R-99 3.1.1-103 D Plate DP/SLC Line LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.1-88 Section 3 -Aging Management Review Results Table 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Reactor Vessel Direct Flow Stainless Steel Reactor Coolant and Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 Internals Neutron Flux (B.2.1.9)Components:
Core Plate DP/SLC Line Water Chemistry (8.2.1.2)
V.81 .RP-26 3.1.1-43 B Steam Dryers Structural Integrity Stainless Steel Reactor Coolant Cracking BWR Vessel Internals IV.B1 .RP-155 3.1.1-101 A (B.2.1.9)
IV.B1.R-104 3.1.1-102 C Water Chemistry (B.2.1.2)
IV.B1 .R-104 3.1.1-102 D Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B Top Guide Structural Support to Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-98 3.1.1-103 A maintain core Neutron Flux (B.2.1.9)configuration and Water Chemistry (B.2.1.2)
IV.B1.R-98 3.1.1-103 B flow distribution Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1 Damage Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2 (B.2.1.9)[Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 B LaSalle County on, Units 1 and 2 License RenevW lication 0 Page 3.1-89 Section 3 -Aging Management Review Results Table 3.1.2-3 Reactor Vessel Internals (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.2. The BWR Vessel Internals (B.2.1.9) program is substituted to manage the aging effect(s) applicable to this component type, material and environment combination.
: 3. The TLAA designation in the Aging Management Program column indicates that loss of preload of the core plate rim bolts due to high neutron fluence is evaluated in Section 4.2.4. The TLAA designation in the Aging Management Program column indicates that loss of preload due to neutron fluence of the jet pump riser brace repair clamps, and jet pump slip joint clamps is evaluated in Section 4.2.5. The BWR Vessel Internals (B.2.1.9) program is used to manage loss of material due to wear of X-750 alloy replacement jet pump main wedges and auxiliary wedges.LaSalle County Station, Units 1 and 2 Page 3.1-90 License Renewal Application This Page Intentionally Left Blank Section 3 -Aging Management Review Results 3.2 AGING MANAGEMENT OF ENGINEERED SAFETY FEATURES 3.
 
==2.1 INTRODUCTION==
 
This section provides the results of the aging management review for those components identified in Section 2.3.2, Engineered Safety Features, as being subject to aging management review. The systems, or portions of systems, which are addressed in this section are described in the indicated sections.* High Pressure Core Spray System (2.3.2.1)* Low Pressure Core Spray System (2.3.2.2)* Reactor Core Isolation Cooling System (2.3.2.3)" Residual Heat Removal System (2.3.2.4)" Standby Gas Treatment System (2.3.2.5)3.2.2 RESULTS The following tables summarize the results of the aging management review for Engineered Safety Features.Table 3.2.2-1 High Pressure Core Spray System -Summary of Aging Management Evaluation Table 3.2.2-2 Low Pressure Core Spray System -Summary of Aging Management Evaluation Table 3.2.2-3 Reactor Core Isolation Cooling System -Summary of Aging Management Evaluation Table 3.2.2-4 Residual Heat Removal System -Summary of Aging Management Evaluation Table 3.2.2-5 Standby Gas Treatment System -Summary of Aging Management Evaluation 3.2.2.1 Materials.
Environments, Aginq Effects Requiring Management And Aging Management Programs 3.2.2.1.1 High Pressure Core Spray System Materials The materials of construction for the High Pressure Core Spray System components are: " Carbon Steel* Carbon and Low Alloy Steel Bolting* Carbon or Low Alloy Steel with Stainless Steel Cladding LaSalle County Station, Units 1 and 2 Page 3.2-1 License Renewal Application Section 3 -Aging Management Review Results" Glass" Stainless Steel" Stainless Steel Bolting" Zinc Environments The High Pressure Core Spray System components are exposed to the following environments:
* Air -Indoor Uncontrolled" Lubricating Oil* Treated Water Aging Effects Requiring Management The following aging effects associated with the High Pressure Core Spray System components require management: " Cumulative Fatigue Damage" Loss of Material* Loss of Preload* Wall Thinning Aging Management Programs The following aging management programs manage the aging effects for the High Pressure Core Spray System components:
* Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Flow-Accelerated Corrosion (B.2.1.10)
* Lubricating Oil Analysis (B.2.1.26)
* One-Time Inspection (B.2.1.21)
* TLAA* Water Chemistry (B.2.1.2)3.2.2.1.2 Low Pressure Core Spray System Materials The materials of construction for the Low Pressure Core Spray System components are:* Carbon Steel* Carbon and Low Alloy Steel Bolting LaSalle County Station, Units 1 and 2 Page 3.2-2 License Renewal Application Section 3 -Aging Management Review Results* Carbon or Low Alloy Steel with Stainless Steel Cladding* Copper Alloy with less than 15% Zinc* Glass* Stainless Steel* Stainless Steel Bolting* Zinc Environments The Low Pressure Core Spray System components are exposed to the following environments:
* Air -Indoor Uncontrolled" Lubricating Oil" Treated Water Aging Effects Requiring Management The following aging effects associated with the Low Pressure Core Spray System components require management:
* Cumulative Fatigue Damage* Loss of Material" Loss of Preload* Wall Thinning Aging Management Programs The following aging management programs manage the aging effects for the Low Pressure Core Spray System components:
* Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Flow-Accelerated Corrosion (B.2.1.10)" Lubricating Oil Analysis (B.2.1.26)" One-Time Inspection (B.2.1.21)" TLAA" Water Chemistry (B.2.1.2)LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-3 Section 3 -Aging Management Review Results 3.2.2.1.3 Reactor Core Isolation Cooling System Materials The materials of construction for the Reactor Core Isolation Cooling System components are:* Carbon Steel* Carbon Steel (with internal coating)* Carbon and Low Alloy Steel Bolting* Carbon or Low Alloy Steel with Stainless Steel Cladding* Copper Alloy with 15% Zinc or More* Copper Alloy with less than 15% Zinc* Glass* Gray Cast Iron" Nickel Alloy* Stainless Steel* Stainless Steel Bolting* Zinc Environments The Reactor Core Isolation Cooling System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Air -Outdoor* Condensation
* Lubricating Oil* Soil* Steam* Treated Water Aging Effects Requiring Management The following aging effects associated with the Reactor Core Isolation Cooling System components require management: " Cracking* Cumulative Fatigue Damage* Loss of Coating Integrity LaSalle County Station, Units 1 and 2 Page 3.2-4 License Renewal Application Section 3 -Aging Management Review Results* Loss of Material* Loss of Preload" Reduction of Heat Transfer* Wall Thinning Aging Management Programs The following aging management programs manage the aging effects for the Reactor Core Isolation Cooling System components:
* Bolting Integrity (B.2.1.11)" Buried and Underground Piping (B.2.1.28)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Flow-Accelerated Corrosion (B.2.1.10)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)" Lubricating Oil Analysis (B.2.1.26)" One-Time Inspection (B.2.1.21)
* Selective Leaching (B.2.1.22)" Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)* TLAA* Water Chemistry (B.2.1.2)3.2.2.1.4 Residual Heat Removal System Materials The materials of construction for the Residual Heat Removal System components are: " Carbon Steel* Carbon and Low Alloy Steel Bolting* Carbon or Low Alloy Steel with Stainless Steel Cladding* Glass* Nickel Alloy* Stainless Steel" Stainless Steel Bolting LaSalle County Station, Units 1 and 2 Page 3.2-5 License Renewal Application Section 3 -Aging Management Review Results Environments The Residual Heat Removal System components are exposed to the following environments: " Air -Indoor Uncontrolled" Condensation
* Lubricating Oil" Treated Water Aging Effects Requiring Management The following aging effects associated with the Residual Heat Removal System components require management:
* Cumulative Fatigue Damage* Loss of Material" Loss of Preload* Reduction of Heat Transfer" Wall Thinning Aging Management Programs The following aging management programs manage the aging effects for the Residual Heat Removal System components:
* Bolting Integrity (B.2.1.11)" External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Flow-Accelerated Corrosion (B.2.1.10)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)" Lubricating Oil Analysis (B.2.1.26)
* One-Time Inspection (B.2.1.21)
* TLAA* Water Chemistry (B.2.1.2)3.2.2.1.5 Standby Gas Treatment System Materials The materials of construction for the Standby Gas Treatment System components are: " Aluminum Alloy" Carbon Steel LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-6 Section 3 -Aging Management Review Results* Carbon and Low Alloy Steel Bolting* Copper Alloy with 15% Zinc or More" Copper Alloy with less than 15% Zinc* Elastomers
* Galvanized Steel* Glass" Stainless Steel Environments The Standby Gas Treatment System components are exposed to the following environments: " Air -Indoor Uncontrolled" Condensation
* Waste Water Aging Effects Requiring Management The following aging effects associated with the Standby Gas Treatment System components require management:
* Hardening and Loss of Strength* Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Standby Gas Treatment System components:
* Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) 3.2.2.2 AMR Results for Which Further Evaluation is Recommended by the GALL Report NUREG-1801 provides the basis for identifying those programs that warrant further evaluation by the reviewer in the license renewal application.
For the Engineered Safety Features, those programs are addressed in the following subsections.
LaSalle County Station, Units 1 and 2 Page 3.2-7 License Renewal Application Section 3 -Aging Management Review Results 3.2.2.2.1 Cumulative Fatigue Damage Fatigue is a time-limited aging analysis (TLAA) as defined in 10 CFR 54.3. TLAAs are required to be evaluated in accordance with 10 CFR 54.21(c).
The evaluation of metal .fatigue as a TLAA for the Control Rod Drive System, High Pressure Core Spray System, Low Pressure Core Spray System, Reactor Coolant Pressure Boundary System, Reactor Core Isolation Cooling System, Reactor Water Cleanup System, and Residual Heat Removal System is discussed in Section 4.3.3.2.2.2.2 Loss of Material due to Cladding Breach Loss of material due to cladding breach could occur for PWR steel pump casings with stainless steel cladding exposed to treated borated water. The GALL Report references NRC Information Notice 94-63, Boric Acid Corrosion of Charging Pump Casings Caused by Cladding Cracks, and recommends further evaluation of a plant-specific AMP to ensure that the aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RLSB- I (Appendix A. I of this SRP-LR).Item Number 3.2.1-2 is applicable to PWRs only and is not used for LSCS.3.2.2.2.3 Loss of Material due to Pitting and Crevice Corrosion 1. Loss of material due to pitting and crevice corrosion could occur in partially encased stainless steel tanks exposed to raw water due to cracking of the perimeter seal from weathering.
The GALL Report recommends further evaluation to ensure that the aging effect is adequately managed. The GALL Report recommends that a plant-specific AMP be evaluated because moisture and water can egress under the tank if the perimeter seal is degraded.
Acceptance criteria are described in Branch Technical Position RSLB-1 (Appendix A. I of this SRP-LR).Item Number 3.2.1-3 is applicable to PWRs and is not used for LSCS. There are no partially encased stainless steel tanks exposed to raw water in Engineered Safety Features systems at LSCS.2. Loss of material due to pitting and crevice corrosion could occur for stainless steel piping, piping components, piping elements, and tanks exposed to outdoor air. The possibility of pitting and crevice corrosion also extends to components exposed to air which has recently been introduced into buildings, i. e., components near intake vents. Pitting and crevice corrosion is only known to occur in environments containing sufficient halides (primarily chlorides) and in which condensation or deliquescence is possible.
Condensation or deliquescence should generally be assumed to be possible.
Applicable outdoor air environments (and associated indoor air environments) include, but are not limited to, those within approximately 5 miles of a saltwater coastline, those within 1/2 mile of a highway which is treated with salt in the wintertime, those areas in which the soil contains more than trace chlorides, those plants having cooling towers where the water is treated with chlorine or chlorine compounds, and those areas subject to chloride contamination from other agricultural or industrial sources. This item is applicable for the environments described above.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-8 Section 3 -Aging Management Review Results GALL AMP XI.M36, "External Surfaces Monitoring, " is an acceptable method to manage the aging effect. The applicant may demonstrate that this item is not applicable by describing the outdoor air environment present at the plant and demonstrating that external pitting or crevice corrosion is not expected.
The GALL Report recommends further evaluation to determine whether an aging management program is needed to manage this aging effect based on the environmental conditions applicable to the plant and requirements applicable to the components.
LSCS will implement the External Surfaces Monitoring of Mechanical Components (B.2.1.24) program to manage the loss of material due to pitting and crevice corrosion in stainless steel piping, piping components, and piping elements exposed to outdoor air in the Reactor Core Isolation Cooling System. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program provides for management of aging effects through periodic visual inspection of external surfaces for evidence of the loss of material.
Any visible evidence of the loss of material will be evaluated for acceptability of continued service. Deficiencies will be documented in accordance with the 10 CFR Part 50, Appendix B Corrective Action Program. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program is described in Appendix B.3.2.2.2.4 Loss of Material due to Erosion Loss of material due to erosion could occur in the stainless steel high-pressure safety injection (HPSI) pump miniflow recirculation orifice exposed to treated borated water.The GALL Report recommends a plant-specific AMP be evaluated for erosion of the orifice due to extended use of the centrifugal HPSI pump for normal charging.
The GALL Report references Licensee Event Report (LER) 50-275/94-023 for evidence of erosion.Further evaluation is recommended to ensure that the aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RSLB- I (Appendix A. I of this SRP-LR).Item Number 3.2.1-5 is applicable to PWRs only and is not used for LSCS. Loss of material due to erosion for Engineered Safety Features systems at LSCS is addressed in Item Number 3.2.1-65.3.2.2.2.5 Loss of Material due to General Corrosion and Fouling that Leads to Corrosion Loss of material due to general corrosion and fouling that leads to corrosion can occur for steel drywell and suppression chamber spray system nozzle and flow orifice internal surfaces exposed to air -indoor uncontrolled.
This could result in plugging of the spray nozzles and flow orifices.
This aging mechanism and effect will apply since the spray nozzles and flow orifices are occasionally wetted, even though the majority of the time this system is on standby. The wetting and drying of these components can accelerate corrosion and fouling. The GALL Report recommends further evaluation of a plant-specific AMP to ensure that the aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RSLB-1 (Appendix A. 1 of this SRP-LR).Item Number 3.2.1-6 is not applicable to LSCS. There are no steel spray system flow orifices or nozzles in an uncontrolled indoor air environment in Engineered Safety LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-9 Section 3 -Aging Management Review Results Features systems at LSCS. At LSCS, the drywell and suppression chamber spray nozzles are cast austenitic stainless steel.3.2.2.2.6 Cracking due to Stress Corrosion Cracking Cracking due to stress corrosion cracking could occur for stainless steel piping, piping components, piping elements and tanks exposed to outdoor air. The possibility of cracking also extends to components exposed to air which has recently been introduced into buildings, i.e., components near intake vents. Cracking is only known to occur in environments containing sufficient halides (primarily chlorides) and in which condensation or deliquescence is possible.
Condensation or deliquescence should generally be assumed to be possible.
Applicable outdoor air environments (and associated indoor air environments) include, but are not limited to, those within approximately 5 miles of a saltwater coastline, those within 1/2 mile of a highway which is treated with salt in the wintertime, those areas in which the soil contains more than trace chlorides, those plants having cooling towers where the water is treated with chlorine or chlorine compounds, and those areas subject to chloride contamination from other agricultural or industrial sources. This item is applicable for the environments described above.GALL AMP X1. M36, "External Surfaces Monitoring, "is an acceptable method to manage the aging effect. The applicant may demonstrate that this item is not applicable by describing the outdoor air environment present at the plant and demonstrating that external chloride stress corrosion cracking is not expected.
The GALL Report recommends further evaluation to determine whether an aging management program is needed to manage this aging effect based on the environmental conditions applicable to the plant and requirements applicable to the components.
LSCS will implement the External Surfaces Monitoring of Mechanical Components (B.2.1.24) program to manage cracking due to stress corrosion cracking in stainless steel piping, piping components, and piping elements exposed to outdoor air in the Reactor Core Isolation Cooling System. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program provides for management of aging effects through periodic visual inspection of external surfaces for evidence of cracking.
Any visible evidence of cracking will be evaluated for acceptability of continued service. Deficiencies will be documented in accordance with the 10 CFR Part 50, Appendix B Corrective Action Program. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program is described in Appendix B.3.2.2.2.7 Quality Assurance for Aging Management of Nonsafety-Related Components QA provisions applicable to License Renewal are discussed in Section B.1.3.3.2.2.2.8 Ongoing Review of Operating Experience Ongoing review of operating experience is addressed in Appendix A, Section A. 1.6 and Appendix B, Section B.1.4.LaSalle County Station, Units 1 and 2 Page 3.2-10 License Renewal Application Section 3 -Aging Management Review Results 3.2.2.2.9 Loss of Material due to Recurring Internal Corrosion Recurring internal corrosion can result in the need to augment AMPs beyond the recommendations in the GALL Report. During the search of plant-specific OE conducted during the LRA development, recurring internal corrosion can be identified by the number of occurrences of aging effects and the extent of degradation at each localized corrosion site. This further evaluation item is applicable if the search of plant-specific OE reveals repetitive occurrences (e.g., one per refueling outage cycle that has occurred over: (a)three or more sequential or nonsequential cycles for a 10-year OE search, or (b) two or more sequential or nonsequential cycles for a 5-year OE search) of aging effects with the same aging mechanism in which the aging effect resulted in the component either not meeting plant-specific acceptance criteria or experiencing a reduction in wall thickness greater than 50 percent (regardless of the minimum wall thickness.)
The GALL Report recommends that a plant-specific AMP, or a new or existing AMP, be evaluated for inclusion of augmented requirements to ensure the adequate management of any recurring aging effect(s).
Potential augmented requirements include: alternative examination methods (e.g., volumetric versus external visual), augmented inspections (e.g., a greater number of locations, additional locations based on risk insights based on susceptibility to aging effect and consequences of failure, a greater frequency of inspections), and additional trending parameters and decision points where increased inspections would be implemented.
Acceptance criteria are described in Appendix A. 1,"Aging Management Review -Generic (Branch Technical Position RSLB-1)." The applicant states: (a) why the program's examination methods will be sufficient to detect the recurring aging effect before affecting the ability of a component to perform its intended function, (b) the basis for the adequacy of augmented or lack of augmented inspections, (c) what parameters will be trended as well as the decision points where increased inspections would be implemented (e.g., the extent of degradation at individual corrosion sites, the rate of degradation change), (d) how inspections of components that are not easily accessed (i.e., buried, underground) will be conducted, and (e) how leaks in any involved buried or underground components will be identified.
Each plant-specific operating experience example should be evaluated to determine if the chosen AMP should be augmented even if the thresholds for significance of aging effect or frequency of occurrence of aging effect have not been exceeded.
For example, during a 10-year search of plant specific operating experience, two instances of 360 degree 30 percent wall loss occurred at copper alloy to steel joints. Neither the significance of the aging effect nor the frequency of occurrence of aging effect threshold has been exceeded.
Nevertheless, the operating experience should be evaluated to determine if the AMP that is proposed to manage the aging effect is sufficient (e.g., method of inspection, frequency of inspection, number of inspections) to provide reasonable assurance that the CLB intended functions of the component will be met throughout the period of extended operation.
Likewise, the GALL Report AMR items associated with the new FE items only cite raw water and waste water environments because OE indicates that these are the predominant environments associated with recurring internal corrosion; however, if the search of plant-specific OE reveals recurring internal corrosion in other water environments (e.g., treated water), the aging effect should be addressed in a similar manner.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-11 Section 3 -Aging Management Review Results LR-ISG-2012-02 has been issued which addresses instances of recurring internal corrosion identified during review of plant-specific operating experience.
The operating experience for LSCS has been reviewed and instances of recurring internal corrosion in the Engineered Safety Features systems have not been identified with a frequency that is consistent with the thresholds discussed in LR-ISG-2012-02.
3.2.2.3 Time-Limited Aging Analysis The time-limited aging analyses identified below are associated with the Engineered Safety Features components:
* Section 4.3, Metal Fatigue Analyses* Section 4.3.2, ASME Section III, Class 2 and 3 and ANSI B31.1 Allowable Stress Analyses" Section 4.3.5, High-Energy Line Break (HELB) Analyses Based Upon Fatigue 3.
 
==2.3 CONCLUSION==
 
The Engineered Safety Features piping, fittings, and components that are subject to aging management review have been identified in accordance with the requirements of 10 CFR 54.4. The aging management programs selected to manage aging effects for the Engineered Safety Features components are identified in the summaries in Section 3.2.2.1 above.A description of these aging management programs is provided in Appendix B, along with the demonstration that the identified aging effects will be managed for the period of extended operation.
Therefore, based on the conclusions provided in Appendix B, the effects of aging associated with the Engineered Safety Features components will be adequately managed so that there is reasonable assurance that the intended functions are maintained consistent with the current licensing basis during the period of extended operation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-12 0 0 Section 3 -Aging Management Review Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-1 Stainless steel, Steel Cumulative fatigue Fatigue is a time-limited Yes, TLAA Fatigue is a TLAA; further evaluation is Piping, piping damage aging analysis (TLAA) to documented in Subsection 3.2.2.2.1.
components, and piping due to fatigue be evaluated for the elements exposed to period of extended Treated water (borated) operation.
See the SRP, Section 4.3 "Metal Fatigue," for acceptable methods for meeting the requirements of 10 CFR 54.21 (c)(1).3.2.1-2 PWR Only 3.2.1-3 PWR Only 3.2.1-4 Stainless steel Piping, Loss of material Chapter XI.M36, Yes, environmental Consistent with NUREG-1801.
The piping components, and due to pitting and "External Surfaces conditions need to External Surfaces Monitoring of Mechanical piping elements; tanks crevice corrosion Monitoring of Mechanical be evaluated Components (8.2.1.24) program will be exposed to Air -outdoor Components" used to manage loss of material of stainless steel piping, piping components, and piping elements exposed to air -outdoor in the Reactor Core Isolation Cooling System.See subsection 3.2.2.2.3.2.
3.2.1-5 PWR Only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-13 Section 3 -Aging Management Review Results Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-6 Steel Drywell and Loss of material A plant-specific aging Yes, plant-specific Not Applicable.
suppression chamber due to general management program is See subsection 3.2.2.2.5.
spray system (internal corrosion; fouling that to be evaluated surfaces):
flow orifice; leads to corrosion spray nozzles exposed to Air -indoor, uncontrolled (Internal) 3.2.1-7 Stainless steel Piping, Cracking Chapter XI.M36, Yes, environmental Consistent with NUREG-1801.
The piping components, and due to stress "External Surfaces conditions need to External Surfaces Monitoring of Mechanical piping elements; tanks corrosion cracking Monitoring of Mechanical be evaluated Components (B.2.1.24) program will be exposed to Air -outdoor Components" used to manage cracking of stainless steel piping, piping components, and piping elements exposed to air -outdoor in the Reactor Core Isolation Cooling System.See subsection 3.2.2.2.6.
3.2.1-8 PWR Only 3.2.1-9 PWR Only 3.2.1-10 Cast austenitic stainless Loss of fracture Chapter XI.M12, No Not Applicable.
steel Piping, piping toughness "Thermal Aging components, and piping due to thermal aging Embrittlement of Cast piping components, and piping elements elements exposed to embrittlement Austenitic Stainless Steel exposed to treated water (borated)
>250 0 C Treated water (borated) (CASS)" exposd tor treated water (b raed > 250&deg;>250'C (>482OF), (>482iF) or treated water >250sC (>482&deg;F)Treated water >250oC in Engineered Safety Features systems.(>482'F)LaSalle Count lion, Units 1 and 2 License ReneW plication Page 30 0 O Section 3 -Aging Management Review .Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-11 Steel Piping, piping Wall thinning Chapter XI.M17, "Flow- No Consistent with NUREG-1801.
The Flow-components, and piping due to flow- Accelerated Corrosion" Accelerated Corrosion (B.2.1.10) program elements exposed to accelerated corrosion will be used to manage wall thinning of the Steam, Treated water carbon steel piping, piping components, and piping elements exposed to steam and treated water in the Reactor Coolant Pressure Boundary System, Reactor Core Isolation Cooling System, Reactor Water Cleanup System, and Residual Heat Removal System.3.2.1-12 Steel, high-strength Cracking Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Bolting Closure bolting exposed due to cyclic loading, Integrity" Integrity (B.2.1.11) program will be used to to Air with steam or water stress corrosion manage cracking of the high strength low leakage cracking alloy steel bolting exposed to air with the potential for reactor coolant leakage in the Reactor Coolant Pressure Boundary System.3.2.1-13 Steel; stainless steel Loss of material Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Bolting Bolting, Closure bolting due to general (steel Integrity" Integrity (B.2.1.11) program will be used to exposed to Air -outdoor only), pitting, and manage loss of material of the carbon and (External), Air -indoor, crevice corrosion low alloy steel and stainless steel bolting uncontrolled (External) exposed to air -indoor uncontrolled in the High Pressure Core Spray System, Low Pressure Core Spray System, Reactor Coolant Pressure Boundary System, Reactor Core Isolation Cooling System, Residual Heat Removal System, and Standby Gas Treatment System.3.2.1-14 Steel Closure bolting Loss of material Chapter XI.M18, "Bolting No Not Applicable.
exposed to Air with due to general Integrity" There is no steel closure bolting exposed to steam or water leakage corrosion air with steam or water leakage in Engineered Safety Features systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-15 Section 3 -Aging Management Review Results Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-15 Copper alloy, Nickel Loss of preload Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Bolting alloy, Steel; stainless due to thermal Integrity" Integrity (B.2.1.11) program will be used to steel, Stainless steel, effects, gasket creep, manage loss of preload of the carbon and Steel; stainless steel and self-loosening low alloy steel and stainless steel bolting Bolting, Closure bolting exposed to air -indoor uncontrolled and exposed to Any treated water in the High Pressure Core environment, Air -Spray System, Low Pressure Core Spray outdoor (External), Raw System, Reactor Coolant Pressure water, Treated borated Boundary System, Reactor Core Isolation water, Fuel oil, Treated Cooling System, Residual Heat Removal water, Air -indoor, System, and Standby Gas Treatment uncontrolled (External)
System.3.2.1-16 Steel Containment Loss of material Chapter XI.M2, "Water No Consistent with NUREG-1801 with isolation piping and due to general, Chemistry," and exceptions.
The One-Time Inspection components (Internal pitting, and crevice Chapter XI.M32, "One- (B.2.1.21) program and the Water surfaces), Piping, piping corrosion Time Inspection" Chemistry (B.2.1.2) program will be used to components, and piping manage loss of material of the carbon steel elements exposed to and gray cast iron heat exchanger Treated water components, piping, piping components, and piping elements, reactor vessel external attachments, and tanks exposed to treated water in the High Pressure Core Spray System, Low Pressure Core Spray System, Reactor Coolant Pressure Boundary System, Reactor Core Isolation Cooling System, Reactor Vessel, and Residual Heat Removal System.An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle Countv ion, Units 1 and 2 License Reneyplication Page30 Section 3 -Aging Management Review Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-17 Aluminum, Stainless Loss of material Chapter XI.M2, 'Water No Consistent with NUREG-1 801 with steel Piping, piping due to pitting and Chemistry," and exceptions.
The One-Time Inspection components, and piping crevice corrosion Chapter XI.M32, "One- (B.2.1.21) program and the Water elements exposed to Time Inspection" Chemistry (B.2.1.2) program will be used to Treated water manage loss of material of the carbon or low alloy steel with stainless steel cladding and stainless steel heat exchanger components, and piping, piping components, and piping elements exposed to treated water and treated water > 140 F in the High Pressure Core Spray System, Low Pressure Core Spray System, Reactor Coolant Pressure Boundary System, Reactor Core Isolation Cooling System, and Residual Heat Removal System.The Bolting Integrity (B.2.1.11) program has been substituted and will be used to manage loss of material of stainless steel bolting exposed to treated water in the High Pressure Core Spray System, Low Pressure Core Spray System, Reactor Core Isolation Cooling System, and Residual Heat Removal System.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.2.1-18 Stainless steel Loss of material Chapter XI.M2, 'Water No Not Applicable.
Containment isolation due to pitting and Chemistry," and Stainless steel piping, piping components, piping and components crevice corrosion Chapter XI.M32, "One- and piping elements exposed to treated (Internal surfaces)
Time Inspection" andrpipingieer ed ty Feates exposed to Treated water water in Engineered Safety Features systems are addressed by Item Number 3.2.1-17.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-17 Section 3 -Aging Management Review Results Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-19 Stainless steel Heat Reduction of heat Chapter XI.M2, "Water No Consistent with NUREG-1 801 with exchanger tubes transfer Chemistry," and exceptions.
The One-Time Inspection exposed to Treated due to fouling Chapter XI.M32, "One- (B.2.1.21) and Water Chemistry (B.2.1.2)water, Treated water Time Inspection" program will be used to manage reduction (borated) of heat transfer of the stainless steel heat exchanger components exposed to treated water in the Residual Heat Removal System.An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.2.1-20 PWR Only 3.2.1-21 PWR Only 3.2.1-22 PWR Only 3.2.1-23 S'teel Heat exchanger Loss of material Chapter XI.M20, "Open- No Not Applicable.
components, due to general, Cycle Cooling Water There are no steel heat exchanger Containment isolation pitting, crevice, and System" Th ere or ont ainment isolanger piping and components microbiologically-components or containment isolation piping (Internal surfaces) influenced corrosion; and components exposed to raw water in exposed to Raw water fouling that leads to Engineered Safety Features systems.corrosion 3.2.1-24 PWR Only LaSalle Count.dtion, Units 1 and 2 License ReneW plication Page30 O O Section 3- Aging Management Review es Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-25 Stainless steel Heat Loss of material Chapter XI.M20, "Open- No Not Applicable.
exchanger components, due to pitting, crevice, Cycle Cooling Water There are no stainless steel heat Containment isolation and microbiologically-System" Ther componess st ainment piping and components influenced corrosion; exchanger components or containment (Internal surfaces) fouling that leads to isolation piping and components exposed exposed to Raw water corrosion to raw water in Engineered Safety Features systems.3.2.1-26 Stainless steel Heat Reduction of heat Chapter XI.M20, "Open- No Not Applicable.
exchanger tubes transfer Cycle Cooling Water There are no stainless steel heat exposed to Raw water due to fouling System" Ther tubes steed heat exchanger tubes exposed to raw water in Engineered Safety Features systems.3.2.1-27 Stainless steel, Steel Reduction of heat Chapter XI.M20, "Open- No Not Applicable.
Heat exchanger tubes transfer Cycle Cooling Water There are no stainless steel or steel heat exposed to Raw water due to fouling System" Ther tubes sed or ster in exchanger tubes exposed to raw water in Engineered Safety Features systems.3.2.1-28 Stainless steel Piping, Cracking Chapter XI.M21A, No Not Applicable.
piping components, and due to stress "Closed Treated Water There are no stainless steel piping, piping piping elements exposed corrosion cracking Systems" componeno and piping posed to Closed-cycle cooling components, and piping elements exposed water >60C C (>140&deg;F) to closed-cycle cooling water >60&deg;C (>140&deg;F) in Engineered Safety Features systems.3.2.1-29 Steel Piping, piping Loss of material Chapter XI.M21A, No Not Applicable.
components, and piping due to general, "Closed Treated Water There are no steel piping, piping elements exposed to pitting, and crevice Systems" There and piping piping Closed-cycle cooling corrosion components, and piping elements exposed water c to closed-cycle cooling water in Engineered Safety Features systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-19 Section 3 -Aging Management Review Results Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-30 Steel Heat exchanger Loss of material Chapter XI.M21A, No Consistent with NUREG-1 801. The Closed components exposed to due to general, "Closed Treated Water Treated Water Systems (B.2.1.13) program Closed-cycle cooling pitting, crevice, and Systems" will be used to manage loss of material of water galvanic corrosion the carbon steel heat exchanger components exposed to closed cycle cooling water in the Reactor Coolant Pressure Boundary System.3.2.1-31 Stainless steel Heat Loss of material Chapter XI.M21A, No Not Applicable.
exchanger components, due to pitting and "Closed Treated Water Piping, piping crevice corrosion Systems" There are no stainless steel heat components, and piping exchanger components or piping, piping elements exposed to components, and piping elements exposed Closed-cycle cooling to closed-cycle cooling water in Engineered water Safety Features systems.3.2.1-32 Copper alloy Heat Loss of material Chapter XI.M21A, No Consistent with NUREG-1801.
The Closed exchanger components, due to pitting, crevice, "Closed Treated Water Treated Water Systems (B.2.1.13) program Piping, piping and galvanic Systems" will be used to manage loss of material of components, and piping corrosion the copper alloy heat exchanger elements exposed to components exposed to closed cycle Closed-cycle cooling cooling water in the Reactor Coolant water Pressure Boundary System.3.2.1-33 Copper alloy, Stainless Reduction of heat Chapter XI.M21A, No Not Applicable.
steel Heat exchanger transfer "Closed Treated Water There are no copper alloy or stainless steel tubes exposed to Closed- due to fouling Systems" heat exchanger tubes exposed to closed-cycle cooling water cycle cooling water in Engineered Safety Features systems.LaSalle County on, Units 1 and 2 License Rene 1wlication Page 30 0 0 Section 3- Aging Management Review Re 9 Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-34 Copper alloy (>15% Zn or Loss of material Chapter XI.M33, No Not Applicable.
>8% Al) Piping, piping due to selective "Selective Leaching" There are no copper alloy (>15% Zn or components, and piping leaching >8% Al) piping, piping components, and exchanger components piping elements or heat exchanger exposed to Closed-cycle components exposed to closed-cycle exposedol Cler cooling water in Engineered Safety cooling water Features systems.3.2.1-35 PWR Only 3.2.1-36 PWR Only 3.2.1-37 Gray cast iron Piping, Loss of material Chapter XI.M33, No Not Applicable.
piping components, and due to selective "Selective Leaching" There are no gray cast iron piping, piping piping elements exposed leaching Teeaen rycs rnppnppn to Soil components, and piping elements exposed to soil in Engineered Safety Features systems.3.2.1-38 Elastomers Elastomer Hardening and loss of Chapter XI.M36, No Consistent with NUREG-1801.
The seals and components strength "External Surfaces External Surfaces Monitoring of Mechanical exposed to Air -indoor, due to elastomer Monitoring of Mechanical Components (B.2.1.24) program will be uncontrolled (External) degradation Components" used to manage hardening and loss of strength of the elastomer seals and components exposed to air -indoor uncontrolled in the Standby Gas Treatment System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-21 Section 3 -Aging Management Review Results Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-39 Steel Containment Loss of material Chapter XI.M36, No Not Applicable.
isolation piping and due to general "External Surfaces components (External corrosion Monitoring of Mechanical There are no steel containment isolation surfaces) exposed to Components" piping and components exposed to Condensation (External) condensation (external) in Engineered Safety Features systems.LaSalle County on, Units 1 and 2 License Rene1W lication Page 30 Section 3 -Aging Management Review RI Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-40 Steel Ducting, piping, and components (External surfaces), Ducting, closure bolting, Containment isolation piping and components (External surfaces)exposed to Air -indoor, uncontrolled (External)
Loss of material due to general corrosion Chapter XI.M36,"External Surfaces Monitoring of Mechanical Components" No Consistent with NUREG-1801.
The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program will be used to manage loss of material of the carbon or low alloy steel with stainless steel cladding, carbon steel, carbon steel (with internal coating), and gray cast iron ducting and components, heat exchanger components, piping, piping components, and piping elements, reactor vessel external attachments, and tanks exposed to air- indoor, uncontrolled in the High Pressure Core Spray System, Low Pressure Core Spray System, Reactor Coolant Pressure Boundary System, Reactor Core Isolation Cooling System, Reactor Vessel, Residual Heat Removal System, and Standby Gas Treatment System.The aging effect of loss of material due to general corrosion does not apply to the external surfaces of reactor vessel, nozzle, and safe end components exposed to air-indoor, uncontrolled in the Reactor Vessel System. During power operation the insulated reactor vessel, nozzles, and safe end components have external temperature greater than 212 degrees F and are at a higher temperature than the air-indoor (uncontrolled) environment.
During plant shutdown the containment atmosphere is normally below the dewpoint temperature.
Therefore, wetting due to condensation and moisture accumulation will not occur during power operation or plant shutdown and loss of material due to general corrosion does not apply.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-23 Section 3 -Aging Management Review Results Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-41 Steel External surfaces Loss of material Chapter XI.M36, No Not Applicable.
exposed to Air -outdoor due to general "External Surfaces There are no steel external surfaces (External) corrosion Monitoring of Mechanical exposed to air -outdoor in Engineered Components"exoetoa-oudoinEgerd Safety Features systems.3.2.1-42 Aluminum Piping, piping Loss of material Chapter XI.M36, No Not Applicable.
components, and piping due to pitting and "External Surfaces elements exposed to Air -crevice corrosion Monitoring of Mechanical There are no aluminum piping, piping outdoor Components" components, and piping elements exposed to air -outdoor in Engineered Safety Features systems.3.2.1-43 Elastomers Elastomer Hardening and loss of Chapter XI.M38, No Not Applicable.
seals and components strength "Inspection of Internal There are no elastomer seals and exposed to Air -indoor, due to elastomer Surfaces in componeno elasto air and uncontrolled (Internal) degradation Miscellaneous Piping and components exposed to air -indoor, oucting Components" uncontrolled (internal) in Engineered Safety Features systems. The internal environment of elastomer seals and components in the Standby Gas Treatment System is considered to be condensation.
Hardening and loss of strength of these components is managed by the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program.3.2.1-44 Steel Piping and Loss of material Chapter XI.M38, No Not Applicable.
components (Internal due to general "Inspection of Internal There are no steel piping and components surfaces), Ducting and corrosion Surfaces in Therecaiegnonsteelppiping and ocomponents (Intrna Misellneos Piingandor ducting and components exposed to air components (Internal Miscellaneous Piping and(internal) in surfaces) exposed to Air Ducting Components" Engineered Safety Features systems. The-indoor, uncontrolledEnierdSftFauesytm.Th (Internal) applicable internal environment for piping and components and ducting and components in Engineered Safety Features systems is considered to be condensation, and is addressed by Item Number 3.2.1-46.LaSalle Count jon, Units 1 and 2 License ReneW &#xfd;lication Page 30 Section 3 -Aging Management Review Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation
_ _Recommended 3.2.1-45 PWR Only 3.2.1-46 Steel Piping and Loss of material Chapter XI.M38, No Consistent with NUREG-1801.
The components (Internal due to general, "Inspection of Internal Inspection of Internal Surfaces in surfaces) exposed to pitting, and crevice Surfaces in Miscellaneous Piping and Ducting Condensation (Internal) corrosion Miscellaneous Piping and Components (B.2.1.25) program will be Ducting Components" used to manage loss of material of the carbon steel, galvanized steel, and gray cast iron ducting and components, piping, piping components, and piping elements, and tanks exposed to condensation in the Reactor Core Isolation Cooling System, Residual Heat Removal System, and Standby Gas Treatment System.3.2.1-47 PWR Only 3.2.1-48 Stainless steel Piping, Loss of material Chapter XI.M38, No Consistent with NUREG-1801.
The piping components, and due to pitting and "Inspection of Internal Inspection of Internal Surfaces in piping elements (Internal crevice corrosion Surfaces in Miscellaneous Piping and Ducting surfaces);
tanks exposed Miscellaneous Piping and Components (B.2.1.25) program will be to Condensation Ducting Components" used to manage loss of material of the (Internal) stainless steel ducting and components, piping, piping components, and piping elements, and tanks exposed to condensation in the Combustible Gas Control System, Reactor Core Isolation Cooling System, Residual Heat Removal System, Standby Gas Treatment System, and Standby Liquid Control System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-25 Section 3 -Aging Management Review Results Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-49 Steel Piping, piping Loss of material Chapter XI.M39, No Consistent with NUREG-1801.
The components, and piping due to general, "Lubricating Oil Analysis," Lubricating Oil Analysis (B.2.1.26) program elements exposed to pitting, and crevice and and the One-Time Inspection (B.2.1.21)
Lubricating oil corrosion Chapter XI.M32, "One- program will be used to manage loss of Time Inspection" material of the carbon steel, carbon steel (with internal coating), and gray cast iron heat exchanger components, piping, piping components, and piping elements, and tanks exposed to lubricating oil in the High Pressure Core Spray System, Low Pressure Core Spray System, Reactor Coolant Pressure Boundary System, Reactor Core Isolation Cooling System, and Residual Heat Removal System.3.2.1-50 Copper alloy, Stainless Loss of material Chapter XI.M39, No Consistent with NUREG-1 801. The steel Piping, piping due to pitting and "Lubricating Oil Analysis," Lubricating Oil Analysis (B.2.1.26) program components, and piping crevice corrosion and and the One-Time Inspection (B.2.1.21) elements exposed to Chapter XI.M32, "One- program will be used to manage loss of Lubricating oil Time Inspection" material of the copper alloy and stainless steel heat exchanger components, and piping, piping components, and piping elements, exposed to lubricating oil in the Reactor Coolant Pressure Boundary System and Reactor Core Isolation Cooling System.LaSalle Countwflion, Units 1 and 2 License ReneW plication Page 30 Section 3 -Aging Management Review sut Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Discussion
;omponent 4 i Steel, Copper alloy, Stainless steel Heat exchanger tubes exposed to Lubricating oil Reduction of heat transfer due to fouling Chapter XI.M39,"Lubricating Oil Analysis," and Chapter XI.M32, "One-Time Inspection" No Consistent with NUREG-1801.
The Lubricating Oil Analysis (B.2.1.26) program and the One-Time Inspection (B.2.1.21) program will be used to manage reduction of heat transfer of the copper alloy and stainless steel heat exchanger tubes exposed to lubricating oil in the Control Room Ventilation System, Diesel Generator and Auxiliaries System, Essential Cooling Water System, and Reactor Core Isolation Cooling System.3.2.1-52 Steel (with coating or Loss of material Chapter XI.M41, "Buried No Not Applicable.
wrapping)
Piping, piping due to general, and Underground Piping There are no steel (with coating or components, and piping pitting, crevice, and and Tanks" wrea n pno pip ing c o elements exposed to Soil microbiologically-wrapping) piping, piping components, and or Concrete influenced corrosion piping elements exposed to soil or concrete in Engineered Safety Features systems.3.2.1-53 Stainless steel, nickel Loss of material Chapter XI.M41, "Buried No Consistent with NUREG-1801.
The Buried alloy piping, piping due to pitting and and Underground Piping and Underground Piping (B.2.1.28) components, and piping crevice corrosion and Tanks" program will be used to manage loss of elements exposed to soil material of the stainless steel piping, piping or concrete components, and piping elements exposed to soil in the Reactor Core Isolation Cooling System.3.2.1-53x Steel, stainless steel, Loss of material due Chapter XI.M41, "Buried No Not Applicable.
nickel alloy underground to general (steel and Underground Piping There are no steel, stainless steel, or nickel piping, piping only), pitting and and Tanks" Th er gr oun d piping, piping components, and piping crevice corrosion alloy underground piping, piping elements exposed to air- components, and piping elements exposed intso expontrled toair- to air-indoor uncontrolled or condensation condensation (external) (external) in Engineered Safety Features systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-27 Section 3 -Aging Management Review Results Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-54 Stainless steel Piping, Cracking Chapter XI.M7, "BWR No Consistent with NUREG-1801 with piping components, and due to stress Stress Corrosion exceptions.
The BWR Stress Corrosion piping elements exposed corrosion cracking, Cracking," and Cracking (B.2.1.7) program and the Water to Treated water >60&deg;C intergranular stress Chapter XI.M2, 'Water Chemistry (B.2.1.2) program will be used to (>140'F) corrosion cracking Chemistry" manage cracking of the stainless steel piping, piping components, and piping elements exposed to treated water > 140 F in the Reactor Coolant Pressure Boundary System.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.2.1-55 Steel Piping, piping None None, provided No, if conditions are Not Applicable.
components, and piping 1) attributes of the met. There are no steel piping, piping elements exposed to concrete are consistent componentostee piping piping Concrete with ACI 318 or ACI 349 components, and piping elements exposed (low water-to-cement to concrete in Engineered Safety Features ratio, low permeability, systems.and adequate air entrainment) as cited in NUREG-1557, and 2) plant OE indicates no degradation of the concrete 3.2.1-56 Aluminum Piping, piping None None NA -No AEM or Consistent with NUREG-1801.
components, and piping AMP elements exposed to Air-indoor, uncontrolled (Internal/External)
LaSalle Count.,lion, Units 1 and 2 License ReneV plication Page 30 Section 3- Aging Management Review es Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-57 Copper alloy Piping, None None NA -No AEM or Consistent with NUREG-1 801.piping components, and AMP piping elements exposed to Air -indoor, uncontrolled (External), Gas 3.2.1-58 PWR Only 3.2.1-59 Galvanized steel Ducting, None None NA -No AEM or Not Applicable.
piping, and components AMP exposed to Air -indoor, There are no galvanized steel ducting, controlled (External) piping, and components exposed to air-indoor, controlled (External) in Engineered Safety Features systems.3.2.1-60 Glass Piping elements None None NA -No AEM or Consistent with NUREG-1801.
exposed to Air -indoor, AMP uncontrolled (External), Lubricating oil, Raw water, Treated water, Treated water (borated), Air with borated water leakage, Condensation (Internal/External), Gas, Closed-cycle cooling water, Air -outdoor 3.2.1-61 Nickel alloy Piping, piping None None NA -No AEM or Consistent with NUREG-1801.
components, and piping AMP elements exposed to Air-indoor, uncontrolled (External)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-29 Section 3 -Aging Management Review Results Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-62 Nickel alloy Piping, piping None None NA -No AEM or Not Applicable.
components, and piping AMP elements exposed to Air There are no nickel alloy piping, piping with borated water components, and piping elements exposed leakage to air with borated water leakage in Engineered Safety Features systems.3.2.1-63 Stainless steel Piping, None None NA -No AEM or Consistent with NUREG-1801.
piping components, and AMP piping elements exposed to Air -indoor, uncontrolled (External), Air with borated water leakage, Concrete, Gas, Air -indoor, uncontrolled (Internal) 3.2.1-64 Steel Piping, piping None None NA -No AEM or Not Applicable.
components, and piping AMP elements exposed to Air There are no steel piping, piping-indoor, controlled components, and piping elements exposed (External), Gas to air -indoor, controlled or gas in Engineered Safety Features systems.3.2.1-65 Any material, piping, Wall thinning due to Chapter XI.M17, "Flow- No Consistent with NUREG-1 801. The Flow-piping components, and erosion Accelerated Corrosion" Accelerated Corrosion (B.2.1.10) program piping elements exposed will be used to manage wall thinning of the to treated water, treated carbon or low alloy steel with stainless steel water (borated) cladding, carbon steel, and stainless steel piping, piping components, and piping elements exposed to treated water in the High Pressure Core Spray System, Low Pressure Core Spray System, and Reactor Core Isolation Cooling System.LaSalle County,%Wion, Units 1 and 2 License ReneV plication Page 34 O O Section 3- Aging Management Review Res4 I, Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-66 Metallic piping, piping Loss of material due A plant-specific aging Yes, plant-specific Not Applicable.
components, and tanks to recurring internal management program is See Subsection 3.2.2.2.9 exposed to raw water or corrosion to be evaluated to waste water address recurring internal corrosion 3.2.1-67 Stainless steel or Cracking due to Chapter XI.M29, No Not Applicable.
aluminum tanks (within stress corrosion "Aboveground Metallic There are no stainless steel or aluminum the scope of Chapter cracking Tanks" tan e n the ste o r a inm XI.M29, "Aboveground tanks (within the scope of Chapter XI.M29, Metallic Tanks") exposed "Aboveground Metallic Tanks") exposed to to soil or concrete, or the soil or concrete, or exposed to external tosolorowin rexteornenvironments of air-outdoor, air-indoor following external uncontrolled, moist air, or condensation in air-indoor uncontrolled, Engineered Safety Features systems.moist air, condensation 3.2.1-68 Steel, stainless steel, or Loss of material due Chapter XI.M29, No Not Applicable.
aluminum tanks (within to general (steel "Aboveground Metallic T able.the scope of Chapter only), pitting, and Tanks" There ankstelithinte ste of XI .M29, "Aboveground crevice corrosion aluminum tanks (within the scope of Metallic Tanks") exposed Chapter XI.M29, "Aboveground Metallic Mtalic Tanks"creteporhed Tanks") exposed to soil or concrete, or to soil or concrete, or the external environments of air-outdoor, air-environments air-outdoor, indoor uncontrolled, moist air, or air-indoor uncontrolled, condensation in Engineered Safety moist air, condensation Features systems.3.2.1-69 Insulated steel, stainless Loss of material due Chapter XI.M36, No Not Applicable.
steel, copper alloy, or to general (steel, and "External Surfaces There are no insulated steel, stainless aluminum, piping, piping copper alloy only), Monitoring of Mechanical steel, copper alloy, or aluminum, piping, components, and tanks pitting, and crevice Components" or Chapter piping components, and tanks exposed to exposed to condensation, corrosion XI.M29, "Aboveground condensation or air-outdoor in Engineered air-outdoor Metallic Tanks," (for Safety Features systems.tanks only) Sft etrssses LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-31 Section 3 -Aging Management Review Results Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety Features Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-70 Steel, stainless steel or Loss of material due Chapter XI.M29, No Not Applicable.
aluminum tanks (within to general (steel "Aboveground Metallic There are no steel, stainless steel or the scope of Chapter only), pitting and Tanks" There a n kstelithinle s te of XI.M29, "Aboveground crevice corrosion aluminum tanks (within the scope of Metallic Tanks") exposed Chapter XI.M29, "Aboveground Metallic to treated water, treated Tanks") exposed to treated water or treated borated water borated water in Engineered Safety Features systems.3.2.1-71 Insulated stainless steel, Cracking due to Chapter XI.M36, No Not Applicable.
aluminum, or copper stress corrosion "External Surfaces There are no insulated stainless steel, alloy (> 15% Zn) piping, cracking Monitoring of Mechanical aluminum, or copper alloy (> 15% Zn)piping components, and Components" or Chapter piping, piping components, and tanks tanks exposed to XI.M29, "Aboveground exposed to condensation or air-outdoor in condensation, air-outdoor Metallic Tanks," (for Engineered Safety Features systems.tanks only)LaSalle County,"ion, Units 1 and 2 License Rene V Plication Page 3 ,
0 O Section 3 -Aging Manageint Review Results Table 3.2.2-1 High Pressure Core Spray System Summary of Aging Management Evaluation Table 3.2.2-1 High Pressure Core Spray System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 A Bolting Stainless Steel Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 A Treated Water Loss of Material Bolting Integrity (B.2.1.11)
V.D2.EP-73 3.2.1-17 E, 1, 2 (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-122 3.2.1-15 A, 1 Flow Device Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Throttle Carbon Steel Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
_T LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-33 Section 3 -Aging Management Review Results Table 3.2.2-1 High Pressure Core Spray System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Leakage Boundary Carbon Steel Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16 A Water Chemistry (B.2.1.2)V.D2.EP-60 3.2.1-16 B I I t +Stainless Steel Air -Indoor Uncontrolled (External)
None None V.F.EP-18 3.2.1-63 A Treated Water (Internal)
Cumulative Fatigue Damage TLAA VII.E3.A-62 3.3.1-2 A, 5 Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A I. +Water Chemistry (B.2.1.2)V.D2.EP-73 3.2.1-17 B 4.2EP7 3.2.-17-Pressure Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Comoonents (B.2.1 .24', V.D2.E-26 3.2.1-40 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Treated Water Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (External) (B.2.1.21)
_Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Treated Water (Internal)
Cumulative Fatigue Damage TLAA V.D2.E-10 3.2.1-1 A, 5 Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16 A 4 +Water Chemistry (B.2.1 .2'V.D2.EP-60 3.2.1-16 8 Glass Air- Indoor None None V.F.EP-15 3.2.1-60 A Uncontrolled (External)
Lubricating Oil (Internal)
None None V.F.EP-16 3.2.1-60 A Stainless Steel Air -Indoor Uncontrolled (External)
None None V.F.EP-18 3.2.1-63 A LaSalle County lon, Units 1 and 2 License RenevW&#xfd;lication Page 3.2-34 0 0 Section 3 -Aging Manag #t Review Results Table 3.2.2-1 High Pressure Core Spray System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item L Management Piping, piping Pressure Boundary Stainless Steel Treated Water (Internal)
Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 5 components, and Damage piping elements Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Zinc Air -Indoor None External Surfaces F, 3 Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis F, 4 (B.2.1.26)
One-Time Inspection F, 4 (B.2.1.21)
Pump Casing Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A (HPCS Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Pump Casing Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A (Water Leg Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Carbon or Low Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A Alloy Steel with Uncontrolled (External)
Monitoring of Mechanical Stainless Steel Components (B.2.1.24)
Cladding Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A I I_ (B.2.1.21)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-35 Section 3 -Aging Management Review Results Table 3.2.2-1 High Pressure Core Spray System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing Pressure Boundary Carbon or Low Treated Water (Internal)
Loss of Material Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B (Water Leg Pump) Alloy Steel with Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Stainless Steel Corrosion (B.2.1.10)
Cladding Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Strainer Element Filter Stainless Steel Treated Water Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Pressure Boundary Stainless Steel Treated Water Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
_Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B LaSalle Countyjon, Units 1 and 2 License lication 0 Page 3.2-36 Section 3 -Aging Manageent Review Results Table 3.2.2-1 High Pressure Core Spray System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (9.2.1.21)
__________Water Chemistry (B.2.1 .2) V.D2.EP-73 3.2.1-17 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-37 Section 3 -Aging Management Review Results Table 3.2.2-1 High Pressure Core Spray System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1 801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. Components in the Treated Water (External) environment are associated with the submerged HPCS suction strainer assemblies.
: 2. The Bolting Integrity (B.2. 1.11) program is substituted to manage the aging effect applicable to this component type, material, and environment combination.
Submerged bolting for the HPCS System suction strainers in the suppression pool is visually inspected for the loss of material during each ISI inspection interval in conjunction with underwater suppression pool inspections.
: 3. Component is zinc casting, and in an air-indoor uncontrolled (external) environment there are no aging effects requiring management.
Nonetheless, the External Surfaces Monitoring of Mechanical Components (B.2.1.24) program is credited for ensuring the absence of any aging effects.4. Component is zinc casting, and in a lubricating oil (internal) environment the component is susceptible to loss of material.5. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.LaSalle County, *on, Units 1 and 2 Page 3.2-38 License Rene l lication 0 Section 3 -Aging gemaent Review Results Table 3.2.2-2 Low Pressure Core Spray System Summary of Aging Management Evaluation Table 3.2.2-2 Low Pressure Core Spray System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 A Bolting Stainless Steel Treated Water Loss of Material Bolting Integrity (B.2.1.11)
V.D2.EP-73 3.2.1-17 E, 1, 2 Bolting (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-122 3.2.1-15 A, 1 Flow Device Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Throttle Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-39 Section 3 -Aging Management Review Results Table 3.2.2-2 Low Pressure Core Spray System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item T _Management Piping, piping components, and piping elements Leakage Boundary Carbon Steel Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16 A Water Chemistry (B.2.1.2)1 V.D2.EP-60 3.2.1-16 B Glass Air- Indoor None None V.F.EP-15 3.2.1-60 A Uncontrolled (External)
I Treated Water (Internal)
None None V.F.EP-29 3.2.1-60 A Stainless Steel Air- Indoor Uncontrolled (External)
None None V.F.EP-18 3.2.1-63 A Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A Water Chemistry (B.2.1.2)V.D2.EP-73 3.2.1-17 B Pressure Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
V.E.E-44 3.2.1-40 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Treated Water Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A, 1 (External) (B.2.1.21)
I_Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B, 1 Treated Water (Internal)
Cumulative Fatigue Damage TLAA V.D2.E-10 3.2.1-1 A, 5 Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16 A Water Chemistry (B.2.1.2)V.D2.EP-60 3.2.1-16 B Copper Alloy with less than 15%Zinc Air -Indoor Uncontrolled (External)
None None V.F.EP-1 0 3.2.1-57 A'F 4 .4. .4 Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
VIII.A.SP-101 3.4.1-16 A__________
____________
-_________
-_____________________________
: a. u _________
a _____LaSalle Units 1 and 2 License Rene1 plication.Page 3.2-40 9 0 Section 3 -Aging Manag Review Results Table 3.2.2-2 Low Pressure Core Spray System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Copper Alloy with Treated Water (Internal)
Loss of Material Water Chemistry (B.2.1.2)
VIII.A.SP-101 3.4.1-16 B components, and less than 15%pipiping elements Zinc Glass Air- Indoor None None V.F.EP-15 3.2.1-60 A Uncontrolled (External)
Lubricating Oil (Internal)
None None V.F.EP-16 3.2.1-60 A Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Zinc Air -Indoor None External Surfaces F, 3 Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis F, 4 (B.2.1.26)
One-Time Inspection F, 4 (8.2.1.21)
Pump Casing Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (LPCS Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Pump Casing Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (Water Leg Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A L _ _ I__ _Corrosion (B.2.1.10) , I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-41 Section 3 -Aging Management Review Results Table 3.2.2-2 Low Pressure Core Spray System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing Pressure Boundary Carbon or Low Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (Water Leg Pump) Alloy Steel with Uncontrolled (External)
Monitoring of Mechanical Stainless Steel Components (B.2.1.24)
Cladding Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (8.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (8.2.1.2)
V.D2.EP-73 3.2.1-17 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Strainer Element Filter Stainless Steel Treated Water Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A, 1 (External)
(8.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B, 1 Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Pressure Boundary Stainless Steel Treated Water Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A, 1 (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B, 1 Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (8.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Valve Body Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
LaSalle ion, Units 1 and 2 License Rene p lication 0 Page 3.2-42 Section 3 -Aging Management Review Results Table 3.2.2-2 Low Pressure Core Spray System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item I Management Valve Body Leakage Boundary Carbon Steel Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-43 Section 3 -Aging Management Review Results Table 3.2.2-2 Low Pressure Core Spray System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. Components in the Treated Water (External) environment are associated with the submerged LPCS System suction strainers.
: 2. The Bolting Integrity (B.2.1.11) program is substituted to manage the aging effect applicable to this component type, material, and environment combination.
Submerged bolting for the LPCS System suction strainers in the suppression pool is visually inspected for the loss of material during each ISI inspection interval in conjunction with underwater suppression pool inspections.
: 3. Component is zinc casting, and in an air-indoor uncontrolled (external) environment there are no aging effects requiring management.
Nonetheless, the External Surfaces Monitoring of Mechanical Components (B.2.1.24) program is credited for ensuring the absence of any aging effects.4. Component is zinc casting, and in a lubricating oil (internal) environment the component is susceptible to loss of material.5. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.LaSalle County ion, Units 1 and 2 _ _Page 3.2-44 License ReneW W lication 0 Section 3 -Aging #t Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System Summary of Aging Management Evaluation Table 3.2.2-3 Reactor Core Isolation Cooling System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 A Bolting Stainless Steel Air -Indoor Loss of Material Bolting Integrity (8.2.1.11)
V.E.EP-70 3.2.1-13 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 A Treated Water Loss of Material Bolting Integrity (B.2.1.11)
V.D2.EP-73 3.2.1-17 E, 1, 2 (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-122 3.2.1-15 A, 1 Flow Device Pressure Boundary Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Throttle Stainless Steel Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Heat Exchanger-Pressure Boundary Copper Alloy with Air- Indoor None None V.F.EP-10 3.2.1-57 C (Lube Oil Cooler) 15% Zinc or More Uncontrolled (External)
Shell Side Components LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-45 Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Pressure Boundary Copper Alloy with Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-76 3.2.1-50 C (Lube Oil Cooler) 15% Zinc or More (B.2.1.26)
Shell Side One-Time Inspection V.D2.EP-76 3.2.1-50 C Components (B.2.1.21)
Copper Alloy with Air -Indoor None None V.F.EP-10 3.2.1-57 C less than 15% Uncontrolled (External)
Zinc Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-76 3.2.1-50 C (B.2.1.26)
One-Time Inspection V.D2.EP-76 3.2.1-50 C (B.2.1.21)
Heat Exchanger
-Pressure Boundary Copper Alloy with Lubricating Oil Loss of Material Lubricating Oil Analysis V.D2.EP-76 3.2.1-50 C (Lube Oil Cooler) less than 15% (External) (B.2.1.26)
Tube Sheet Zinc One-Time Inspection V.D2.EP-76 3.2.1-50 C (B.2.1.21)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.A.SP-101 3.4.1-16 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.A.SP-101 3.4.1-16 D Heat Exchanger
-Heat Transfer Copper Alloy with Lubricating Oil Reduction of Heat Lubricating Oil Analysis V.D2.EP-78 3.2.1-51 A (Lube Oil Cooler) 15% Zinc or More (External)
Transfer (B.2.1.26)
Tubes One-Time Inspection V.D2.EP-78 3.2.1-51 A (B.2.1.21)
Treated Water (Internal)
Reduction of Heat One-Time Inspection VIII.E.SP-100 3.4.1-18 A Transfer (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-100 3.4.1-18 B Pressure Boundary Copper Alloy with Lubricating Oil Loss of Material Lubricating Oil Analysis V.D2.EP-76 3.2.1-50 C 15% Zinc or More (External) (B.2.1.26)
One-Time Inspection V.D2.EP-76 3.2.1-50 C I I I I I__ _ _ _ _ _ _ _ (B.2.1.21)
I I I I LaSalle County.10jon, Units 1 and 2 License RenevW lication.Page 3.2-46 Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Pressure Boundary Copper Alloy with Treated Water (Internal)
Cracking One-Time Inspection H, 7 (Lube Oil Cooler) 15% Zinc or More (B.2.1.21)
Tubes Water Chemistry (B.2.1.2)
H, 7 Loss of Material One-Time Inspection VIII.A.SP-101 3.4.1-16 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.A.SP-101 3.4.1-16 D Selective Leaching VII.F1.AP-65 3.3.1-72 A (B.2.1.22)
Hoses Leakage Boundary Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 A Corrosion (B.2.1.10)
Glass Air -Indoor None None V.F.EP-15 3.2.1-60 A Uncontrolled (External)
Treated Water (Internal)
None None V.F.EP-29 3.2.1-60 A Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
_LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-47 Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Leakage Boundary Stainless Steel Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A Water Chemistry (B.2.1.2)V.D2.EP-73 3.2.1-17 B 4 4__ __ __ __ _ __ _ ---.E-- ---- 32.1-17 B Pressure Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
V.E.E-44 3.2.1-40 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Steam (Internal)
Loss of Material One-Time Inspection VIII.B2.SP-160 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-160 3.4.1-14 B Wall Thinning Flow-Accelerated V.D2.E-07 3.2.1-11 A Corrosion (B.2.1.10)
Treated Water Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A, 1 (External) (B.2.1.21)
_Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B, 1 Treated Water (Internal)
Cumulative Fatigue Damaae TLAA V.D2.E-10 3.2.1-1 A, 8 Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11 A Glass Air -Indoor None None V.F.EP-15 3.2.1-60 A Uncontrolled (External)
Lubricating Oil (Internal)
None None V.F.EP-16 3.2.1-60 A Treated Water (Internal)
None None V.F.EP-29 3.2.1-60 A Stainless Steel Air -Indoor Uncontrolled (External)
None None V.F.EP-18 3.2.1-63 A LaSalle CountyAon, Units 1 and 2 License Rene Page 3.2-48 Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Stainless Steel Air -Outdoor (External)
Cracking External Surfaces V.D2.EP-103 3.2.1-7 A components, and Monitoring of Mechanical piping elements Components (B.2.1.24)
Loss of Material External Surfaces V.D2.EP-107 3.2.1-4 A Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D1 .EP-80 3.2.1-50 A (B.2.1.26)
One-Time Inspection V.D1.EP-80 3.2.1-50 A (B.2.1.21)
Soil (External)
Cracking Buried and Underground H, 5 Piping (B.2.1.28)
Loss of Material Buried and Underground V.D2.EP-72 3.2.1-53 A Piping (B.2.1.28)
Treated Water (Internal)
Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 8 Damage Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Zinc Air -Indoor None External Surfaces F, 3 Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis F, 4 (B.2.1.26)
One-Time Inspection F, 4 (B.2.1.21)
Pump Casing Leakage Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (Condenser Uncontrolled (External)
Monitoring of Mechanical Condensate Pump) Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-49 Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item[ t Management Pump Casing Leakage Boundary Gray Cast Iron Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (Condenser (B.2.1.21)
Condensate Pump) Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Selective Leaching VII.E4.AP-31 3.3.1-72 A (B.2.1.22)
Pump Casing Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (Condenser Uncontrolled (External)
Monitoring of Mechanical Vacuum Pump) Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (RCIC Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Pump Casing Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (Turbine Main Oil Uncontrolled (External)
Monitoring of Mechanical Pump) Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Pump Casing Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (Water Leg Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B LaSalle Countvtion, Units 1 and 2 License Rene w p lication 0 Page 3.2-50 0 0 Section 3 -Aging Management Review Results 0 Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing Pressure Boundary Carbon Steel Treated Water (Internal)
Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A (Water Leg Pump) Corrosion (B.2.1.10)
Carbon or Low Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Alloy Steel with Uncontrolled (External)
Monitoring of Mechanical Stainless Steel Components (B.2.1.24)
Cladding Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Treated Water (internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Wall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 A Corrosion (B.2.1.10)
Rupture Disks Pressure Boundary Nickel Alloy Air -Indoor None None V.F.EP-17 3.2.1-61 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-274 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Strainer Element Filter Carbon Steel Lubricating Oil Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (External) (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-51 Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Strainer Element Filter Carbon Steel Treated Water (External)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16 A, 1 Water Chemistry (B.2.1.2)V.D2.EP-60 3.2.1-16 B, 1 Treated Water (internal:
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16 A Water Chemistry (B.2.1.2)V.D2.EP-60 3.2.1-16 B Stainless Steel Treated Water (External)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A, 1 Water Chemistry (B.2.1.2)V.D2.EP-73 3.2.1-17 B, 1 Treated Water (Internal Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A Water Chemistry (B.2.1.2)V.D2.EP-73 3.2.1-17 B Pressure Boundary Carbon Steel Lubricating Oil (External)
Loss of Material Lubricating Oil Analysis (B.2.1.26)
V.D2.EP-77 3.2.1-49 A One-Time Inspection (B.2.1.21)
V.D2.EP-77 3.2.1-49 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Treated Water Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A, 1 (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B, 1 Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16 A Water Chemistry (B.2.1.2)V.D2.EP-60 3.2.1-16 B Stainless Steel Treated Water (External)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A, 1 Water Chemistry (B.2.1.2)V.D2.EP-73 3.2.1-17 B, 1 Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A__________________
a ____________________
a ________________
i _______________________
U _________________________
: i.
* A +/- +/- _________LaSalle Countylion, Units 1 and 2 License Rene~yP lication Page 3.2-52 Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Strainer Element Pressure Boundary Stainless Steel Treated Water (Internal)
Loss of Material Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Tanks (Turbine Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Lube Oil (with internal Uncontrolled (External)
Monitoring of Mechanical Reservoirs) coating) Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Coating Integrity Service Level III and H, 6 Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 C (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 C (B.2.1.21)
Tanks (Vacuum Leakage Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A Tank) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 C (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 D Selective Leaching VII.E4.AP-31 3.3.1-72 C (B.2.1.22)
Turbine Casings Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 A (RCIC Turbine) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-53 Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item ManMgement Valve Body Leakage Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
V.E.E-44 3.2.1-40 A Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16 A-4 4 I.Water Chemistry (B.2.1.2)V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11 A 4 1- 1 + 4 4 Pressure Boundary I Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Comoonents (B.2.1 .24)V.E.E-44 3.2.1-40 A Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Steam (Internal)
Loss of Material One-Time Inspection VIII.B2.SP-160 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-160 3.4.1-14 B Wall Thinning Flow-Accelerated V.D2.E-07 3.2.1-11 A Corrosion (B.2.1.10)
Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16 A Water Chemistry (B.2.1.2)V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11 A LaSalle County on, Units 1 and 2 License ReneW plication Page 3.2-54 0Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Stainless Steel Air -Outdoor (External)
Cracking External Surfaces V.D2.EP-103 3.2.1-7 A Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces V.D2.EP-107 3.2.1-4 A Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (P.2.1.2)
V.D2.EP-73 3.2.1-17 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-55 Section 3 -Aging Management Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. Components in the Treated Water (External) environment are associated with the submerged RCIC suction strainer assemblies.
: 2. The Bolting Integrity (B.2.1.11) program is substituted to manage the aging effect applicable to this component type, material, and environment combination.
Submerged bolting for the RCIC System suction strainers in the suppression pool is visually inspected for the loss of material during each ISI inspection interval in conjunction with underwater suppression pool inspections.
: 3. Component is zinc casting, and in an air-indoor uncontrolled (external) environment there are no aging effects requiring management.
Nonetheless, the External Surfaces Monitoring of Mechanical Components (B.2.1.24) program is credited for ensuring the absence of any aging effects.4. Component is zinc casting, and in a lubricating oil (internal) environment the component is susceptible to loss of material.5. The aging effects for stainless steel components in a soil (external) environment include cracking.
The Buried and Underground Piping (B.2.1.28) program will be used to manage the applicable aging effects for this component, material, and environment combination.
LaSalle Countv..4 ion, Units 1 and 2 Page 3.2-56 License Rene Wplication 0 0 0 0 Section 3- Aging Managelnt Review Results Table 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Plant Specific Notes: (continued)
: 6. The aging effects for carbon steel (with internal coating) in a lubricating oil environment include loss of coating integrity.
The Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable to carbon steel (with internal coating) in a lubricating oil environment.
: 7. The aging effects for copper alloy with 15% zinc or more in a treated water environment include cracking.
The One-Time Inspection (B.2.1 .21)program and Water Chemistry (B.2.1.2) program are used to manage cracking for copper alloy with 15% zinc or more in a treated water environment.
: 8. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-57 Section 3 -Aging Management Review Results Table 3.2.2-4 Residual Heat Removal System Summary of Aging Management Evaluation Table 3.2.2-4 Residual Heat Removal System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 A Bolting Stainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 A Treated Water Loss of Material Bolting Integrity (B.2.1.11)
V.D2.EP-73 3.2.1-17 E, 1,2 (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-122 3.2.1-15 A, 1 Flow Device Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Nickel Alloy Air- Indoor None None V.F.EP-17 3.2.1-61 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection G, 3 (B.2.1.21)
Water Chemistry (B.2.1.2)
G, 3 Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A ( B.2.1.21)
__r 3.2.1-17 B[Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B LaSalle Countvlon, Units 1 and 2 License Rene V P lication.Page 3.2-58 0 0 Section 3- Aging Management Review Results Table 3.2.2-4 Residual Heat Removal System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Flow Device Throttle Nickel Alloy Treated Water (Internal)
Loss of Material One-Time Inspection G, 3 (B.2.1.21)
Water Chemistry (B.2.1.2)
G, 3 Stainless Steel Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Heat Exchanger
-Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A (RHR Heat Uncontrolled (External)
Monitoring of Mechanical Exchanger)
Shell Components (B.2.1.24)
Side Components Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 C (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 D Heat Exchanger-Pressure Boundary Stainless Steel Treated Water Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 C (RHR Heat (External) (B.2.1.21)
Exchanger)
Tube Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 D Sheet Heat Exchanger
-Heat Transfer Stainless Steel Treated Water Reduction of Heat One-Time Inspection V.D2.EP-74 3.2.1-19 A (RHR Heat (External)
Transfer (B.2.1.21)
Exchanger)
Tubes Water Chemistry (B.2.1.2)
V.D2.EP-74 3.2.1-19 B Pressure Boundary Stainless Steel Treated Water Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 C (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 D Hoses Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-59 Section 3 -Aging Management Review Results Table 3.2.2-4 Residual Heat Removal System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Leakage Boundary Stainless Steel Air -Indoor Uncontrolled (External)
None None V.F.EP-1 8 3.2.1-63 A Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17 A 4 + 4 Water Chemistry (B.2.1.2)V.D2.EP-73 3.2.1-17 B Pressure Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
V.D2.E-26 3.2.1-40 A Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 A (B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 A (B.2.1.21)
Treated Water Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A, 1 (External) (B.2.1.21)
_Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B, 1 Treated Water (Internal)
Cumulative Fatigue Damaae TLAA V.D2.E-10 3.2.1-1 A, 4 Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11 A Glass Air -Indoor Uncontrolled (External)
None None V.F.EP-15 3.2.1-60 A Lubricating Oil (Internal) 1 None None I V.F.EP-16 3.2.1-60 1 A Treated Water (Internal)
None None V.F.EP-29 3.2.1-60 A LaSalle County iion, Units 1 and 2 License Rene plication 0 Page 3.2-60 0 Section 3 -Aging Manageent Review Results Table 3.2.2-4 Residual Heat Removal System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 A components, and Uncontrolled (External) piping elements Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Pump Casing Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A (RHR Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Pump Casing Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A (Water Leg Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Carbon or Low Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A Alloy Steel with Uncontrolled (External)
Monitoring of Mechanical Stainless Steel Components (B.2.1.24)
Cladding Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Spray Nozzles Spray Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 A I Uncontrolled (External)
I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-61 Section 3 -Aging Management Review Results Table 3.2.2-4 Residual Heat Removal System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item I E Management Spray Nozzles Spray Stainless Steel Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Strainer Element Filter Stainless Steel Treated Water Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A, 1 (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B, 1 Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Pressure Boundary Stainless Steel Treated Water Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A, 1 (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B, 1 Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Valve Body Leakage Boundary Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-60 3.2.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 B Wall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 A Corrosion (B.2.1.10)
Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 A_ _ Uncontrolled (External)
LaSalle Countiw ion, Units 1 and 2 License ReneW plication.Page 3.2-62 Section 3 -Aging Management Review Results Table 3.2.2-4 Residual Heat Removal System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Stainless Steel Treated Water (Internal)
Loss of Material One-Time Inspection V.D2.EP-73 3.2.1-17 A (B.2.1.21)
__Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-63 Section 3 -Aging Management Review Results Table 3.2.2-4 Residual Heat Removal System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. Components in the Treated Water (External) environment are associated with the submerged RHR suction strainer assemblies.
: 2. The Bolting Integrity (B.2.1.11) program is substituted to manage the aging effect applicable to this component type, material, and environment combination.
Submerged bolting for the RHR System suction strainers in the suppression pool is visually inspected for the loss of material during each ISI inspection interval in conjunction with underwater suppression pool inspections.
: 3. The Water Chemistry (B.2.1.2) program and One-Time Inspection (B.2.1.21) program are used to manage the aging effect(s) applicable to this component type, material, and environment combination.
: 4. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.LaSalle Count~~ ion, Units 1 and 2 License ReneW plication O Page 3.2-64 Section 3 -Aging Management Review Results Table 3.2.2-5 Standby Gas Treatment System Summary of Aging Management Evaluation Table 3.2.2-5 Standby Gas Treatment System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 A Bolting Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 C Uncontrolled (External)
Ducting and Leakage Boundary Stainless Steel Condensation Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 C, 1 Components (External)
Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Aluminum Alloy Air -Indoor None None V.F.EP-3 3.2.1-56 C Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Carbon Steel Air -Indoor Loss of Material External Surfaces V.B.E-26 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-65 Section 3 -Aging Management Review Results Table 3.2.2-5 Standby Gas Treatment System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Ducting and Pressure Boundary Elastomers Air -Indoor Hardening and Loss of External Surfaces V.B.EP-59 3.2.1-38 A Components Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 2 Strength Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Glass Air -Indoor None None V.F.EP-15 3.2.1-60 C Uncontrolled (External)
Condensation (Internal)
None None V.F.EP-66 3.2.1-60 C Flexible Pressure Boundary Elastomers Air- Indoor Hardening and Loss of External Surfaces V.B.EP-59 3.2.1-38 A Connection Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.F1.AP-113 3.3.1-82 A Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 2 Strength Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Loss of Material Inspection of Internal G, 2 Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Piping, piping Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.B.E-26 3.2.1-40 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements I I Components (B.2.1.24)
LaSalle Countyjion, Units 1 and 2 License Rene V 1lication Page 3.2-66 Section 3 -Aging Management Review Results Table 3.2.2-5 Standby Gas Treatment System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 A components, and Surfaces in Miscellaneous piping elements Piping and Ducting Components (B.2.1.25)
Copper Alloy with Air -Indoor None None V.F.EP-10 3.2.1-57 A less than 15% Uncontrolled (External)
Zinc Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Structural Integrity Carbon Steel Air- Indoor Loss of Material External Surfaces V.B.E-26 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Valve Body Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.B.E-26 3.2.1-40 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Copper Alloy with Air -Indoor None None V.F.EP-10 3.2.1-57 A 15% Zinc or More Uncontrolled (External) 1_1_1_1 _ 1 LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.2-67 Section 3 -Aging Management Review Results Table 3.2.2-5 Standby Gas Treatment System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Copper Alloy with Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A 15% Zinc or More Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
I LaSalle Countwnion, Units 1 and 2 License ReneW plication.Page 3.2-68 Section 3 -Aging Management Review Results Table 3.2.2-5 Standby Gas Treatment System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The stainless steel drip pans are located internal to the ventilation ductwork, and therefore the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the applicable aging effects.2. The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the aging effect(s)applicable to this component type, material, and environment combination.
LaSalle County Station, Units 1 and 2 Page 3.2-69 License Renewal Application This Page Intentionally Left Blank Section 3 -Aging Management Review Results.3.3 3.3.1 AGING MANAGEMENT OF AUXILIARY SYSTEMS INTRODUCTION This section provides the results of the aging management review for those components identified in Section 2.3.3, Auxiliary Systems, as being subject to aging management review. The systems, or portions of systems, which are addressed in this section are described in the indicated sections.* Closed Cycle Cooling Water System (2.3.3.1)* Combustible Gas Control System (2.3.3.2)* Compressed Air System (2.3.3.3)" Control Rod Drive System (2.3.3.4)" Control Room Ventilation System (2.3.3.5)" Cranes, Hoists and Refueling Equipment System (2.3.3.6)* Demineralized Water Makeup System (2.3.3.7)" Diesel Generator and Auxiliaries System (2.3.3.8)" Drywell Pneumatic System (2.3.3.9)" Electrical Penetration Pressurization System (2.3.3.10)" Essential Cooling Water System (2.3.3.11)
* Fire Protection System (2.3.3.12)
* Fuel Pool Cooling and Storage System (2.3.3.13)
* Nonessential Cooling Water System (2.3.3.14)" Nonsafety-Related Ventilation System (2.3.3.15)
* Plant Drainage System (2.3.3.16)
* Primary Containment Ventilation System (2.3.3.17)" Process Radiation Monitoring System (2.3.3.18)" Process Sampling and Post Accident Monitoring System (2.3.3.19)
* Radwaste System (2.3.3.20)
* Reactor Water Cleanup System (2.3.3.21)
* Safety-Related Ventilation System (2.3.3.22)
* Standby Liquid Control System (2.3.3.23)
* Suppression Pool Cleanup System (2.3.3.24)
* Traversing Incore Probe System (2.3.3.25)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-1 Section 3 -Aging Management Review Results 3.3.2 RESULTS The following tables summarize the results of the aging management review for Auxiliary Systems.Table 3.3.2-1 Closed Cycle Cooling Water System -Summary of Aging Management Evaluation Table 3.3.2-2 Combustible Gas Control System -Summary of Aging Management Evaluation Table 3.3.2-3 Compressed Air System -Summary of Aging Management Evaluation Table 3.3.2-4 Control Rod Drive System -Summary of Aging Management Evaluation Table 3.3.2-5 Control Room Ventilation System -Summary of Aging Management Evaluation Table 3.3.2-6 Cranes, Hoists and Refueling Equipment System -Summary of Aging Management Evaluation Table 3.3.2-7 Demineralized Water Makeup System -Summary of Aging Management Evaluation Table 3.3.2-8 Diesel Generator and Auxiliaries System -Summary of Aging Management Evaluation Table 3.3.2-9 Drywell Pneumatic System -Summary of Aging Management Evaluation Table 3.3.2-10 Electrical Penetration Pressurization System -Summary of Aging Management Evaluation Table 3.3.2-11 Essential Cooling Water System -Summary of Aging Management Evaluation Table 3.3.2-12 Fire Protection System -Summary of Aging Management Evaluation Table 3.3.2-13 Fuel Pool Cooling and Storage System -Summary of Aging Management Evaluation Table 3.3.2-14 Nonessential Cooling Water System -Summary of Aging Management Evaluation Table 3.3.2-15 Nonsafety-Related Ventilation System -Summary of Aging Management Evaluation Table 3.3.2-16 Plant Drainage System -Summary of Aging Management Evaluation Table 3.3.2-17 Primary Containment Ventilation System -Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 Page 3.3-2 License Renewal Application Section 3 -Aging Management Review Results Table 3.3.2-18 Process Radiation Monitoring System -Summary of Aging Management Evaluation Table 3.3.2-19 Process Sampling and Post Accident Monitoring System -Summary of Aging Management Evaluation Table 3.3.2-20 Radwaste System -Summary of Aging Management Evaluation Table 3.3.2-21 Reactor Water Cleanup System -Summary of Aging Management Evaluation Table 3.3.2-22 Safety-Related Ventilation System -Summary of Aging Management Evaluation Table 3.3.2-23 Standby Liquid Control System -Summary of Aging Management Evaluation Table 3.3.2-24 Suppression Pool Cleanup System -Summary of Aging Management Evaluation Table 3.3.2-25 Traversing Incore Probe System -Summary of Aging Management Evaluation Materials, Environments, Aging Effects Requiring Management And Aging Management Programs Closed Cycle Cooling Water System Materials The materials of construction for the Closed Cycle Cooling Water System components are:* Carbon Steel* Carbon and Low Alloy Steel Bolting" Copper Alloy with less than 15% Zinc* Glass* Gray Cast Iron" Stainless Steel.3.3.2.1 3.3.2.1.1 LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-3 Section 3 -Aging Management Review Results Environments The Closed Cycle Cooling Water System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Air/Gas -Dry* Closed Cycle Cooling Water* Closed Cycle Cooling Water > 140 F" Condensation
* Lubricating Oil Aging Effects Requiring Management The following aging effects associated with the Closed Cycle Cooling Water System components require management: " Cracking* Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Closed Cycle Cooling Water System components:
* Bolting Integrity (B.2.1.11)
* Closed Treated Water Systems (B.2.1.13)" External Surfaces Monitoring of Mechanical Components (B.2.1.24)" Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* Lubricating Oil Analysis (B.2.1.26)
* One-Time Inspection (B.2.1.21)
* Selective Leaching (B.2.1.22) 3.3.2.1.2 Combustible Gas Control System Materials The materials of construction for the Combustible Gas Control System components are:* Carbon Steel" Carbon and Low Alloy Steel Bolting* Glass LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-4 Section 3 -Aging Management Review Results* Stainless Steel* Stainless Steel Bolting Environments The Combustible Gas Control System components are exposed to the following environments:
* Air -Indoor Uncontrolled" Condensation
* Waste Water Aging Effects Requiring Management The following aging effects associated with the Combustible Gas Control System components require management:
* Loss of Material" Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Combustible Gas Control System components: " Bolting Integrity (B.2.1.11)" External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) 3.3.2.1.3 Compressed Air System Materials The materials of construction for the Compressed Air System components are:* Carbon Steel* Carbon and Low Alloy Steel Bolting" Copper Alloy with less than 15% Zinc Environments The Compressed Air System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Condensation LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-5 Section 3 -Aging Management Review Results Aging Effects Requiring Management The following aging effects associated with the Compressed Air System components require management: " Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Compressed Air System components:
* Bolting Integrity (B.2.1.11)
* Compressed Air Monitoring (B.2.1.15)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24) 3.3.2.1.4 Control Rod Drive System Materials The materials of construction for the Control Rod Drive System components are:* Carbon Steel* Carbon and Low Alloy Steel Bolting* Glass* Gray Cast Iron* Stainless Steel" Stainless Steel Bolting Environments The Control Rod Drive System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Condensation
* Lubricating Oil* Treated Water* Waste Water Aging Effects Requiring Management The following aging effects associated with the Control Rod Drive System components require management:
* Cumulative Fatigue Damage* Loss of Material LaSalle County Station, Units 1 and 2 Page 3.3-6 License Renewal Application Section 3 -Aging Management Review Results* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Control Rod Drive System components: " Bolting Integrity (B.2.1.11)" External Surfaces Monitoring of Mechanical Components (B.2.1.24)" Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)" Lubricating Oil Analysis (B.2.1.26)
* One-Time Inspection (B.2.1.21)" TLAA" Water Chemistry (B.2.1.2)3.3.2.1.5 Control Room Ventilation System Materials The materials of construction for the Control Room Ventilation System components are: " Aluminum Alloy* Carbon Steel* Carbon and Low Alloy Steel Bolting* Copper Alloy with 15% Zinc or More" Copper Alloy with less than 15% Zinc* Ductile Cast Iron* Elastomers" Galvanized Steel" Glass* Stainless Steel* Stainless Steel Bolting Environments The Control Room Ventilation System components are exposed to the following environments: " Air -Indoor Uncontrolled
* Air/Gas -Dry* Condensation LaSalle County Station, Units 1 and 2 Page 3.3-7 License Renewal Application Section 3 -Aging Management Review Results* Lubricating Oil* Waste Water Aging Effects Requiring Management The following aging effects associated with the Control Room Ventilation System components require management: " Hardening and Loss of Strength" Loss of Material" Loss of Preload* Reduction of Heat Transfer Aging Management Programs The following aging management programs manage the aging effects for the Control Room Ventilation System components:
* Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)" Lubricating Oil Analysis (B.2.1.26)" One-Time Inspection (B.2.1.21) 3.3.2.1.6 Cranes, Hoists and Refueling Equipment System Materials The materials of construction for the Cranes, Hoists and Refueling Equipment System components are:* Aluminum Alloy* Carbon Steel* Carbon and Low Alloy Steel Bolting* Stainless Steel* Stainless Steel Bolting Environments The Cranes, Hoists and Refueling Equipment System components are exposed to the following environments:
* Air -Indoor Uncontrolled" Treated Water LaSalle County Station, Units 1 and 2 Page 3.3-8 License Renewal Application Section 3 -Aging Management Review Results Aging Effects Requiring Management The following aging effects associated with the Cranes, Hoists and Refueling Equipment System components require management:
* Cumulative Fatigue Damage* Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Cranes, Hoists and Refueling Equipment System components: " Inspection of Overhead Heavy Load and Light Load (Related to Refueling)
Handling Systems (B.2.1.14)
* TLAA" Water Chemistry (B.2.1.2)3.3.2.1.7 Demineralized Water Makeup System Materials The materials of construction for the Demineralized Water Makeup System components are: " Carbon Steel* Carbon and Low Alloy Steel Bolting* Copper Alloy with 15% Zinc or More* Copper Alloy with less than 15% Zinc" Galvanized Steel" Glass" Gray Cast Iron" Stainless Steel Environments The Demineralized Water Makeup System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Treated Water LaSalle County Station, Units 1 and 2 Page 3.3-9 License Renewal Application Section 3 -Aging Management Review Results Aging Effects Requiring Management The following aging effects associated with the Demineralized Water Makeup System components require management:
* Cracking* Loss of Coating Integrity* Loss of Material" Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Demineralized Water Makeup System components:
* Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* One-Time Inspection (B.2.1.21)
* Selective Leaching (B.2.1.22)
* Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)* Water Chemistry (B.2.1.2) 0 3.3.2.1.8 Diesel Generator and Auxiliaries System Materials The materials of construction for the Diesel Generator and Auxiliaries System components are: " Aluminum Alloy* Carbon Steel" Carbon and Low Alloy Steel Bolting* Copper Alloy with 15% Zinc or More" Copper Alloy with less than 15% Zinc" Ductile Cast Iron" Elastomers" Glass" Gray Cast Iron" Stainless Steel* Stainless Steel Bolting LaSalle County Station, Units 1 and 2 Page 3.3-10 License Renewal Application Section 3 -Aging Management Review Results Environments The Diesel Generator and Auxiliaries System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Air -Outdoor* Closed Cycle Cooling Water" Condensation
* Diesel Exhaust* Fuel Oil* Lubricating Oil* Soil* Waste Water Aging Effects Requiring Management The following aging effects associated with the Diesel Generator and Auxiliaries System components require management:
* Cracking* Cumulative Fatigue Damage* Hardening and Loss of Strength* Loss of Material* Loss of Preload" Reduction of Heat Transfer Aging Management Programs The following aging management programs manage the aging effects for the Diesel Generator and Auxiliaries System components:
* Bolting Integrity (B.2.1.11)
* Buried and Underground Piping (B.2.1.28)" Closed Treated Water Systems (B.2.1.13)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Fuel Oil Chemistry (B.2.1.19)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* Lubricating Oil Analysis (B.2.1.26)
LaSalle County Station, Units 1 and 2 Page 3.3-11 License Renewal Application Section 3 -Aging Management Review Results" One-Time Inspection (B.2.1.21)" Selective Leaching (B.2.1.22)" TLAA 3.3.2.1.9 Drywell Pneumatic System Materials The materials of construction for the Drywell Pneumatic System components are:* Aluminum Alloy* Carbon Steel* Carbon and Low Alloy Steel Bolting* Copper Alloy with 15% Zinc or More* Copper Alloy with less than 15% Zinc* Ductile Cast Iron* Glass* Gray Cast Iron* Nickel Alloy* Polymers* Stainless Steel* Stainless Steel Bolting Environments The Drywell Pneumatic System components are exposed to the following environments: " Air -Indoor Uncontrolled
* Air/Gas -Dry* Closed Cycle Cooling Water" Condensation
* Lubricating Oil* Waste Water Aging Effects Requiring Management The following aging effects associated with the Drywell Pneumatic System components require management:
* Change in Material Properties" Loss of Material* Loss of Preload LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-12 Section 3 -Aging Management Review Results Aging Management Programs The following aging management programs manage the aging effects for the Drywell Pneumatic System components: " Bolting Integrity (B.2.1.11)
* Closed Treated Water Systems (B.2.1.13)
* Compressed Air Monitoring (B.2.1.15)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* Lubricating Oil Analysis (B.2.1.26)
* One-Time Inspection (B.2.1.21)
* Selective Leaching (B.2.1.22) 3.3.2.1.10 Electrical Penetration Pressurization System Materials The materials of construction for the Electrical Penetration Pressurization System components are: " Carbon Steel* Stainless Steel Environments The Electrical Penetration Pressurization System components are exposed to the following environments: " Air -Indoor Uncontrolled" Air/Gas -Dry Aging Effect Requiring Management The following aging effect associated with the Electrical Penetration Pressurization System components requires management:
* Loss of Material Aging Management Program The following aging management program manages the aging effects for the Electrical Penetration Pressurization System components:
& External Surfaces Monitoring of Mechanical Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-13 Section 3 -Aging Management Review Results 3.3.2.1.11 Essential Cooling Water System Materials The materials of construction for the Essential Cooling Water System components are: " Carbon Steel" Carbon Steel (with internal coating)* Carbon and Low Alloy Steel Bolting* Carbon or Low Alloy Steel with Stainless Steel Cladding" Copper Alloy with 15% Zinc or More" Copper Alloy with 15% Zinc or More (with internal coating)" Copper Alloy with less than 15% Zinc* Gray Cast Iron* Stainless Steel" Stainless Steel Bolting Environments The Essential Cooling Water System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Air -Outdoor" Concrete* Condensation" Lubricating Oil" Raw Water" Soil* Treated Water Aging Effects Requiring Management The following aging effects associated with the Essential Cooling Water System components require management:
* Cracking* Loss of Coating Integrity* Loss of Material" Loss of Preload* Reduction of Heat Transfer LaSalle County Station, Units 1 and 2 Page 3.3-14 License Renewal Application Section 3 -Aging Management Review Results Aging Management Programs The following aging management programs manage the aging effects for the Essential Cooling Water System components: " Bolting Integrity (B.2.1.11)" Buried and Underground Piping (B.2.1.28)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Lubricating Oil Analysis (B.2.1.26)" One-Time Inspection (B.2.1.21)" Open-Cycle Cooling Water System (B.2.1.12)
* Selective Leaching (B.2.1.22)
* Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)* Water Chemistry (B.2.1.2)3.3.2.1.12 Fire Protection System Materials The materials of construction for the Fire Protection System components are:* Aluminum Silicate" Calcium Silicate* Carbon Steel* Carbon and Low Alloy Steel Bolting" Ceramic Fiber" Concrete Block" Copper Alloy with less than 15% Zinc* Ductile Cast Iron* Elastomers
* Galvanized Steel* Glass* Gray Cast Iron* Grout" Gypsum* Mineral Fiber* Pyrocrete LaSalle County Station, Units 1 and 2 Page 3.3-15 License Renewal Application Section 3 -Aging Management Review Results" Reinforced Concrete* Stainless Steel* Stainless Steel Bolting Environments The Fire Protection System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Air -Outdoor* Air/Gas -Dry* Condensation" Diesel Exhaust* Raw Water* Soil Aging Effects Requiring Management The following aging effects associated with the Fire Protection System components require management:
* Change in Material Properties
* Concrete Cracking and Spalling* Cracking* Cumulative Fatigue Damage" Loss of Coating Integrity" Loss of Material" Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Fire Protection System components: " Bolting Integrity (B.2.1.11)
* Buried and Underground Piping (B.2.1.28)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Fire Protection (B.2.1.16)" Fire Water System (B.2.1.17)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
LaSalle County Station, Units 1 and 2 Page 3.3-16 License Renewal Application Section 3 -Aging Management Review Results" Selective Leaching (B.2.1.22)
* Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)* Structures Monitoring (B.2.1.34)" TLAA 3.3.2.1.13 Fuel Pool Cooling and Storage System Materials The materials of construction for the Fuel Pool Cooling and Storage System components are:* Aluminum Alloy* Boral* Carbon Steel" Carbon and Low Alloy Steel Bolting* Glass* Rio-Tinto Alcan Composite" Stainless Steel* Stainless Steel Bolting Environments The Fuel Pool Cooling and Storage System components are exposed to the following environments: " Air -Indoor Uncontrolled
* Condensation" Treated Water" Waste Water Aging Effects Requiring Management The following aging effects associated with the Fuel Pool Cooling and Storage System components require management:
* Loss of Material* Loss of Preload* Reduction of Neutron Absorbing Capacity; Change in Dimensions and Loss of Material LaSalle County Station, Units 1 and 2 Page 3.3-17 License Renewal Application Section 3 -Aging Management Review Results Aging Management Programs The following aging management programs manage the aging effects for the Fuel Pool Cooling and Storage System components: " Bolting Integrity (B.2.1.11)" External Surfaces Monitoring of Mechanical Components (B.2.1.24)" Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)" Monitoring of Neutron-Absorbing Materials Other Than Boraflex (B.2.1.27)
* One-Time Inspection (B.2.1.21)
* Water Chemistry (B.2.1.2)3.3.2.1.14 Nonessential Cooling Water System Materials The materials of construction for the Nonessential Cooling Water System components are:* Aluminum Alloy* Carbon Steel* Carbon steel (with external coating)* Carbon Steel (with internal coating)" Carbon and Low Alloy Steel Bolting* Copper Alloy with less than 15% Zinc* Gray Cast Iron* Stainless Steel Environments The Nonessential Cooling Water System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Air -Outdoor" Air/Gas -Dry" Concrete* Condensation
* Raw Water" Soil LaSalle County Station, Units 1 and 2 Page 3.3-18 License Renewal Application Section 3 -Aging Management Review Results Aging Effects Requiring Management The following aging effects associated with the Nonessential Cooling Water System components require management:
* Cracking* Loss of Coating Integrity* Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Nonessential Cooling Water System components:
* Bolting Integrity (B.2.1.11)
* Buried and Underground Piping (B.2.1.28)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Open-Cycle Cooling Water System (B.2.1.12)
* Selective Leaching (B.2.1.22)
* Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)3.3.2.1.15 Nonsafety-Related Ventilation System Materials The materials of construction for the Nonsafety-Related Ventilation System components are:* Carbon Steel* Carbon and Low Alloy Steel Bolting* Copper Alloy with less than 15% Zinc* Ductile Cast Iron* Glass* Stainless Steel Environments The Nonsafety-Related Ventilation System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Air/Gas -Dry* Closed Cycle Cooling Water LaSalle County Station, Units 1 and 2 Page 3.3-19 License Renewal Application Section 3 -Aging Management Review Results* Condensation Aging Effects Requiring Management The following aging effects associated with the Nonsafety-Related Ventilation System components require management: " Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Nonsafety-Related Ventilation System components:
* Bolting Integrity (B.2.1.11)
* Closed Treated Water Systems (B.2.1.13)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) 3.3.2.1.16 Plant Drainage System Materials The materials of construction for the Plant Drainage System components are: " Carbon Steel" Carbon and Low Alloy Steel Bolting" Copper Alloy with less than 15% Zinc" Ductile Cast Iron* Galvanized Steel* Glass* Polymers" Stainless Steel Environments The Plant Drainage System components are exposed to the following environments: " Air -Indoor Uncontrolled" Concrete* Condensation
* Waste Water LaSalle County Station, Units 1 and 2 Page 3.3-20 License Renewal Application Section 3 -Aging Management Review Results Aging Effects Requiring Management The following aging effects associated with the Plant Drainage System components require management: " Loss of Coating Integrity" Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Plant Drainage System components:
* Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)" Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)3.3.2.1.17 Primary Containment Ventilation System Materials The materials of construction for the Primary Containment Ventilation System components are: " Carbon Steel* Carbon and Low Alloy Steel Bolting* Copper Alloy with 15% Zinc or More" Copper Alloy with less than 15% Zinc* Gray Cast Iron* Stainless Steel Environments The Primary Containment Ventilation System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Air/Gas -Dry* Closed Cycle Cooling Water" Condensation" Lubricating Oil LaSalle County Station, Units 1 and 2 Page 3.3-21 License Renewal Application Section 3 -Aging Management Review Results* Waste Water Aging Effects Requiring Management The following aging effects associated with the Primary Containment Ventilation System components require management:
* Loss of Material" Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Primary Containment Ventilation System components: " Bolting Integrity (B.2.1.11)" Closed Treated Water Systems (B.2.1.13)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* Lubricating Oil Analysis (B.2.1.26)" One-Time Inspection (B.2.1.21)" Selective Leaching (B.2.1.22) 3.3.2.1.18 Process Radiation Monitoring System Materials The materials of construction for the Process Radiation Monitoring System components are:* Aluminum Alloy* Carbon Steel* Carbon and Low Alloy Steel Bolting* Copper Alloy with less than 15% Zinc* Glass" Stainless Steel" Stainless Steel Bolting Environments The Process Radiation Monitoring System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Closed Cycle Cooling Water LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-22 Section 3 -Aging Management Review Results* Condensation" Raw Water" Waste Water Aging Effects Requiring Management The following aging effects associated with the Process Radiation Monitoring System components require management:
* Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Process Radiation Monitoring System components:
* Bolting Integrity (B.2.1.11)
* Closed Treated Water Systems (B.2.1.13)" External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* Open-Cycle Cooling Water System (B.2.1.12) 3.3.2.1.19 Process Sampling and Post Accident Monitoring System Materials The materials of construction for the Process Sampling and Post Accident Monitoring System components are:* Aluminum Alloy* Carbon Steel* Carbon and Low Alloy Steel Bolting* Carbon or Low Alloy Steel with Stainless Steel Cladding* Copper Alloy with 15% Zinc or More* Glass* Stainless Steel* Stainless Steel Bolting LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-23 Section 3 -Aging Management Review Results Environments The Process Sampling and Post Accident Monitoring System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Air/Gas -Dry* Closed Cycle Cooling Water* Condensation" Treated Water* Waste Water Aging Effects Requiring Management The following aging effects associated with the Process Sampling and Post Accident Monitoring System components require management: " Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Process Sampling and Post Accident Monitoring System components:
* Bolting Integrity (B.2.1.11)
* Closed Treated Water Systems (B.2.1.13)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)" Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* One-Time Inspection (B.2.1.21)
* Selective Leaching (B.2.1.22)" Water Chemistry (B.2.1.2)3.3.2.1.20 Radwaste System Materials The materials of construction for the Radwaste System components are:* Carbon Steel" Carbon and Low Alloy Steel Bolting* Ductile Cast Iron* Stainless Steel LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-24 Section 3 -Aging Management Review Results* Stainless Steel Bolting Environments The Radwaste System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Condensation
* Treated Water Aging Effects Requiring Management The following aging effects associated with the Radwaste System components require management:
* Loss of Material" Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Radwaste System components:
* Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* One-Time Inspection (B.2.1.21)
* Water Chemistry (B.2.1.2)3.3.2.1.21 Reactor Water Cleanup System Materials The materials of construction for the Reactor Water Cleanup System components are: " Carbon Steel* Carbon and Low Alloy Steel Bolting* Carbon or Low Alloy Steel with Stainless Steel Cladding* Glass" Stainless Steel LaSalle County Station, Units I and 2 Page 3.3-25 License Renewal Application Section 3 -Aging Management Review Results Environments The Reactor Water Cleanup System components are exposed to the following environments: " Air -Indoor Uncontrolled
* Treated Water* Treated Water > 140 F Aging Effects Requiring Management The following aging effects associated with the Reactor Water Cleanup System components require management:
* Cracking" Cumulative Fatigue Damage" Loss of Material* Loss of Preload* Wall Thinning Aging Management Programs The following aging management programs manage the aging effects for the Reactor Water Cleanup System components:
* Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Flow-Accelerated Corrosion (B.2.1.10)
* One-Time Inspection (B.2.1.21)" TLAA* Water Chemistry (B.2.1.2)3.3.2.1.22 Safety-Related Ventilation System Materials The materials of construction for the Safety-Related Ventilation System components are:* Aluminum Alloy* Carbon Steel" Copper Alloy with 15% Zinc or More* Copper Alloy with less than 15% Zinc* Elastomers
* Galvanized Steel LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-26 Section 3 -Aging Management Review Results* Stainless Steel Environments The Safety-Related Ventilation System components are exposed to the following environments: " Air -Indoor Uncontrolled
* Condensation
* Waste Water Aging Effects Requiring Management The following aging effects associated with the Safety-Related Ventilation System components require management: " Hardening and Loss of Strength" Loss of Material* Reduction of Heat Transfer Aging Management Programs The following aging management programs manage the aging effects for the Safety-Related Ventilation System components:
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)" Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) 3.3.2.1.23 Standby Liquid Control System Materials The materials of construction for the Standby Liquid Control System components are: " Carbon Steel* Carbon and Low Alloy Steel Bolting* Copper Alloy with 15% Zinc or More" Glass" Stainless Steel* Stainless Steel Bolting LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-27 Section 3 -Aging Management Review Results Environments The Standby Liquid Control System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Condensation
* Sodium Pentaborate Solution" Treated Water" Waste Water Aging Effects Requiring Management The following aging effects associated with the Standby Liquid Control System components require management:
* Cracking* Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Standby Liquid Control System components:
* Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* One-Time Inspection (B.2.1.21)
* Selective Leaching (B.2.1.22)
* Water Chemistry (B.2.1.2)Suppression Pool Cleanup System Materials The materials of construction for the Suppression Pool Cleanup System components are: 3.3.2.1.24
* Carbon Steel* Carbon and Low Alloy Steel Bolting* Gray Cast Iron* Stainless Steel Environments LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-28 Section 3 -Aging Management Review Results The Suppression Pool Cleanup System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Treated Water Aging Effects Requiring Management The following aging effects associated with the Suppression Pool Cleanup System components require management:
* Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Suppression Pool Cleanup System components: " Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* One-Time Inspection (B.2.1.21)
* Selective Leaching (B.2.1.22)
* Water Chemistry (B.2.1.2)Traversing Incore Probe System Materials The materials of construction for the Traversing Incore Probe System components are: 0 Stainless Steel Environments The Traversing Incore Probe System components are exposed to the following environments: " Air -Indoor Uncontrolled
* Condensation Aging Effect Requiring Management The following aging effect associated with the Traversing Incore Probe System components requires management:
* Loss of Material 3.3.2.1.25 LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-29 Section 3 -Aging Management Review Results Aging Management Programs The following aging management program manages the aging effects for the Traversing Incore Probe System components:
Compressed Air Monitoring (B.2.1.15) 3.3.2.2 AMR Results for Which Further Evaluation is Recommended by the GALL Report NUREG-1 801 provides the basis for identifying those programs that warrant further evaluation by the reviewer in the license renewal application.
For the Auxiliary Systems, those programs are addressed in the following subsections.
3.3.2.2.1 Cumulative Fatigue Damage Fatigue is a TLAA as defined in 10 CFR 54.3. TLAAs are required to be evaluated in accordance with 10 CFR 54.21(c).
The evaluation of metal fatigue as a TLAA for the Feedwater System, High Pressure Core Spray System, Reactor Coolant Pressure Boundary System, Reactor Core Isolation Cooling System, and Reactor Water Cleanup System is discussed in Section 4.3. The evaluation of crane load cycles as a TLAA for the Cranes, Hoists and Refueling Equipment System is discussed in Section 4.7.3.3.2.2.2 Cracking due to Stress Corrosion Cracking and Cyclic Loading Cracking due to SCC and cyclic loading could occur in stainless steel PWR non-regenerative heat exchanger components exposed to treated borated water greater than 60 0 C (>140 0 F) in the chemical and volume control system. The existing aging management program on monitoring and control of primary water chemistry in PWRs manages the aging effects of cracking due to SCC. However, control of water chemistry does not preclude cracking due to SCC and cyclic loading. Therefore, the effectiveness of the water chemistry control program should be verified to ensure that cracking is not occurring.
The GALL Report recommends that a plant-specific aging management program be evaluated to verify the absence of cracking due to SCC and cyclic loading to ensure that these aging effects are managed adequately.
An acceptable verification program is to include temperature and radioactivity monitoring of the shell side water, and eddy current testing of tubes.Item Number 3.3.1-3 is applicable to PWRs only and is not used for LSCS.3.3.2.2.3 Cracking due to Stress Corrosion Cracking Cracking due to stress corrosion cracking could occur for stainless steel piping, piping components, piping elements and tanks exposed to outdoor air. The possibility of cracking also extends to components exposed to air which has recently been introduced into buildings, i.e., components near intake vents. Cracking is only known to occur in environments containing sufficient halides (primarily chlorides) and in which condensation or deliquescence is possible.
Condensation or deliquescence should generally be assumed to be possible.
Applicable outdoor air environments (and associated indoor air environments) include, but are not limited to, those within approximately 5 miles of a saltwater coastline, those within 1/2 mile of a highway which LaSalle County Station, Units 1 and 2 Page 3.3-30 License Renewal Application Section 3 -Aging Management Review Results is treated with salt in the wintertime, those areas in which the soil contains more than trace chlorides, those plants having cooling towers where the water is treated with chlorine or chlorine compounds, and those areas subject to chloride contamination from other agricultural or industrial sources. This item is applicable for the environments described above.GALL AMP Xl. M36, "External Surfaces Monitoring, " is an acceptable method to manage the aging effect. The applicant may demonstrate that this item is not applicable by describing the outdoor air environment present at the plant and demonstrating that external chloride stress corrosion cracking is not expected.
The GALL Report recommends further evaluation to determine whether an adequate aging management program is used to manage this aging effect based on the environmental conditions applicable to the plant and ASME Code Section Xl requirements applicable to the components.
LSCS will implement the External Surfaces Monitoring of Mechanical Components (B.2.1.24) program to manage cracking due to stress corrosion cracking in stainless steel piping, piping components, and piping elements exposed to outdoor air in the Diesel Generator and Auxiliaries System. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program provides for management of aging effects through periodic visual inspection of external surfaces for evidence of cracking.
Any visible evidence of cracking will be evaluated for acceptability of continued service. Deficiencies will be documented in accordance with the 10 CFR Part 50, Appendix B Corrective Action Program. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program is described in Appendix B.3.3.2.2.4 Loss of Material due to Cladding Breach Loss of material due to cladding breach could occur for PWR steel charging pump casings with stainless steel cladding exposed to treated borated water. The GALL Report references NRC Information Notice 94-63, "Boric Acid Corrosion of Charging Pump Casings Caused by Cladding Cracks," and recommends further evaluation of a plant-specific aging management program to ensure that the aging effect is adequately managed. Acceptance criteria are described in Branch Technical Position RLSB- I (Appendix A. I of this SRP-LR).Item Number 3.3.1-5 is applicable to PWRs only and is not used for LSCS.3.3.2.2.5 Loss of Material due to Pitting and Crevice Corrosion Loss of material due to pitting and crevice corrosion could occur for stainless steel piping, piping components, piping elements, and tanks exposed to outdoor air. The possibility of pitting and crevice corrosion also extends to components exposed to air which has recently been introduced into buildings, i.e., components near intake vents.Pitting and crevice corrosion is only known to occur in environments containing sufficient halides (primarily chlorides) and in which condensation or deliquescence is possible.Condensation or deliquescence should generally be assumed to be possible.
Applicable outdoor air environments (and associated indoor air environments) include, but are not limited to, those within approximately 5 miles of a saltwater coastline, those within 1/2 LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-31 Section 3 -Aging Management Review Results mile of a highway which is treated with salt in the wintertime, those areas in which the soil contains more than trace chlorides, those plants having cooling towers where the water is treated with chlorine or chlorine compounds, and those areas subject to chloride contamination from other agricultural or industrial sources. This item is applicable for the environments described above.GALL AMP X1. M36, "External Surfaces Monitoring, "is an acceptable method to manage the aging effect. The applicant may demonstrate that this item is not applicable by describing the outdoor air environment present at the plant and demonstrating that external pitting or crevice corrosion is not expected.
The GALL Report recommends further evaluation to determine whether an adequate aging management program is used to manage this aging effect based on the environmental conditions applicable to the plant and ASME Code Section X1 requirements Quality Assurance for Aging Management of Nonsafety-Related Components.
LSCS will implement the External Surfaces Monitoring of Mechanical Components (B.2.1.24) program to manage the loss of material due to pitting and crevice corrosion in stainless steel piping, piping components, and piping elements exposed to outdoor air in the Diesel Generator and Auxiliaries System. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program provides for management of aging effects through periodic visual inspection of external surfaces for evidence of the loss of material.
Any visible evidence of the loss of material will be evaluated for acceptability of continued service. Deficiencies will be documented in accordance with the 10 CFR Part 50, Appendix B Corrective Action Program. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program is described in Appendix B.3.3.2.2.6 Quality Assurance for Aging Management of Nonsafety-Related Components QA provisions applicable to License Renewal are discussed in Section B.1.3.3.3.2.2.7 Ongoing Review of Operating Experience Ongoing review of operating experience is addressed in Appendix A, Section A. 1.6 and Appendix B, Section B.1.4.3.3.2.2.8 Loss of Material due to Recurring Internal Corrosion Recurring internal corrosion can result in the need to augment AMPs beyond the recommendations in the GALL Report. During the search of plant-specific OE conducted during the LRA development, recurring internal corrosion can be identified by the number of occurrences of aging effects and the extent of degradation at each localized corrosion site. This further evaluation item is applicable if the search of plant-specific OE reveals repetitive occurrences (e.g., one per refueling outage cycle that has occurred over: (a)three or more sequential or nonsequential cycles for a 10-year OE search, or (b) two or more sequential or nonsequential cycles for a 5-year OE search) of aging effects with the same aging mechanism in which the aging effect resulted in the component either not meeting plant-specific acceptance criteria or experiencing a reduction in wall thickness greater than 50 percent (regardless of the minimum wall thickness.)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-32 Section 3 -Aging Management Review Results The GALL Report recommends that a plant-specific AMP, or a new or existing AMP, be evaluated for inclusion of augmented requirements to ensure the adequate management of any recurring aging effect(s).
Potential augmented requirements include: alternative examination methods (e.g., volumetric versus external visual), augmented inspections (e.g., a greater number of locations, additional locations based on risk insights based on susceptibility to aging effect and consequences of failure, a greater frequency of inspections), and additional trending parameters and decision points where increased inspections would be implemented.
Acceptance criteria are described in Appendix A. 1,"Aging Management Review -Generic (Branch Technical Position RSLB-1)." The applicant states: (a) why the program's examination methods will be sufficient to detect the recurring aging effect before affecting the ability of a component to perform its intended function, (b) the basis for the adequacy of augmented or lack of augmented inspections, (c) what parameters will be trended as well as the decision points where increased inspections would be implemented (e.g., the extent of degradation at individual corrosion sites, the rate of degradation change), (d) how inspections of components that are not easily accessed (i.e., buried, underground) will be conducted, and (e) how leaks in any involved buried or underground components will be identified.
Each plant-specific operating experience example should be evaluated to determine if the chosen AMP should be augmented even if the thresholds for significance of aging effect or frequency of occurrence of aging effect have not been exceeded.
For example, during a 10-year search of plant specific operating experience, two instances of 360 degree 30 percent wall loss occurred at copper alloy to steel joints. Neither the significance of the aging effect nor the frequency of occurrence of aging effect threshold has been exceeded.
Nevertheless, the operating experience should be evaluated to determine if the AMP that is proposed to manage the aging effect is sufficient (e.g., method of inspection, frequency of inspection, number of inspections) to provide reasonable assurance that the CLB intended functions of the component will be met throughout the period of extended operation.
Likewise, the GALL Report AMR items associated with the new FE items only cite raw water and waste water environments because OE indicates that these are the predominant environments associated with recurring internal corrosion; however, if the search of plant-specific OE reveals recurring internal corrosion in other water environments (e.g., treated water), the aging effect should be addressed in a similar manner.LR-ISG-2012-02 has been issued which addresses instances of recurring internal corrosion identified during review of plant-specific operating experience.
The operating experience for LSCS has been reviewed and instances of internal corrosion in the Essential Cooling Water System, Nonessential Cooling Water System, Fire Protection System, and Plant Drainage System have been identified with a frequency that is consistent with the thresholds discussed in LR-ISG-2012-02.
LSCS will implement the following inspections:
: 1. The Open-Cycle Cooling Water System (B.2.1.12) program will be used to manage the loss of material due to recurring internal corrosion in above-ground and buried carbon steel piping exposed to raw water in the Essential Cooling Water System and Nonessential Cooling Water System. A minimum of ten (10) MIC degradation LaSalle County Station, Units 1 and 2 Page 3.3-33 License Renewal Application Section 3 -Aging Management Review Results inspections in aboveground Essential Cooling Water System piping and a minimum of ten (10) MIC degradation inspections in aboveground Nonessential Cooling Water System piping will be performed every 24 months until the frequency of MIC occurrences no longer meets the criteria for recurring internal corrosion.
These inspections supplement those that are being performed to implement the requirements of GL 89-13. A portion of these inspection locations will be selected with process conditions similar (e.g. flow, temperature) to those in buried portions of the piping to provide sufficient understanding of the condition of the buried piping.2. The Fire Water System (B.2.1.17) program will be used to manage the loss of material due to recurring internal corrosion in above-ground and buried carbon steel piping exposed to raw water in the Fire Protection System. Inspections will be performed at five locations in aboveground piping susceptible to MIC every year until the frequency of MIC occurrences no longer meets the criteria for recurring internal corrosion.
A portion of these inspection locations will be selected with process conditions similar (e. g. flow, temperature) to those in buried portions of the piping to provide sufficient understanding of the condition of the buried piping.3. The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program will be used to manage the loss of material due to recurring internal corrosion in above-ground carbon steel and galvanized steel piping exposed to waste water in the Plant Drainage System. Ten different locations will be inspected during each ten-year inspection period of this program. Inspections will continue until the frequency of occurrences no longer meets the criteria for recurring internal corrosion.
The inspections may consist of direct visual inspection, or wall thickness measurements using UT or other suitable techniques.
Where ultrasonic examinations are performed, the examination will consist of a full circumferential ultrasonic thickness scan in the area at a minimum of three inches on either side of the location of interest.
The entire boundary of any area found thinned is recorded, even if it extends beyond the original specified examination area. When inspections identify multiple corrosion sites, they are reviewed to determine if they may be evaluated as separate flaws to assess the structural integrity of the piping. The selected inspection locations will be periodically reviewed to validate their relevance and usefulness and adjusted as appropriate.
Evaluation of the inspection results will include (1) a comparison to the nominal wall thickness or previous wall thickness measurements to determine rate of corrosion degradation, (2) a comparison to the design minimum allowable wall thickness to determine the acceptability of the component for continued use, and (3) a determination of reinspection interval.
Additional locations will be examined if these examinations or plant operating experience identify significant degradation.
Where the degradation is identified in ASME Section III portions of piping, the applicable ASME Section III requirements for augmented examinations will be utilized.
Where the degradation is identified in non-ASME Section III portions of piping, the following supplemental inspection criteria will be used. For through-wall leaks and material loss greater than 50 percent of nominal wall, four additional locations will be examined.
Where the identified material loss is 30 percent to 50 percent of nominal wall thickness and the calculated remaining life is less than two years, two additional locations will be examined.
For the Essential Cooling Water system, an operability evaluation is performed for degraded LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-34 Section 3 -Aging Management Review Results conditions that involve system leakage or the measured remaining pipe wall thickness is less than design thickness.
The operability evaluation includes reviews for loss of flow, water spraying on surrounding SSC, flooding, and potential for flaw propagation.
Based on the operability evaluation, any appropriate compensatory actions are identified and implemented until such time as repair or replacement is completed.
Deficiencies will be documented in accordance with the 10 CFR Part 50, Appendix B Corrective Action Program. The Open-Cycle Cooling Water System (B.2.1.12) program, Fire Water System (B.2.1.17) program, and Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program are described in Appendix B.3.3.2.3 Time-Limited Aging Analysis The time-limited aging analyses identified below are associated with the Auxiliary Systems components:
* Section 4.3, Metal Fatigue Analyses* Section 4.7, Other Plant-Specific Time-Limited Aging Analysis 3.
 
==3.3 CONCLUSION==
 
The Auxiliary Systems piping, fittings, and components that are subject to aging management review have been identified in accordance with the requirements of 10 CFR 54.4. The aging management programs selected to manage aging effects for the Auxiliary Systems components are identified in the summaries in Section 3.3.2.1 above.A description of these aging management programs is provided in Appendix B, along with the demonstration that the identified aging effects will be managed for the period of extended operation.
Therefore, based on the conclusions provided in Appendix B, the effects of aging associated with the Auxiliary Systems components will be adequately managed so that there is reasonable assurance that the intended functions are maintained consistent with the current licensing basis during the period of extended operation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-35 This Page Intentionally Left Blank
* 0 Section 3 -Aging Managementew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effectl Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-1 Steel Cranes: structural Cumulative fatigue Fatigue is a time-limited Yes, TLAA Fatigue is a TLAA; further evaluation is girders exposed to Air- damage aging analysis (TLAA) to documented in Subsection 3.3.2.2.1.
indoor, uncontrolled due to fatigue be evaluated for the (External) period of extended operation for structural girders of cranes that fall within the scope of 10 CFR 54 (Standard Review Plan, Section 4.7,"Other Plant-Specific Time-Limited Aging Analyses," for generic guidance for meeting the requirements of 10 CFR 54.21 (c)(1))3.3.1-2 Stainless steel, Steel Cumulative fatigue Fatigue is a time-limited Yes, TLAA Fatigue is a TLAA; further evaluation is Heat exchanger damage aging analysis (TLAA) to documented in Subsection 3.3.2.2.1.
components and tubes, due to fatigue be evaluated for the Piping, piping period of extended components, and piping operation.
See the SRP, elements exposed to Section 4.3 "Metal Treated borated water, Fatigue," for acceptable Air -indoor, uncontrolled, methods for meeting the Treated water requirements of 10 CFR 54.21 (c)(1).3.3.1-3 PWR Only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-36 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-4 Stainless steel Piping, Cracking Chapter XI.M36, Yes, environmental Consistent with NUREG-1801.
The piping components, and due to stress "External Surfaces conditions need to External Surfaces Monitoring of Mechanical piping elements; tanks corrosion cracking Monitoring of Mechanical be evaluated Components (B.2.1.24) program will be exposed to Air -outdoor Components" used to manage cracking of stainless steel piping, piping components, and piping elements exposed to air -outdoor in the Diesel Generator and Auxiliaries System.See subsection 3.3.2.2.3.
3.3.1-5 PWR Only 3.3.1-6 Stainless steel Piping, Loss of material Chapter XI.M36, Yes, environmental Consistent with NUREG-1801.
The piping components, and due to pitting and "External Surfaces conditions need to External Surfaces Monitoring of Mechanical piping elements; tanks crevice corrosion Monitoring of Mechanical be evaluated Components (B.2.1.24) program will be exposed to Air -outdoor Components" used to manage loss of material of stainless steel piping, piping components, and piping elements exposed to air -outdoor in the Diesel Generator and Auxiliaries System.See subsection 3.3.2.2.5.
3.3.1-7 PWR Only 3.3.1-8 PWR Only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-37 Section 3 -Aging Manag nteview Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-9 PWR Only 3.3.1-10 Steel, high-strength Cracking Chapter XI.M18, "Bolting No Not Applicable.
Closure bolting exposed due to stress Integrity" There is no steel, high-strength closure to Air with steam or water corrosion cracking; tis nosed hith-steam ore leakage cyclic loading bolting exposed to air with steam or water leakage in Auxiliary Systems.3.3.1-11 Steel, high-strength High- Cracking Chapter XI.M18, "Bolting No Not Applicable.
pressure pump, closure due to stress Integrity" There is no steel, high-strength high-bolting exposed to Air corrosion cracking; prere is closureng high-with steam or water cyclic loading pressure pump, closure bolting exposed to leakage air with steam or water leakage in Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-38 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-12 Steel; stainless steel Loss of material Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Bolting Closure bolting, Bolting due to general (steel Integrity" Integrity (B.2.1.11) program will be used to exposed to only), pitting, and manage loss of material of carbon and low Condensation, Air -crevice corrosion alloy steel bolting and stainless steel bolting indoor, uncontrolled exposed to air -indoor uncontrolled in the (External), Air -outdoor Closed Cycle Cooling Water System, (External)
Combustible Gas Control System, Compressed Air System, Control Rod Drive System, Control Room Ventilation System, Demineralized Water Makeup System, Diesel Generator and Auxiliaries System, Drywell Pneumatic System, Essential Cooling Water System, Fire Protection System, Fuel Pool Cooling and Storage System, Nonessential Cooling Water System, Nonsafety-Related Ventilation System, Plant Drainage System, Primary Containment Ventilation System, Process Radiation Monitoring System, Process Sampling and Post Accident Monitoring System, Radwaste System, Reactor Water Cleanup System, Standby Liquid Control System, and Suppression Pool Cleanup System.3.3.1-13 Steel Closure bolting Loss of material Chapter XI.M18, "Bolting No Not Applicable.
exposed to Air with due to general Integrity" steam or water leakage corrosion There is no steel closure bolting exposed to air with steam or water leakage in Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-39 Section 3 -Aging Management~eview Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-14 Steel, Stainless Steel Loss of preload Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Bolting Bolting exposed to Soil Integrity" Integrity (B.2.1.11) program will be used to manage loss of preload of the carbon and low alloy steel bolting exposed to soil in the Fire Protection System.3.3.1-15 Steel; stainless steel, Loss of preload Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Bolting Copper alloy, Nickel due to thermal Integrity" Integrity (B.2.1.11) program will be used to alloy, Stainless steel effects, gasket creep, manage loss of preload of carbon and low Closure bolting, Bolting and self-loosening alloy steel bolting and stainless steel bolting exposed to Air -indoor, exposed to air -indoor uncontrolled and uncontrolled (External), raw water in the Closed Cycle Cooling Any environment, Air -Water System, Combustible Gas Control outdoor (External), Raw System, Compressed Air System, Control water, Treated borated Rod Drive System, Control Room water, Fuel oil, Treated Ventilation System, Demineralized Water water Makeup System, Diesel Generator and Auxiliaries System, Drywell Pneumatic System, Essential Cooling Water System, Fire Protection System, Fuel Pool Cooling and Storage System, Nonessential Cooling Water System, Nonsafety-Related Ventilation System, Plant Drainage System, Primary Containment Ventilation System, Process Radiation Monitoring System, Process Sampling and Post Accident Monitoring System, Radwaste System, Reactor Water Cleanup System, Standby Liquid Control System, and Suppression Pool Cleanup System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-40 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-16 Stainless steel Piping, Cracking Chapter XI.M2, 'Water No Not Applicable.
piping components, and due to stress Chemistry," and piping elements exposed corrosion cracking, Chapter XI.M25, "BWR The main process piping in the LSCS to Treated water >60'C intergranular stress Reactor Water Cleanup Reactor Water Cleanup (RWCU) System is (>140&deg;F) corrosion cracking System" carbon steel. There are no stainless steel piping, piping components, and piping elements -4 inch NPS exposed to treated water >60&deg;C (>140&deg;F).
Therefore, LSCS does not use the Chapter XI.M25, "BWR Reactor Water Cleanup System" program to manage cracking.Cracking in RWCU System stainless steel piping, piping components, and piping elements < 4 inch NPS exposed to treated water >60'C (>140&deg;F) is addressed in 3.3.1-19.3.3.1-17 Stainless steel Heat Reduction of heat Chapter XI.M2, 'Water No Not Applicable.
exchanger tubes transfer Chemistry," and exposed to Treated due to fouling Chapter XI.M32, "One- There are no stainless steel heat water, Treated borated Time Inspection" exchanger tubes exposed to treated water water or treated borated water in Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-41 0 9 Section 3 -Aging Managemeqiew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-18 Stainless steel High- Cracking Chapter XI.M2, 'Water No Not Applicable.
pressure pump, casing, due to stress Chemistry," and Piping, piping corrosion cracking Chapter XI.M32, "One- There are no stainless steel high-pressure components, and piping Time Inspection" pump, casing, piping, piping components, elements exposed to and piping elements exposed to treated Treated borated water borated water >60&deg;C (>140&deg;F) or sodium>60'C (>140'F), Sodium pentaborate solution >60. C (>140&deg;F) in pentaborate solution Auxiliary Systems.>60oC (>140'F)3.3.1-19 Stainless steel Cracking Chapter XI.M2, 'Water No Consistent with NUREG-1801 with Regenerative heat due to stress Chemistry," and exceptions.
The One-Time Inspection exchanger components corrosion cracking Chapter XI.M32, "One- (B.2.1.21) program and Water Chemistry exposed to Treated water Time Inspection" (B.2.1.2) program will be used to manage>60&deg;C (>140'F) cracking of the carbon or low alloy steel with stainless steel cladding and stainless steel regenerative heat exchanger components, piping, piping components, and piping elements exposed to treated water > 140'F in the Reactor Water Cleanup System.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-42 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-20 Stainless steel, Stainless Cracking Chapter XI.M2, "Water No Consistent with NUREG-1801 with steel; steel with stainless due to stress Chemistry," and exceptions.
The One-Time Inspection steel cladding Heat corrosion cracking Chapter XI.M32, "One- (B.2.1.21) program and Water Chemistry exchanger components Time Inspection" (B.2.1.2) program will be used to manage exposed to Treated cracking of the carbon or low alloy steel borated water >60&deg;C with stainless steel cladding and stainless (>140&deg;F), Treated water steel non-regenerative heat exchanger>60*C (>140&deg;F) components exposed to treated water >140'F in the Reactor Water Cleanup System.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-43 Section 3 -Aging ManagemenPeview Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-21 Steel Piping, piping Loss of material Chapter XI.M2, 'Water No Consistent with NUREG-1801 with components, and piping due to general, Chemistry," and exceptions.
The One-Time Inspection elements exposed to pitting, and crevice Chapter XI.M32, "One- (B.2.1.21) program and Water Chemistry Treated water corrosion Time Inspection" (B.2.1.2) program will be used to manage loss of material of carbon steel, ductile cast iron, and gray cast iron accumulator, heat exchanger components, piping, piping components, and piping elements, and tanks exposed to treated water in the Control Rod Drive System, Demineralized Water Makeup System, Fuel Pool Cooling and Storage System, Process Sampling and Post Accident Monitoring System, Radwaste System, Reactor Water Cleanup System, and Suppression Pool Cleanup System.An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-44 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-22 Copper alloy Piping, Loss of material Chapter XI.M2, 'Water No Consistent with NUREG-1 801 with piping components, and due to general, Chemistry," and exceptions.
The One-Time Inspection piping elements exposed pitting, crevice, and Chapter XI.M32, "One- (B.2.1.21) program and Water Chemistry to Treated water galvanic corrosion Time Inspection" (B.2.1.2) program will be used to manage loss of material of copper alloy with 15%zinc or more and copper alloy with less than 15% zinc piping, piping components, and piping elements exposed to treated water in the Demineralized Water Makeup System and Standby Liquid Control System.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.3.1-23 Aluminum Piping, piping Loss of material Chapter XI.M2, 'Water No Not Applicable.
components, and piping due to pitting and Chemistry," and The loss of material in aluminum piping, elements exposed to crevice corrosion Chapter XI.M32, "One- piping components, and piping elements Treated water Time Inspection" exposed to treated water is addressed in 3.3.1-25.3.3.1-24 Aluminum Piping, piping Loss of material Chapter XI.M2, 'Water No Not Applicable.
components, and piping due to pitting and Chemistry," and The loss of material in aluminum piping, elements exposed to crevice corrosion Chapter XI.M32, "One- piping components, and piping elements Treated water Time Inspection" exposed to treated water is addressed in 3.3.1-25.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-45 0 0 .Section 3 -Aging Management ew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-25 Stainless steel, Stainless Loss of material Chapter XI.M2, "Water No Consistent with NUREG-1801 with steel; steel with stainless due to pitting and Chemistry," and exceptions.
The One-Time Inspection steel cladding, Aluminum crevice corrosion Chapter XI.M32, "One- (B.2.1.21) program and Water Chemistry Piping, piping Time Inspection" (B.2.1.2) program will be used to manage components, and piping loss of material of aluminum, aluminum elements, Heat alloy, carbon or low alloy steel with exchanger components stainless steel cladding, and stainless steel exposed to Treated crane/hoist (fuel prep machine), heat water, Sodium exchanger components, miscellaneous pentaborate solution steel, piping, piping components, and piping elements, and tanks exposed to sodium pentaborate solution, treated water, and treated water > 140&deg;F in the Control Rod Drive System, Cranes, Hoists and Refueling Equipment System, Essential Cooling Water System, Fuel Pool Cooling and Storage System, Process Sampling and Post Accident Monitoring System, Radwaste System, Reactor Water Cleanup System, Standby Liquid Control System, Suppression Pool Cleanup System, and Structural Commodity Group.An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-46 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-26 Steel (with elastomer Loss of material Chapter XI.M2, 'Water No Not Applicable.
lining), Steel (with due to pitting and Chemistry," and elsoe iigor crevice corrosion Chapter XI.M32, "One- There are no steel (with elastomer lining)elastomer lining orceiecroin CatrXI3,"n-piping, piping components, and piping stainless steel cladding) (only for steel after Time Inspection" elements exposed to treated water in Piping, piping lining/cladding e lemen te ms .components, and piping degradation)
Auxiliary Systems.elements exposed to The loss of material in steel (with stainless Treated water steel cladding) piping, piping components, and piping elements exposed to treated water is addressed in 3.3.1-25.3.3.1-27 Stainless steel Heat Reduction of heat Chapter Xl.M2, 'Water No Consistent with NUREG-1801 with exchanger tubes transfer Chemistry," and exceptions.
The One-Time Inspection exposed to Treated water due to fouling Chapter XI.M32, "One- (B.2.1.21) program and Water Chemistry Time Inspection" (B.2.1.2) program will be used to manage reduction of heat transfer of stainless steel heat exchanger tubes exposed to treated water in the Essential Cooling Water System.An exception applies to the NUREG-1 801 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.3.1-28 PWR Only 3.3.1-29 PWR Only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-47 Section 3 -Aging Managementeiew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-30 Concrete; cementitious Changes in material Chapter XI.M20, "Open- No Not Applicable.
material Piping, piping properties Cycle Cooling Water components, and piping due to aggressive System" There are no concrete; cementitious elements exposed to chemical attack material piping, piping components, and elemnts ed tpiping elements exposed to raw water in Raw Water Auxiliary Systems.3.3.1-30x Fiberglass, HDPE Piping, Cracking, blistering, Chapter XI.M20, "Open- No Not Applicable.
piping components, and change in color Cycle Cooling Water There are no fiberglass, HDPE piping, piping elements exposed due to water System" pipin cpents, aD pipinge to Raw water (internal) absorption piping components, and piping elements exposed to raw water in Auxiliary Systems.3.3.1-31 Concrete; cementitious Cracking Chapter XI.M20, "Open- No Not Applicable.
material Piping, piping due to settling Cycle Cooling Water components, and piping System" There are no concrete; cementitious elements exposed to material piping, piping components, and Raw Water piping elements exposed to raw water in Auxiliary Systems.3.3.1-32 Reinforced concrete, Cracking Chapter XI.M20, "Open- No Not Applicable.
asbestos cement Piping, due to aggressive Cycle Cooling Water There are no reinforced concrete, asbestos piping components, and chemical attack and System" cement piping, piping components, and piping elements exposed leaching; c ement exp osed tompon e r in to Raw water Changes in material piping elements exposed to raw water in properties Auxiliary Systems.due to aggressive chemical attack LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-48 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-32x Elastomer seals and Hardening and loss of Chapter XI.M20, "Open- No Not Applicable.
components exposed to strength due to Cycle Cooling Water There are no elastomer seals and raw water elastomer System" components exposed to raw water in degradation; loss of Auxiliary Systems.material due to erosion 3.3.1-33 Concrete; cementitious Loss of material Chapter XI.M20, "Open- No Not Applicable.
material Piping, piping due to abrasion, Cycle Cooling Water There are no concrete; cementitious components, and piping cavitation, aggressive System" material piping, piping components, and elements exposed to chemical attack, and piping pipin g ompone r in Raw Water leaching piping elements exposed to raw water in Auxiliary Systems.3.3.1-34 Nickel alloy, Copper alloy Loss of material Chapter XI.M20, "Open- No Not Applicable.
Piping, piping due to general, Cycle Cooling Water components, and piping pitting, and crevice System" There are no nickel alloy piping, piping elements exposed to corrosion components, and piping elements exposed Raw water to raw water in Auxiliary Systems. The loss of material in copper alloy piping, piping components, and piping elements exposed to raw water is addressed in 3.3.1-36.3.3.1-35 Copper alloy Piping, Loss of material Chapter XI.M20, "Open- No Not Applicable.
piping components, and due to general, Cycle Cooling Water The loss of material in copper alloy piping, piping elements exposed pitting, crevice, and System" The o mpo nentserand piping , to Raw water microbiologically-piping components, and piping elements influenced corrosion exposed to raw water is addressed in 3.3.1-36.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-49 Section 3 -Aging Managementeiew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-36 Copper alloy Piping, Loss of material Chapter XI.M20, "Open- No Consistent with NUREG-1 801. The Open-piping components, and due to general, Cycle Cooling Water Cycle Cooling Water System (B.2.1.12) piping elements exposed pitting, crevice, and System" program will be used to manage loss of to Raw water microbiologically-material of copper alloy with less than 15%influenced corrosion; zinc piping, piping components, and piping fouling that leads to elements exposed to raw water in the corrosion Nonessential Cooling Water System and Process Radiation Monitoring System.3.3.1-37 Steel (with coating or Loss of material Chapter XI.M20, "Open- No Consistent with NUREG-1801.
The Open-lining) Piping, piping due to general, Cycle Cooling Water Cycle Cooling Water System (B.2.1.12) components, and piping pitting, crevice, and System" program will be used to manage loss of elements exposed to microbiologically-material of carbon steel (with internal Raw water influenced corrosion; coating) and carbon steel (with external fouling that leads to coating) heat exchanger components, corrosion; piping, piping components, and piping lining/coating elements, and traveling water screen degradation framework exposed to raw water in the Essential Cooling Water System and Nonessential Cooling Water System.The loss of coating integrity in carbon steel (with internal coating) and carbon steel (with external coating) heat exchanger components, piping, piping components, and piping elements, and traveling water screen framework is managed by the Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) plant-specific program.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-50 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-38 Copper alloy, Steel Heat Loss of material Chapter XI.M20, "Open- No Consistent with NUREG-1801.
The Open-exchanger components due to general, Cycle Cooling Water Cycle Cooling Water System (B.2.1.12) exposed to Raw water pitting, crevice, System" program will be used to manage loss of galvanic, and material of carbon steel, copper alloy with microbiologically-15% zinc or more, copper alloy with 15%influenced corrosion; zinc or more (with internal coating), copper fouling that leads to alloy with less than 15% zinc, and gray cast corrosion iron traveling water screen framework, heat exchanger components, piping, piping components, and piping elements exposed to raw water in the Essential Cooling Water System and Nonessential Cooling Water System.3.3.1-39 Stainless steel Piping, Loss of material Chapter XI.M20, "Open- No Not Applicable.
piping components, and due to pitting and Cycle Cooling Water The loss of material in stainless steel piping elements exposed crevice corrosion System" Thn poss omatentstand steel to Raw water piping, piping components, and piping elements exposed to raw water is addressed in 3.3.1-40.LaSalle County Station, Units 1 and 2 License Renewal Application 0 Page 3.3-51 0 0 Section 3-Aging Managernenteiew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-40 Stainless steel Piping, Loss of material Chapter XI.M20, "Open- No Consistent with NUREG-1801.
The Open-piping components, and due to pitting and Cycle Cooling Water Cycle Cooling Water System (B.2.1.12) piping elements exposed crevice corrosion; System" program will be used to manage loss of to Raw water fouling that leads to material of carbon or low alloy steel with corrosion stainless steel cladding and stainless steel fish barrier, heat exchanger components, piping, piping components, and piping elements in the Essential Cooling Water System, Nonessential Cooling Water System, and Process Radiation Monitoring System.3.3.1-41 Stainless steel Piping, Loss of material Chapter XI.M20, "Open- No The RG 1.127, Inspection of Water-Control piping components, and due to pitting, crevice, Cycle Cooling Water Structures Associated with Nuclear Power piping elements exposed and microbiologically-System" Plants (B.2.1.35) program has been to Raw water influenced corrosion substituted and will be used to manage the loss of material in stainless steel concrete anchors exposed to raw water in the Lake Screen House.3.3.1-42 Copper alloy, Titanium, Reduction of heat Chapter XI.M20, "Open- No Consistent with NUREG-1801.
The Open-Stainless steel Heat transfer Cycle Cooling Water Cycle Cooling Water System (B.2.1.12) exchanger tubes due to fouling System" program will be used to manage reduction exposed to Raw water of heat transfer of the copper alloy with 15% zinc or more, copper alloy with less than 15% zinc, and stainless steel heat exchanger tubes exposed to raw water in the Essential Cooling Water System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-52 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Component Aging Effect/ Aging Management Further Discussion Mechanism Programs Evaluation Recommended Stainless steel Piping, Cracking Chapter XI.M21A, No Consistent with NUREG-1801.
The Closed piping components, and due to stress "Closed Treated Water Treated Water Systems (B.2.1.13) program piping elements exposed corrosion cracking Systems" will be used to manage cracking of to Closed-cycle cooling stainless steel piping, piping components, water >60*C (>140&deg;F) and piping elements exposed to closed cycle cooling water > 140&deg;F in the Closed Cycle Cooling Water System.Stainless steel; steel with Cracking Chapter XI.M21A, No Consistent with NUREG-1801.
The Closed stainless steel cladding due to stress "Closed Treated Water Treated Water Systems (B.2.1.13) program Heat exchanger corrosion cracking Systems" will be used to manage cracking of components exposed to stainless steel heat exchanger components Closed-cycle cooling exposed to closed cycle cooling water >water >60&deg;C (>140&deg;F) 140'F in the Closed Cycle Cooling Water System.Steel Piping, piping components, and piping elements; tanks exposed to Closed-cycle cooling water Loss of material due to general, pitting, and crevice corrosion Chapter XI.M21A,"Closed Treated Water Systems" No Consistent with NUREG-1801.
The Closed Treated Water Systems (B.2.1.13) program will be used to manage loss of material of carbon steel, ductile cast iron, and gray cast iron piping, piping components, and piping elements and tanks exposed to closed cycle cooling water in the Closed Cycle Cooling Water System, Diesel Generator and Auxiliaries System, Drywell Pneumatic System, Nonsafety-Related Ventilation System, Primary Containment Ventilation System, and Process Sampling and Post Accident Monitoring System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-53 0 Section 3 -Aging Managementview Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Component Aging Effect/ Aging Management Further Discussion Mechanism Programs Evaluation Recommended Steel, Copper alloy Heat exchanger components, Piping, piping components, and piping elements exposed to Closed-cycle cooling water Loss of material due to general, pitting, crevice, and galvanic corrosion Chapter XI.M21A,"Closed Treated Water Systems" No Consistent with NUREG-1 801. The Closed Treated Water Systems (B.2.1.13) program will be used to manage loss of material of carbon steel, copper alloy with 15% zinc or more, copper alloy with less than 15% zinc, and gray cast iron heat exchanger components, piping, piping components, and piping elements exposed to closed cycle cooling water in the Closed Cycle Cooling Water System, Diesel Generator and Auxiliaries System, Nonsafety-Related Ventilation System, Primary Containment Ventilation System, and Process Radiation Monitoring System.3.3.1-47 Stainless steel; steel with Loss of material Chapter XI.M21A, No Not applicable.
stainless steel cladding due to "Closed Treated Water Microbiologically-influenced corrosion is not Heat exchanger microbiologically-Systems" a predicted aging mechanism for the loss of components exposed to influenced corrosion material in the closed cycle cooling water Closed-cycle cooling environment.
The loss of material in water stainless steel heat exchanger components exposed to closed cycle cooling water is addressed in Item Number 3.3.1-49.3.3.1-48 Aluminum Piping, piping Loss of material Chapter XI.M21A, No Not Applicable.
components, and piping due to pitting and "Closed Treated Water There are no aluminum piping, piping elements exposed to crevice corrosion Systems" componeno a nd piping p osed Closed-cycle cooling components, and piping elements exposed water to closed-cycle cooling water in Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-54 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effectl Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-49 Stainless steel Piping, Loss of material Chapter XL.M21A, No Consistent with NUREG-1801.
The Closed piping components, and due to pitting and "Closed Treated Water Treated Water Systems (B.2.1.13) program piping elements exposed crevice corrosion Systems" will be used to manage loss of material of to Closed-cycle cooling stainless steel heat exchanger water components, piping, piping components, and piping elements exposed to closed cycle cooling water and closed cycle cooling water > 140'F in the Closed Cycle Cooling Water System, Diesel Generator and Auxiliaries System, Nonsafety-Related Ventilation System, Primary Containment Ventilation System, Process Radiation Monitoring System, and Process Sampling and Post Accident Monitoring System.3.3.1-50 Stainless steel, Copper Reduction of heat Chapter XL.M21A, No Consistent with NUREG-1801.
The Closed Alloy, Steel Heat transfer "Closed Treated Water Treated Water Systems (B.2.1.13) program exchanger tubes due to fouling Systems" will be used to manage reduction of heat exposed to Closed-cycle transfer of copper alloy with 15% zinc or cooling water more heat exchanger tubes exposed to closed cycle cooling water in the Diesel Generator and Auxiliaries System.3.3.1-51 Boraflex Spent fuel Reduction of neutron- Chapter XI.M22, No Not applicable.
storage racks: neutron- absorbing capacity "Boraflex Monitoring" LSCS does not use Boraflex for neutron absorbing sheets (PWR), due to boraflex LsCSpdon not se fl sorageuron Spent fuel storage racks: degradation absorption in the spent fuel storage racks.neutron-absorbing sheets The LSCS spent fuel storage racks use (BWR) exposed to boral and rio-tinto alcan composite for Treated borated water, neutron absorption.
The reduction in Treated w war neutron absorbing capacity for boral and rio-tinto alcan composite is addressed in Item Number 3.3.1-102.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-55 0 0 Section 3 -Aging Managementeview Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-52 Steel Cranes: rails and Loss of material Chapter XI.M23, No Consistent with NUREG-1801.
The structural girders due to general "Inspection of Overhead Inspection of Overhead Heavy Load and exposed to Air -indoor, corrosion Heavy Load and Light Light Load (Related to Refueling)
Handling uncontrolled (External)
Load (Related to Systems (B.2.1.14) program will be used to Refueling)
Handling manage loss of material of carbon steel Systems" crane/hoist components exposed to air -indoor uncontrolled in the Cranes, Hoists and Refueling Equipment System.3.3.1-53 Steel Cranes -rails Loss of material Chapter XI.M23, No Consistent with NUREG-1801.
The exposed to Air -indoor, due to wear "Inspection of Overhead Inspection of Overhead Heavy Load and uncontrolled (External)
Heavy Load and Light Light Load (Related to Refueling)
Handling Load (Related to Systems (B.2.1.14) program will be used to Refueling)
Handling manage loss of material of carbon steel Systems" crane/hoist components exposed to air -indoor uncontrolled in the Cranes, Hoists and Refueling Equipment System.3.3.1-54 Copper alloy Piping, Loss of material Chapter XI.M24, No Consistent with NUREG-1801.
The piping components, and due to general, "Compressed Air Compressed Air Monitoring (B.2.1.15) piping elements exposed pitting, and crevice Monitoring" program will be used to manage loss of to Condensation corrosion material of the copper alloy piping, piping components, and piping elements exposed to condensation in the Compressed Air System..LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-56 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-55 Steel Piping, piping Loss of material Chapter XI.M24, No Consistent with NUREG-1801 with components, and piping due to general and "Compressed Air exceptions.
The Compressed Air elements:
compressed pitting corrosion Monitoring" Monitoring (B.2.1.15) program will be used air system exposed to to manage loss of material of carbon steel Condensation (Internal) piping, piping components, and piping elements exposed to condensation in the Compressed Air System.An exception applies to the NUREG-1801 recommendations for Compressed Air Monitoring (B.2.1.15) program implementation.
3.3.1-56 Stainless steel Piping, Loss of material Chapter XI.M24, No Consistent with NUREG-1 801 with piping components, and due to pitting and "Compressed Air exceptions.
The Compressed Air piping elements exposed crevice corrosion Monitoring" Monitoring (B.2.1.15) program will be used to Condensation to manage loss of material of stainless steel (Internal) accumulators, piping, piping components, and piping elements exposed to condensation in the Drywell Pneumatic System and Traversing Incore Probe System.An exception applies to the NUREG-1 801 recommendations for Compressed Air Monitoring (B.2.1.15) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-57 0 Section 3 -Aging Managementew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-57 Elastomers Fire barrier Increased hardness; Chapter XI.M26, "Fire No Consistent with NUREG-1801.
The Fire penetration seals shrinkage; loss of Protection" Protection (B.2.1.16) program will be used exposed to Air -indoor, strength to manage change in material properties of uncontrolled, Air -due to weathering elastomers fire barriers (penetration seals outdoor and fire stops) exposed to air -indoor uncontrolled in the Fire Protection System.3.3.1-58 Steel Halon/carbon Loss of material Chapter XI.M26, "Fire No Consistent with NUREG-1801.
The Fire dioxide fire suppression due to general, Protection" Protection (B.2.1.16) program will be used system piping, piping pitting, and crevice to manage loss of material of carbon steel components, and piping corrosion and gray cast iron carbon dioxide fire elements exposed to Air suppression system piping, piping-indoor, uncontrolled components, and piping elements and (External) tanks exposed to air -indoor, uncontrolled in the Fire Protection System.There are no in scope halon fire suppression systems at LSCS.3.3.1-59 Steel Fire rated doors Loss of material Chapter XI.M26, "Fire No Consistent with NUREG-1801.
The Fire exposed to Air -indoor, due to wear Protection" Protection (B.2.1.16) program will be used uncontrolled, Air -to manage loss of material of carbon steel outdoor and galvanized steel fire barriers (doors)exposed to air -indoor uncontrolled and air-outdoor in the Fire Protection System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-58 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-60 Reinforced concrete Concrete cracking Chapter XI.M26, "Fire No Consistent with NUREG-1801.
The Fire Structural fire barriers:
and spalling Protection," and Protection (B.2.1.16) program and walls, ceilings and floors due to aggressive Chapter Xl.S6, Structures Monitoring (B.2.1.34) program exposed to Air -indoor, chemical attack, and "Structures Monitoring" will be used to manage concrete cracking uncontrolled reaction with and spalling and cracking of concrete block, aggregates grout, and reinforced concrete fire barriers (penetration seals and fire stops) and fire barriers (walls and slabs) exposed to air -indoor uncontrolled in the Fire Protection System.3.3.1-61 Reinforced concrete Cracking, loss of Chapter XI.M26, "Fire No Consistent with NUREG-1801.
The Fire Structural fire barriers:
material Protection," and Protection (B.2.1.16) program and walls, ceilings and floors due to freeze-thaw, Chapter XI.S6, Structures Monitoring (B.2.1.34) program exposed to Air -outdoor aggressive chemical "Structures Monitoring" will be used to manage concrete cracking attack, and reaction and spalling of reinforced concrete fire with aggregates barriers (walls and slabs) exposed to air -outdoor in the Fire Protection System.3.3.1-62 Reinforced concrete Loss of material Chapter XI.M26, "Fire No Consistent with NUREG-1801.
The Fire Structural fire barriers:
due to corrosion of Protection," and Protection (B.2.1.16) program and walls, ceilings and floors embedded steel Chapter XL.S6, Structures Monitoring (B.2.1.34) program exposed to Air -indoor, "Structures Monitoring" will be used to manage loss of material of uncontrolled, Air -embedded steel in reinforced concrete fire outdoor barriers (walls and slabs) exposed to air -indoor uncontrolled and air -outdoor in the Fire Protection System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-59 Section 3 -Aging Manageme View Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Number Component+ 1-3.3.1-63 Steel Fire Hydrants exposed to Air -outdoor Loss of material due to general, pitting, and crevice corrosion Chapter XI.M27, "Fire Water System" No Discussion Consistent with NUREG-1 801 with exceptions.
The Fire Water System (B.2.1.17) program will be used to manage loss of material of ductile cast iron fire hydrants exposed to air -outdoor in the Fire Protection System.Exceptions apply to the NUREG-1 801 recommendations for Fire Water System (B.2.1.17) program implementation.
i i i i 3.3.1-64 Steel, Copper alloy Piping, piping components, and piping elements exposed to Raw water Loss of material due to general, pitting, crevice, and microbiologically-influenced corrosion; fouling that leads to corrosion; flow blockage due to fouling Chapter XI.M27, "Fire Water System" No Consistent with NUREG-1 801 with exceptions.
The Fire Water System (B.2.1.17) program will be used to manage loss of material of carbon steel, copper alloy with less than 15% zinc, ductile cast iron, galvanized steel, and gray cast iron piping, piping components, and piping elements and tanks exposed to raw water in the Fire Protection System.Exceptions apply to the NUREG-1 801 recommendations for Fire Water System (B.2.1.17) program implementation.
The Bolting Integrity (B.2. 1.11) program has been substituted and will be used to manage loss of material of carbon and low alloy steel bolting exposed to raw water in the Nonessential Cooling Water System and Fire Protection System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-60 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-65 Aluminum Piping, piping Loss of material Chapter XI.M27, "Fire No The Open-Cycle Cooling Water System components, and piping due to pitting and Water System" (B.2.1.12) program has been substituted elements exposed to crevice corrosion; and will be used to manage loss of material Raw water fouling that leads to in aluminum alloy piping, piping corrosion; flow components, and piping elements exposed blockage due to to raw water in the Nonessential Cooling fouling Water System.3.3.1-66 Stainless steel Piping, Loss of material Chapter Xl.M27, "Fire No Consistent with NUREG-1801 with piping components, and due to pitting and Water System" exceptions.
The Fire Water System piping elements exposed crevice corrosion; (B.2.1.17) program will be used to manage to Raw water fouling that leads to loss of material of stainless steel piping, corrosion; flow piping components, and piping elements blockage due to exposed to raw water in the Fire Protection fouling System.Exceptions apply to the NUREG-1 801 recommendations for Fire Water System (B.2.1.17) program implementation.
3.3.1-67 Steel Tanks exposed to Loss of material Chapter XI.M29, No Not Applicable.
Air -outdoor (External) due to general, "Aboveground Metallic There are no steel tanks exposed to air -pitting, and crevice Tanks" outdoor in Auxil t ems.corrosion Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-61 Section 3 -Aging Management~eview Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-68 Steel Piping, piping Loss of material Chapter XI.M30, "Fuel Oil No Not applicable.
components, and piping due to general, Chemistry", and The loss of material in carbon steel piping, elements exposed to pitting, and crevice Chapter XI.M32, "One- piping components, and piping elements Fuel oil corrosion Time Inspection" exposed to fuel oil is addressed in Item Number 3.3.1-70.3.3.1-69 Copper alloy Piping, Loss of material Chapter XI.M30, "Fuel Oil No Consistent with NUREG-1801.
The Fuel piping components, and due to general, Chemistry," and Oil Chemistry (B.2.1.19) program and One-piping elements exposed pitting, crevice, and Chapter XI.M32, "One- Time Inspection (B.2.1.21) program will be to Fuel oil microbiologically-Time Inspection" used to manage loss of material of copper influenced corrosion alloy with 15% zinc or more and copper alloy with less than 15% zinc piping, piping components, and piping elements exposed to fuel oil in the Diesel Generator and Auxiliaries System.3.3.1-70 Steel Piping, piping Loss of material Chapter XI.M30, "Fuel Oil No Consistent with NUREG-1801.
The Fuel components, and piping due to general, Chemistry," and Oil Chemistry (B.2.1.19) program and One-elements; tanks exposed pitting, crevice, and Chapter XI.M32, "One- Time Inspection (B.2.1.21) program will be to Fuel oil microbiologically-Time Inspection" used to manage loss of material of carbon influenced corrosion; steel and gray cast iron piping, piping fouling that leads to components, and piping elements and corrosion tanks exposed to fuel oil in the Diesel Generator and Auxiliaries System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-62 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-71 Stainless steel, Loss of material Chapter XI.M30, "Fuel Oil No Consistent with NUREG-1801.
The Fuel Aluminum Piping, piping due to pitting, crevice, Chemistry," and Oil Chemistry (B.2.1.19) program and One-components, and piping and microbiologically-Chapter XI.M32, "One- Time Inspection (B.2.1.21) program will be elements exposed to influenced corrosion Time Inspection" used to manage loss of material of Fuel oil stainless steel piping, piping components, and piping elements exposed to fuel oil in the Diesel Generator and Auxiliaries System.3.3.1-72 Gray cast iron, Copper Loss of material Chapter XI.M33, No Consistent with NUREG-1 801. The alloy (>15% Zn or >8% due to selective "Selective Leaching" Selective Leaching (B.2.1.22) program will Al) Piping, piping leaching be used to manage loss of material of components, and piping copper alloy with 15% zinc or more, copper elements, Heat alloy with 15% zinc or more (with internal exchanger components coating), and gray cast iron traveling water exposed to Treated screen framework, heat exchanger water, Closed-cycle components, piping, piping components, cooling water, Soil, Raw and piping elements, and tanks exposed to water, Waste water closed cycle cooling water, raw water, soil, treated water, and waste water in the Closed Cycle Cooling Water System, Demineralized Water Makeup System, Diesel Generator and Auxiliaries System, Drywell Pneumatic System, Essential Cooling Water System, Fire Protection System, Nonessential Cooling Water System, Primary Containment Ventilation System, Process Sampling and Post Accident Monitoring System, Reactor Core Isolation Cooling System, Standby Liquid Control System, and Suppression Pool Cleanup System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-63 0 Section 3- Aging Manageme iew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-73 Concrete; cementitious Changes in material Chapter XI.M36, No Not Applicable.
material Piping, piping properties "External Surfaces There are no concrete; cementitious components, and piping due to aggressive Monitoring of Mechanical material piping, piping components, and elements exposed to Air -chemical attack Components" piping pipin g compouts, in outdoor piping elements exposed to air -outdoor in Auxiliary Systems.3.3.1-74 Concrete; cementitious Cracking Chapter XI.M36, No Not Applicable.
material Piping, piping due to settling "External Surfaces There are no concrete; cementitious components, and piping Monitoring of Mechanical material piping, piping components, and elements exposed to Air -Components"maeilpiniigcooetsad ouentdr epiping elements exposed to air -outdoor in outdoor Auxiliary Systems.3.3.1-75 Reinforced concrete, Cracking Chapter XI.M36, No Not Applicable.
asbestos cement Piping, due to aggressive "External Surfaces piping components, and chemical attack and Monitoring of Mechanical There are no reinforced concrete, asbestos piping elements exposed leaching; Components" cement piping, piping components, and to Air -outdoor Changes in material piping elements exposed to air -outdoor in properties Auxiliary Systems.due to aggressive chemical attack 3.3.1-76 Elastomers Elastomer:
Hardening and loss of Chapter XL.M36, No Consistent with NUREG-1 801. The seals and components strength "External Surfaces External Surfaces Monitoring of Mechanical exposed to Air -indoor, due to elastomer Monitoring of Mechanical Components (B.2.1.24) program will be uncontrolled degradation Components" used to manage hardening and loss of (Internal/External) strength of elastomer seals and components exposed to air -indoor uncontrolled in the Control Room Ventilation System, Diesel Generator and Auxiliaries System, and Safety-Related Ventilation System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-64 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-77 Concrete; cementitious Loss of material Chapter XI.M36, No Not Applicable.
material Piping, piping due to abrasion, "External Surfaces There are no concrete; cementitious components, and piping cavitation, aggressive Monitoring of Mechanical material piping, piping components, and elements exposed to Air -chemical attack, and Components" piping piping compouts, in outdor leahingpiping elements exposed to air -outdoor in outdoor leaching Auxiliary Systems.3.3.1-78 Steel Piping and Loss of material Chapter XL.M36, No Consistent with NUREG-1801.
The components (External due to general "External Surfaces External Surfaces Monitoring of Mechanical surfaces), Ducting and corrosion Monitoring of Mechanical Components (B.2.1.24) program will be components (External Components" used to manage loss of material of carbon surfaces), Ducting; or low alloy steel with stainless steel closure bolting exposed cladding, carbon steel, carbon steel (with to Air -indoor, internal coating), ductile cast iron, uncontrolled (External), galvanized steel, and gray cast iron Air -indoor, uncontrolled accumulators, ducting and components, (External), Air -outdoor heat exchanger components, piping, piping (External), Condensation components, and piping elements, and (External) tanks exposed to air -indoor uncontrolled and air -outdoor in the Closed Cycle Cooling Water System, Combustible Gas Control System, Compressed Air System, Control Rod Drive System, Control Room Ventilation System, Demineralized Water Makeup System, Diesel Generator and Auxiliaries System, Drywell Pneumatic System, Electrical Penetration Pressurization System, Essential Cooling Water System, Fire Protection System, Fuel Pool Cooling and Storage System, Nonessential Cooling Water System, Nonsafety-Related Ventilation System, Plant Drainage System, Primary LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-65 Section 3-Aging Managemen iew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effectl Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended Containment Ventilation System, Process Radiation Monitoring System, Process Sampling and Post Accident Monitoring System, Radwaste System, Reactor Water Cleanup System, Safety-Related Ventilation System, Standby Liquid Control System, and Suppression Pool Cleanup System.The Fire Protection (B.2.1.16) program has been substituted and will be used to manage loss of material of carbon steel and galvanized steel fire barriers (doors)exposed to air -indoor uncontrolled and air-outdoor in the Fire Protection System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-66 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-79 Copper alloy Piping, Loss of material Chapter XL.M36, No Not Applicable.
piping components, and due to general, "External Surfaces The loss of material in copper alloy with piping elements exposed pitting, and crevice Monitoring of Mechanical less than 15% zinc heat exchanger to Condensation corrosion Components" t s exposedat e nsa tion (External) components exposed to condensation (external) is addressed in Item Number 3.3.1-89.
The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the loss of material in copper alloy heat exchanger tubes exposed to condensation (external).
The tubes are located inside the heat exchanger and the external surfaces of the tubes are subject to the internal HVAC environment of condensation during normal operation.
The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components program performs visual inspections of the external surfaces of the tubes during heat exchanger internal inspections.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-67 Section 3 -Aging Manag ntemview Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-80 Steel Heat exchanger Loss of material Chapter XI.M36, No Consistent with NUREG-1801.
The components, Piping, due to general, "External Surfaces External Surfaces Monitoring of Mechanical piping components, and pitting, and crevice Monitoring of Mechanical Components (B.2.1.24) program will be piping elements exposed corrosion Components" used to manage loss of material of carbon to Air -indoor, steel heat exchanger shell side uncontrolled (External), components exposed to air -indoor Air -outdoor (External) uncontrolled in the Demineralized Water Makeup System, Diesel Generator and Auxiliaries System, Control Room Ventilation System and Primary Containment Ventilation System.The Buried and Underground Piping (B.2.1.28) program has been substituted and will be used to manage loss of material of carbon steel piping, piping components, and piping elements located underground, exposed to an air-outdoor environment, in the Essential Cooling Water System and Nonessential Cooling Water System.3.3.1-81 Copper alloy, Aluminum Loss of material Chapter XL.M36, No Not Applicable.
Piping, piping due to pitting and "External Surfaces There are no copper alloy or aluminum components, and piping crevice corrosion Monitoring of Mechanical piping, piping components, and piping elements exposed to Air Components" elements exposed to air -outdoor in-outdoor (External), Air -e lemen te ms .outdoor Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-68 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-82 Elastomers Elastomer:
Loss of material Chapter XI.M36, No Consistent with NUREG-1801.
The seals and components due to wear "External Surfaces External Surfaces Monitoring of Mechanical exposed to Air -indoor, Monitoring of Mechanical Components (B.2.1.24) program will be uncontrolled (External)
Components" used to manage loss of material of elastomer seals and components exposed to air -indoor uncontrolled in the Control Room Ventilation System, Safety-Related Ventilation System, and Standby Gas Treatment System.3.3.1-83 Stainless steel Diesel Cracking Chapter XI.M38, No Consistent with NUREG-1801.
The engine exhaust piping, due to stress "Inspection of Internal Inspection of Internal Surfaces in piping components, and corrosion cracking Surfaces in Miscellaneous Piping and Ducting piping elements exposed Miscellaneous Piping and Components (B.2.1.25) program will be to Diesel exhaust Ducting Components" used to manage cracking of stainless steel diesel engine exhaust piping, piping components, and piping elements exposed to diesel exhaust in the Diesel Generator and Auxiliaries System.3.3.1-84 There is no Item Number 3.3.1-84 listed in NUREG-1800 or subsequent issued ISGs 3.3.1-85 Elastomers Elastomer Hardening and loss of Chapter XI.M38, No Not Applicable.
seals and components strength "Inspection of Internal There are no elastomer seals and exposed to Closed-cycle due to elastomer Surfaces in components exposed to closed cycle cooling water degradation Miscellaneous Piping and cooling water in Auxiliary Systems.Ducting Components" LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-69 Section 3 -Aging Managemen ew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-86 Elastomers, Elastomers Hardening and loss of Chapter XI.M38, No Not applicable.
linings, Elastomer:
seals strength "Inspection of Internal There are no elastomer linings, seals or and components due to elastomer Surfaces in components exposed to treated borated exposed to Treated degradation Miscellaneous Piping and water, treated water, or raw water in borated water, Treated Ducting Components" Auxiliary Systems.water, Raw water 3.3.1-87 There is no Item Number 3.3.1-87 listed in NUREG-1 800 or subsequent issued ISGs 3.3.1-88 Steel; stainless steel Loss of material Chapter XI.M38, No Consistent with NUREG-1 801. The Piping, piping due to general (steel "Inspection of Internal Inspection of Internal Surfaces in components, and piping only), pitting, and Surfaces in Miscellaneous Piping and Ducting elements, Piping, piping crevice corrosion Miscellaneous Piping and Components (B.2.1.25) program will be components, and piping Ducting Components" used to manage loss of material of carbon elements, diesel engine steel and stainless diesel engine exhaust exhaust exposed to Raw piping, piping components, and piping water (potable), Diesel elements exposed to diesel exhaust in the exhaust Diesel Generator and Auxiliaries System and Fire Protection System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-70 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-89 Steel, Copper alloy Loss of material For fire water system No Consistent with NUREG-1801.
The Piping, piping due to general, components:
Chapter Inspection of Internal Surfaces in components, and piping pitting, and crevice XI.M27, "Fire Water Miscellaneous Piping and Ducting elements exposed to corrosion System," or for other Components (B.2.1.25) program will be Moist air or condensation components:
Chapter used to manage loss of material of carbon (Internal)
XI.M38, "Inspection of steel, copper alloy with 15% zinc or more, Internal Surfaces in copper alloy with less than 15% zinc, Miscellaneous Piping and ductile cast iron, and gray cast iron Ducting Components" accumulators, heat exchanger components, piping, piping components, and piping elements, and tanks exposed to condensation in the Control Rod Drive System, Control Room Ventilation System, Diesel Generator and Auxiliaries System, Drywell Pneumatic System, Fire Protection System, Nonsafety-Related Ventilation System, Primary Containment Ventilation System, Safety-Related Ventilation System, Standby Gas Treatment System, and Standby Liquid Control System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-71 Section 3-Aging Managemeiew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-90 Steel Ducting and Loss of material Chapter XL.M38, No Consistent with NUREG-1801.
The components (Internal due to general, "Inspection of Internal Inspection of Internal Surfaces in surfaces) exposed to pitting, crevice, and Surfaces in Miscellaneous Piping and Ducting Condensation (Internal) (for drip pans and Miscellaneous Piping and Components (B.2.1.25) program will be drain lines) Ducting Components" used to manage loss of material of carbon microbiologically-steel and galvanized steel ducting and influenced corrosion components, heat exchanger components, piping, piping components, and piping elements exposed to condensation in the Combustible Gas Control System, Control Room Ventilation System, Drywell Pneumatic System, and Safety-Related Ventilation System.3.3.1-91 Steel Piping, piping Loss of material Chapter XL.M38, No Consistent with NUREG-1801.
The components, and piping due to general, "Inspection of Internal Inspection of Internal Surfaces in elements; tanks exposed pitting, crevice, and Surfaces in Miscellaneous Piping and Ducting to Waste Water microbiologically-Miscellaneous Piping and Components (B.2.1.25) program will be influenced corrosion Ducting Components" used to manage loss of material of carbon steel, ductile cast iron, and galvanized steel heat exchanger components, piping, piping components, and piping elements, and tanks exposed to waste water in the Combustible Gas Control System, Control Rod Drive System, Diesel Generator and Auxiliaries System, Fuel Pool Cooling and Storage System, Plant Drainage System, Reactor Coolant Pressure Boundary System, and Standby Liquid Control System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-72 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-92 Aluminum Piping, piping Loss of material Chapter XI.M38, No Consistent with NUREG-1801.
The components, and piping due to pitting and "Inspection of Internal Inspection of Internal Surfaces in elements exposed to crevice corrosion Surfaces in Miscellaneous Piping and Ducting Condensation (Internal)
Miscellaneous Piping and Components (B.2.1.25) program will be Ducting Components" used to manage loss of material of aluminum alloy ducting and components, piping, piping components, and piping elements, and tanks exposed to condensation in the Condensate System, Control Room Ventilation System, Diesel Generator and Auxiliaries System, Drywell Pneumatic System, Process Radiation Monitoring System, Safety-Related Ventilation System, and Standby Gas Treatment System.3.3.1-93 Copper alloy Piping, Loss of material Chapter XI.M38, No Not Applicable.
piping components, and due to pitting and "Inspection of Internal piping elements exposed crevice corrosion Surfaces in There are no copper alloy piping, piping to Raw water (potable)
Miscellaneous Piping and components, and piping elements exposed Ducting Components" to raw water (potable) in Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-73 Section 3 -Aging Managementeiew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-94 Stainless steel Ducting Loss of material Chapter XI.M38, No Consistent with NUREG-1801.
The and components due to pitting and "Inspection of Internal Inspection of Internal Surfaces in exposed to Condensation crevice corrosion Surfaces in Miscellaneous Piping and Ducting Miscellaneous Piping and Components (B.2.1.25) program will be Ducting Components" used to manage loss of material of carbon or low alloy steel with stainless steel cladding and stainless steel ducting and components, piping, piping components, and piping elements exposed to condensation in the Control Room Ventilation System, Primary Containment Ventilation System, Process Sampling and Post Accident Monitoring System, and Safety-Related Ventilation System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-74 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-95 Copper alloy, Stainless steel, Nickel alloy, Steel Piping, piping components, and piping elements, Heat exchanger components, Piping, piping components, and piping elements; tanks exposed to Waste water, Condensation (Internal)
Loss of material due to pitting, crevice, and microbiologically-influenced corrosion Chapter XI.M38,"Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components" No Consistent with NUREG-1801.
The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program will be used to manage loss of material of carbon steel, copper alloy with 15% zinc or more, copper alloy with less than 15% zinc, nickel alloy, and stainless steel accumulators, ducting and components, piping, piping components, and piping elements, structural steel elements, and tanks exposed to condensation and waste water in the Closed Cycle Cooling Water System, Combustible Gas Control System, Control Rod Drive System, Control Room Ventilation System, Diesel Generator and Auxiliaries System, Drywell Pneumatic System, Fire Protection System, Fuel Pool Cooling and Storage System, Plant Drainage System, Primary Containment Ventilation System, Process Radiation Monitoring System, Process Sampling and Post Accident Monitoring System, Radwaste System, Reactor Core Isolation Cooling System, Safety-Related Ventilation System, Standby Gas Treatment System, Auxiliary Building, Diesel Generator Building, Primary Containment, Radwaste Building, Reactor Building, and Turbine Building.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-75 0 1 0 Section 3 -Aging Managene view Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-96 Elastomers Elastomer:
Loss of material Chapter XI.M38, No Not Applicable.
seals and components due to wear "Inspection of Internal There are no elastomer seals and exposed to Air -indoor, Surfaces in Th e ne e xpo sela to air and uncontrolled (Internal)
Miscellaneous Piping and components exposed to air- indoor, Ducting Components" uncontrolled (internal) in Auxiliary Systems.3.3.1-97 Steel Piping, piping Loss of material Chapter XI.M39, No Consistent with NUREG-1801.
The components, and piping due to general, "Lubricating Oil Analysis," Lubricating Oil Analysis (B.2.1.26) program elements, Reactor pitting, and crevice and and One-Time Inspection (B.2.1.21) coolant pump oil corrosion Chapter XI.M32, "One- program will be used to manage loss of collection system: tanks, Time Inspection" material of carbon steel and gray cast iron Reactor coolant pump oil gearbox, heat exchanger components, collection system: piping, piping, piping components, and piping tubing, valve bodies elements and tanks exposed to lubricating exposed to Lubricating oil oil in the Closed Cycle Cooling Water System, Control Rod Drive System, Control Room Ventilation System, Diesel Generator and Auxiliaries System, and Drywell Pneumatic System.3.3.1-98 Steel Heat exchanger Loss of material Chapter XI.M39, No Consistent with NUREG-1801.
The components exposed to due to general, "Lubricating Oil Analysis," Lubricating Oil Analysis (B.2.1.26) program Lubricating oil pitting, crevice, and and and One-Time Inspection (B.2.1.21) microbiologically-Chapter XI.M32, "One- program will be used to manage loss of influenced corrosion; Time Inspection" material of carbon steel and gray cast iron fouling that leads to heat exchanger components exposed to corrosion lubricating oil in the Essential Cooling Water System and Diesel Generator and Auxiliaries System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-76 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-99 Copper alloy, Aluminum Loss of material Chapter XI.M39, No Consistent with NUREG-1801.
The Piping, piping due to pitting and "Lubricating Oil Analysis," Lubricating Oil Analysis (B.2.1.26) program components, and piping crevice corrosion and and One-Time Inspection (B.2.1.21) elements exposed to Chapter XI.M32, "One- program will be used to manage loss of Lubricating oil Time Inspection" material of aluminum alloy, copper alloy with 15% zinc or more, and copper alloy with less than 15% zinc heat exchanger components, piping, piping components, and piping elements, and tanks exposed to lubricating oil in the Control Room Ventilation System, Diesel Generator and Auxiliaries System, Drywell Pneumatic System, Primary Containment Ventilation System, and Reactor Coolant Pressure Boundary System.3.3.1-100 Stainless steel Piping, Loss of material Chapter XI.M39, No Consistent with NUREG-1801.
The piping components, and due to pitting, crevice, "Lubricating Oil Analysis," Lubricating Oil Analysis (B.2.1.26) program piping elements exposed and microbiologically-and and One-Time Inspection (B.2.1.21) to Lubricating oil influenced corrosion Chapter XI.M32, "One- program will be used to manage loss of Time Inspection" material of stainless steel heat exchanger components, piping, piping components, and piping elements exposed to lubricating oil in the Control Room Ventilation System, Diesel Generator and Auxiliaries System, and Essential Cooling Water System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-77 Section 3 -Aging Managemen iew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effectl Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-101 Aluminum Heat Reduction of heat Chapter XL.M39, No Consistent with NUREG-1801.
The exchanger tubes transfer "Lubricating Oil Analysis," Lubricating Oil Analysis (B.2.1.26) program exposed to Lubricating oil due to fouling and and One-Time Inspection (B.2.1.21)
Chapter XI.M32, "One- program will be used to manage reduction Time Inspection" of heat transfer of aluminum alloy heat exchanger components exposed to lubricating oil in the Diesel Generator and Auxiliaries System.3.3.1-102 Boralo; boron steel, and Reduction of neutron- Chapter XI.M40, No Consistent with NUREG-1801.
The other materials absorbing capacity; "Monitoring of Neutron- Monitoring of Neutron-Absorbing Materials (excluding Boraflex) change in dimensions Absorbing Materials other Other Than Boraflex (B.2.1.27) program will Spent fuel storage racks: and loss of material than Boraflex" be used to manage reduction of neutron neutron-absorbing sheets due to effects of SFP absorbing capacity; change in dimensions (PWR), Spent fuel environment and loss of material of the Boral and Rio-storage racks: neutron- Tinto Alcan composite fuel storage racks absorbing sheets (BWR) exposed to treated water in the Fuel Pool exposed to Treated Cooling and Storage System.borated water, Treated water 3.3.1-103 Reinforced concrete, Cracking Chapter XI.M41, "Buried No Not Applicable.
asbestos cement Piping, due to aggressive and Underground Piping There are no reinforced concrete, asbestos piping components, and chemical attack and and Tanks" cement piping, piping components, and piping elements exposed leaching; piping piping ompons, and to Soil or concrete Changes in material piping elements exposed to soil or concrete properties in Auxiliary Systems.due to aggressive chemical attack LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-78 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-104 HDPE, Fiberglass Piping, Cracking, blistering, Chapter XI.M41, "Buried No Not Applicable.
piping components, and change in color and Underground Piping There are no HOPE, fiberglass piping, piping elements exposed due to water and Tanks" Thein a pents, and piping , to Soil or concrete absorption piping components, and piping elements exposed to soil or concrete in Auxiliary Systems.3.3.1-105 Concrete cylinder piping, Cracking, spalling, Chapter XI.M41, "Buried No Not Applicable.
Asbestos cement pipe corrosion of rebar and Underground Piping There are no concrete cylinder piping, Piping, piping due to exposure of and Tanks" asest o c oncrete piping, piping components, and piping rebar asbestos cement pipe piping, piping elements exposed to Soil components, and piping elements exposed or concrete to soil or concrete in Auxiliary Systems.3.3.1-106 Steel (with coating or Loss of material Chapter XI.M41, "Buried No Consistent with NUREG-1801.
The Buried wrapping)
Piping, piping due to general, and Underground Piping and Underground Piping (B.2.1.28) components, and piping pitting, crevice, and and Tanks" program will be used to manage loss of elements exposed to Soil microbiologically-material of carbon steel, ductile cast iron, or concrete influenced corrosion and gray cast iron piping, piping components, and piping elements exposed to soil in the Diesel Generator and Auxiliaries System, Essential Cooling Water System, Fire Protection System, and Nonessential Cooling Water System.3.3.1-107 Stainless steel, nickel Loss of material Chapter XI.M41, "Buried No Not Applicable.
alloy piping, piping due to pitting and and Underground Piping There are no stainless steel, nickel alloy components, and piping crevice corrosion and Tanks" pipi n o pip ing essm steel, n i ping elements exposed to Soil piping, piping components, and piping or concrete elements exposed to soil or concrete in Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-79 Section 3 -Aging Managementeview Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-108 Titanium, super Loss of material Chapter XI.M41, "Buried No Not Applicable.
austenitic, aluminum, due to pitting and and Underground Piping There are no titanium, super austenitic, copper alloy, stainless crevice corrosion and Tanks" a re cop per a usteel, steel, nickel alloy piping, aluminum, copper alloy, stainless steel, piping components, and nickel alloy piping, piping components, and piping elements, bolting piping elements, bolting exposed to soil or exposed to soil or concrete in Auxiliary Systems.concrete 3.3.1-109 Steel Bolting exposed to Loss of material Chapter XI.M41, "Buried No Consistent with NUREG-1801.
The Buried Soil or concrete due to general, and Underground Piping and Underground Piping (B.2.1.28) pitting and crevice and Tanks" program will be used to manage loss of corrosion material of carbon and low alloy steel bolting exposed to soil in the Fire Protection System.3.3.1-109x Underground aluminum, Loss of material Chapter XI.M41, "Buried No Not Applicable.
copper alloy, stainless due to general (steel and Underground Piping There are no underground aluminum, steel, nickel alloy steel only), pitting and and Tanks" Ther allo unlessro teeluminum, piping, piping crevice corrosion copper alloy, stainless steel, nickel alloy components, and piping steel piping, piping components, and piping elements elements in Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-80 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-110 Stainless steel Piping, Cracking Chapter XI.M7, "BWR No Not Applicable.
piping components, and due to stress Stress Corrosion The BWR Stress Corrosion Cracking piping elements exposed corrosion cracking Cracking," and (BWR Stram Corros cracking to Teatd waer 60&deg;CChater I.M, 'Wter(B.2.1.7) program manages cracking to Treated water >60'C Chapter XI.M2, Water initiation and growth in Reactor Coolant (> 140'F) Chemistry" Pressure Boundary System piping, piping components, and piping elements > 4 inch NPS through the implementation of an augmented Inservice Inspection (ISI)program in accordance with ASME Code, Section XI. Cracking in stainless steel piping, piping components, and piping elements < 4 inch NPS exposed to treated water >140'F in the Auxiliary Systems is addressed in Item Number 3.3.1-19.3.3.1-111 Steel Structural steel Loss of material Chapter XI.S6, No Not Applicable.
exposed to Air -indoor, due to general, "Structures Monitoring" With the exception of the Cranes, Hoists uncontrolled (External) pitting, and crevice and Refel in ou mt Syste m, ho is corrosion and Refueling Equipment System, there is no structural steel exposed to air-indoor uncontrolled in Auxiliary Systems. The loss of material in structural steel exposed to air-indoor uncontrolled in the Cranes, Hoists and Refueling Equipment System is addressed in Item Number 3.3.1-52.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-81 Section 3-Aging Managemerlew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effectl Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-112 Steel Piping, piping None None, provided No, if conditions are Consistent with NUREG-1801.
components, and piping 1) attributes of the met.elements exposed to concrete are consistent Concrete with ACI 318 or ACI 349 (low water-to-cement ratio, low permeability, and adequate air entrainment) as cited in NUREG-1557, and 2) plant OE indicates no degradation of the concrete 3.3.1-113 Aluminum Piping, piping None None NA -No AEM or Consistent with NUREG-1 801.components, and piping AMP elements exposed to Air-dry (Internal/External), Air -indoor, uncontrolled (Internal/External), Air -indoor, controlled (External), Gas 3.3.1-114 Copper alloy Piping, None None NA -No AEM or Consistent with NUREG-1 801.piping components, and AMP piping elements exposed to Air -indoor, uncontrolled (Internal/External), Air -dry, Gas 3.3.1-115 PWR Only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-82 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-116 Galvanized steel Piping, None None NA- No AEM or Consistent with NUREG-1 801.piping components, and AMP piping elements exposed to Air -indoor, uncontrolled 3.3.1-117 Glass Piping elements None None NA -No AEM or Consistent with NUREG-1801.
exposed to Air -indoor, AMP uncontrolled (External), Lubricating oil, Closed-cycle cooling water, Air -outdoor, Fuel oil, Raw water, Treated water, Treated borated water, Air with borated water leakage, Condensation (Internal/External)
Gas 3.3.1-118 Nickel alloy Piping, piping None None NA- No AEM or Consistent with NUREG-1801.
components, and piping AMP elements exposed to Air-indoor, uncontrolled (External)
LaSalle County Station, Units 1 and 2 License Renewal Application 0 Page 3.3-83 Section 3 -Aging Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effectl Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-119 Nickel alloy, PVC, Glass None None NA -No AEM or Consistent with NUREG-1 801.Piping, piping AMP components, and piping elements exposed to Air with borated water leakage, Air -indoor, uncontrolled, Condensation (Internal), Waste Water 3.3.1-120 Stainless steel Piping, None None NA -No AEM or Consistent with NUREG-1 801.piping components, and AMP piping elements exposed to Air -indoor, uncontrolled (Internal/External), Air -indoor, uncontrolled (External), Air with borated water leakage, Concrete, Air- dry, Gas 3.3.1-121 Steel Piping, piping None None NA -No AEM or Consistent with NUREG-1801.
components, and piping AMP elements exposed to Air-indoor, controlled (External), Air -dry, Gas LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-84 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-122 Titanium Heat exchanger None None NA -No AEM or Not Applicable.
components, Piping, AMP pipigcomponents, Ping, AThere are no titanium heat exchanger piping components, and components, piping, piping components, to Air -indoor, and piping elements exposed to air -indoor uncontrolled or Air -uncontrolled or air -outdoor in Auxiliary outdoor Systems.3.3.1-123 Titanium (ASTM Grades None None NA -No AEM or Not Applicable.
1,2, 7, 11, or12 that AMP contains > 5% aluminum There are no titanium (ASTM Grades 1,2, or more than 0.20% 7, 11, or 12 that contains > 5% aluminum or oxygen or any amount of more than 0.20% oxygen or any amount of oxyen) Ht any amountotin) heat exchanger components other than tin) Heat exchanger tubes, piping, piping components, and tubes, Piping, piping piping elements exposed to raw water in components, and piping Auxiliary Systems.elements exposed to Raw water 3.3.1-124 Stainless steel, Steel Cracking due to Chapter XI.M2, 'Water No Not Applicable.(with stainless steel or stress corrosion Chemistry," and Chapter There are no stainless steel or steel (with nickel-alloy cladding), cracking XI.M32, "One-Time stainless steel or nickel-alloy cladding)Spent fuel storage racks Inspection" s t fu el or rack s,-alloy gladding (BWR), Spent fuel spent fuel storage racks, piping, piping storage racks (PWR), components, and piping elements exposed Piping, piping to treated water >60'C (>140&deg;F) or treated components, and piping borated water >60&deg;C (>140&deg;F) in Auxiliary elements; exposed to Systems.Treated water >60'C (>140*F), Treated borated water >60&deg;C (>1 40'F)LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-85 Section 3 -Aging Managemen iew Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-125 Steel (with stainless steel Loss of material due Chapter XI.M2, "Water No Consistent with NUREG-1801 with cladding), stainless steel to pitting and crevice Chemistry," and Chapter exceptions.
The One-Time Inspection Spent fuel storage racks corrosion XI.M32, "One-Time (B.2.1.21) program and Water Chemistry (BWR), Spent fuel Inspection" (B.2.1.2) program will be used to manage storage racks (PWR), loss of material of stainless steel storage Piping, piping racks (control rod blade, defective fuel, and components, and piping spent fuel) exposed to treated water in the elements; exposed to Fuel Pool Cooling and Storage System.Treated water, Treated An exception applies to the NUREG-1801 borated water A xeto ple oteNRG10 recommendations for Water Chemistry (B.2.1.2) program implementation.
3.3.1-126 Any material, piping, Wall thinning due to Chapter XI.M17, "Flow- No Not Applicable.
piping components, and erosion Accelerated Corrosion" There are no piping, piping components, piping elements exposed and piping elements exposed to treated water (borated), raw water, treated water (borated) or raw water water susceptible to wall thinning due to erosion in Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-86 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-127 Metallic piping, piping Loss of material due A plant-specific aging Yes, plant-specific The Open-Cycle Cooling Water System components, and tanks to recurring internal management program is (B.2.1.12) program will be used to manage exposed to raw water or corrosion to be evaluated to the loss of material due to recurring internal waste water address recurring internal corrosion in carbon steel piping, piping corrosion components, and piping elements exposed to raw water in the Essential Cooling Water System and Nonessential Cooling Water System.The Fire Water System (B.2.1.17) program will be used to manage the loss of material due to recurring internal corrosion in carbon steel piping, piping components, and piping elements exposed to raw water in the Fire Protection System.The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program will be used to manage the loss of material due to recurring internal corrosion in carbon steel and galvanized steel piping, piping components, and piping elements exposed to waste water in the Plant Drainage System.See Subsection 3.3.2.2.8.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-87 Section 3 -Aging Managementeview Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-128 Steel, stainless steel, or Loss of material due Chapter XI.M29, No Not Applicable.
aluminum tanks (within to general (steel "Aboveground Metallic There are no steel, stainless steel, or the scope of Chapter only), pitting, or Tanks" al e outdoor tank s steel, o n Xl.M29, "Aboveground crevice corrosion; aluminum outdoor tanks constructed on soil Metallic Tanks") exposed cracking due to stress or concrete, or, indoor large-volume tanks to soil or concrete, or the corrosion cracking (100,000 gallons and greater) designed to following external (stainless steel and internal pressures approximating environments air-outdoor, aluminum only) atmospheric pressure and exposed air-indoor uncontrolled, internally to water (e.g., within the scope of moist air, condensation Chapter XI.M29, "Aboveground Metallic Tanks") exposed to soil or concrete, or the following external environments air-outdoor, air-indoor uncontrolled, moist air or condensation in Auxiliary Systems.3.3.1-129 Steel tanks exposed to Loss of material due Chapter XI.M29, No Not Applicable.
soil or concrete; air- to general, pitting, "Aboveground Metallic There are no steel outdoor tanks indoor uncontrolled, raw and crevice corrosion Tanks" There on soil ortdo or inds water, treated water, constructed on soil or concrete, or, indoor waste water, large-volume tanks (100,000 gallons and condensation greater) designed to internal pressures approximating atmospheric pressure and exposed internally to water (e.g., within the scope of Chapter XI.M29, "Aboveground Metallic Tanks") exposed to soil or concrete, air-indoor uncontrolled, raw water, treated water, waste water or condensation in Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-88 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-130 Metallic sprinklers Loss of material due Chapter XI.M27, "Fire No Consistent with NUREG-1801 with exposed to air-indoor to general (where Water System" exceptions.
The Fire Water System controlled, air-indoor applicable), pitting, (B.2.1.17) program will be used to manage uncontrolled, air-outdoor, crevice, and loss of material and flow blockage of moist air, condensation, microbiologically-metallic sprinklers exposed to air-indoor raw water, treated water influenced corrosion, uncontrolled, air-outdoor, condensation, fouling that leads to and raw water in the Fire Protection corrosion; flow System.blockage due to Exceptions apply to the NUREG-1801 fouling recommendations for Fire Water System (B.2.1.17) program implementation.
3.3.1-131 Steel, stainless steel, Loss of material due Chapter XI.M27, "Fire No Consistent with NUREG-1801 with copper alloy, or to general (steel, and Water System" exceptions.
The Fire Water System aluminum fire water copper alloy only), (B.2.1.17) program will be used to manage system piping, piping pitting, crevice, and loss of material and flow blockage of components and piping microbiologically-carbon steel and stainless steel piping, elements exposed to air- influenced corrosion, piping components and piping elements indoor uncontrolled fouling that leads to exposed to air-indoor uncontrolled and (internal), air-outdoor corrosion; flow condensation in the Fire Protection System.(internal), or blockage due to condensation (internal) fouling Exceptions apply to the NUREG-1 801 recommendations for Fire Water System (B.2.1.17) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-89 Section 3-Aging Managementeview Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-132 Insulated steel, stainless Loss of material Chapter XI.M36, No The External Surfaces Monitoring of steel, copper alloy, due to general "External Surfaces Mechanical Components (B.2.1.24) aluminum, or copper (steel, and copper Monitoring of Mechanical program will be used to manage the loss of alloy alloy only), pitting, Components" or Chapter material of insulated carbon steel piping, (> 15% Zn) piping, piping and crevice XI.M29, "Aboveground piping components, and piping elements components, and tanks corrosion; cracking Metallic Tanks" (for tanks and cracking of insulated stainless steel exposed to condensation, due to stress only) piping, piping components, and piping air-outdoor corrosion cracking elements exposed to condensation in the (aluminum, stainless Closed Cycle Cooling Water System, steel and copper Control Room Ventilation System, Essential alloy (>15% Zn) Cooling Water System, Nonessential only) Cooling Water System, Nonsafety-Related Ventilation System, and Primary Containment Ventilation System.3.3.1-133 Underground HDPE Cracking, blistering, Chapter XI.M41, "Buried No Not Applicable.
piping, piping change in color due and Underground Piping There are no underground HDPE piping, components, and piping to water absorption and Tanks" There a peno and piping , elements in an air-indoor piping components, and piping elements in elements inoan or an air-indoor uncontrolled or condensation uncontrolled or (external) environment in Auxiliary condensation (external)
Systems.environment 3.3.1-134 Steel, stainless steel, or Loss of material due Chapter XI.MI.M38, No Not Applicable.
copper alloy piping, to general (steel and "Inspection of Internal The Open-Cycle Cooling Water System piping components, and copper alloy only), Surfaces in The pen-Cyc ll be ust e piping elements, and pitting, crevice, and Miscellaneous Piping and (B.2.1.12) program will be used to manage heat exchanger microbiologically Ducting Components" the nonsafety-related steel, stainless steel, components exposed to influenced corrosion, and copper alloy piping, piping a raw water environment fouling that leads to components, and piping elements, and heat (for nonsafety-related corrosion exchanger components not covered by components not covered NRC GL 89-13 and exposed to a raw water by NRC GL 89-13) environment.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-90 Section 3 -Aging Management Review Results Table 3.3.1 Summary of Aging Management Evaluations for the Auxiliary Systems Item Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-135 Steel or stainless steel Loss of material due Chapter XI.MI.M36, No Not Applicable.
pump casings to general (steel "External Surfaces There are no steel or stainless steel pump submerged in a waste only), pitting, crevice, Monitoring of Mechanical casings submerged in a waste water water (internal and and microbiologically Components" (ings submerna wist in external) environment influenced corrosion (internal and external) environment in Auxiliary Systems.3.3.1-136 Steel, stainless steel or Loss of material due Chapter XI.M27, "Fire No Not Applicable.
aluminum fire water to general (steel Water System" storage tanks exposed to only), pitting, crevice, There are no steel, stainless steel or air-indoor uncontrolled, and microbiologically-aluminum fire water storage tanks exposed air-outdoor, influenced corrosion, to air-indoor uncontrolled, air-outdoor, condensation, moist air, fouling that leads to condensation, moist air, raw water, or raw water, treated water corrosion; cracking treated water in Auxiliary Systems.due to stress corrosion cracking (stainless steel and aluminum only)3.3.1-137 Steel, stainless steel or Loss of material due Chapter XI.M29, No Not Applicable.
aluminum tanks (within to general (steel only) "Aboveground Metallic There are no steel, stainless steel, or the scope of Chapter pitting and crevice Tanks" a re outdoor tanks steel, o n XI.M29, "Aboveground corrosion aluminum outdoor tanks constructed on soil Metallic Tanks") exposed or concrete, or, indoor large-volume tanks to treated water, treated (100,000 gallons and greater) designed to borated water internal pressures approximating atmospheric pressure and exposed internally to water (e.g., within the scope of Chapter XI.M29, "Aboveground Metallic Tanks") exposed to treated water or treated borated water in Auxiliary Systems.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-91 0 0 Section 3- Aging Management Review Results Table 3.3.2-1 Closed Cycle Cooling Water System Summary of Aging Management Evaluation Table 3.3.2-1 Closed Cycle Cooling Water System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (CRD Feed Pump Uncontrolled (External)
Monitoring of Mechanical Bearing and Gear Components (B.2.1.24)
Oil Coolers) Tube Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-189 3.3.1-46 A Side Components Water (Internal)
Systems (B.2.1.13)
Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-189 3.3.1-46 A Water (Internal)
Systems (B.2.1.13)
Selective Leaching VII.C2.A-50 3.3.1-72 C (B.2.1.22)
Heat Exchanger-Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Clean-up Non- Uncontrolled (External)
Monitoring of Mechanical Regenerative Heat Components (B.2.1.24)
Exchanger)
Shell Closed Cycle Cooling Loss of Material Closed Treated Water VII.E3.AP-189 3.3.1-46 A Side Components Water (Internal)
Systems (B.2.1.13)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-92 Section 3 -Aging Management Review Results Table 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Heat Exchanger-Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Drywell Equipment Uncontrolled (External)
Monitoring of Mechanical Drain Sump Heat Components (B.2.1.24)
Exchanger)
Shell Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-189 3.3.1-46 A Side Components Water (Internal)
Systems (B.2.1.13)
Heat Exchanger-Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 C (Drywell Uncontrolled (External)
Penetration Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 C Cooling Coils) Water (Internal)
Systems (B.2.1.13)
Tube Side Components Heat Exchanger
-Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 C (Nitrogen Uncontrolled (External)
Compressor Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 C Aftercooler)
Shell Water (Internal)
Systems (B.2.1.13)
Side Components Heat Exchanger
-Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 C (Nitrogen Uncontrolled (External)
Compressor Inter- Closed Cycle Cooling Cracking Closed Treated Water VII.E3.AP-192 3.3.1-44 A Cooler) Tube Side Water > 140 F (Internal)
Systems (B.2.1.13)
Components Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 C Systems (B.2.1.13)
LaSalle Count~vftion, Units 1 and 2 License ReneiV P lication 0 Page 3.3-93 0 9 Section 3 -Aging Managemeview Results Table 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (RWCU Pump Uncontrolled (External)
Monitoring of Mechanical Heat Exchanger)
Components (B.2.1.24)
Tube Side Closed Cycle Cooling Loss of Material Closed Treated Water VII.E3.AP-189 3.3.1-46 A Components Water (Internal)
Systems (B.2.1.13)
Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Reactor Building Uncontrolled (External)
Monitoring of Mechanical Closed Cooling Components (B.2.1.24)
Water Heat Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-189 3.3.1-46 A Exchanger)
Shell Water (Internal)
Systems (B.2.1.13)
Side Components Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Reactor Building Uncontrolled (External)
Monitoring of Mechanical Equipment Drain Components (B.2.1.24)
Tank Heat Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-189 3.3.1-46 A Exchanger)
Shell Water (Internal)
Systems (B.2.1.13)
Side Components Heat Exchanger-Leakage Boundary Copper Alloy with Air/Gas -Dry (External)
None None VII.J.AP-9 3.3.1-114 C (Reactor Building less than 15% Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 C Ventilation Zinc Water (Internal)
Systems (B.2.1.13)
Instrument Room A/C Unit) Tube Side Components Hoses Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical I _Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-94 Section 3 -Aging Management Review Results Table 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Hoses Leakage Boundary Carbon Steel Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Piping, piping components, and piping elements Leakage Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78 A Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation Loss of Material External Surfaces VII.C1 .A-405 3.3.1-132 A, 1 (External)
Monitoring of Mechanical Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis (B.2.1.26)
VII.C2.AP-127 3.3.1-97 A+One-Time Inspection (B.2.1.21)
VII.C2.AP-127 3.3.1-97 A Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 A Water (Internal)
Systems (B.2.1.13)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
_ _ Lubricating Oil (Internal)
None None VII.J.AP-15 3.3.1-117 A Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Closed Cycle Cooling Water > 140 F (Internal)
Cracking Closed Treated Water Systems (B.2.1.13)
VII.C2.AP-186 3.3.1-43 A Loss of Material Closed Treated Water Systems (B.2.1.13)
VII.C2.A-52 3.3.1-49 A t 1~ t I Pressure Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78 A.Closed Cycle Cooling Water (Internal)
Loss of Material Closed Treated Water Systems (B.2.1.13)
VII.C2.AP-202 3.3.1-45 A LaSalle Count, ,on, Units 1 and 2 License Rene W lication.Page 3.3-95 0 Section 3 -Aging ManagemReview Results Table 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Carbon Steel Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 1 components, and (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Pump Casing Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Reactor Building Uncontrolled (External)
Monitoring of Mechanical Closed Cooling Components (B.2.1.24)
Water Pump) Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Tanks (Reactor Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Building Closed Uncontrolled (External)
Monitoring of Mechanical Cooling Water Components (B.2.1.24)
Chemical Feeder) Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Tanks (Reactor Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Building Closed Uncontrolled (External)
Monitoring of Mechanical Cooling Water Components (B.2.1.24)
Expansion Tank) Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 1 (External)
Monitoring of Mechanical Components (B.2.1.24)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
III LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-96 Section 3 -Aging Management Review Results Table 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management I Valve Body Leakage Boundary Stainless Steel Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A Water (Internal)
Systems (B.2.1.13)
Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 1 (External)
Monitoring of Mechanical Components (B.2.1.24)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A Water (Internal)
Systems (B.2.1.13)
LaSalle Countwlon, Units 1 and 2 License ReneOpWlication 0 Page 3.3-97 0 0 Section 3 -Aging Managemeview Results Table 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. These components are in an air-indoor, uncontrolled environment, and are insulated.
Because of the potential for air in-leakage through minor gaps in insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dew point of the air on the external surfaces of the insulation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-98 Section 3 -Aging Management Review Results Table 3.3.2-2 Combustible Gas Control System Summary of Aging Management Evaluation Table 3.3.2-2 Combustible Gas Control System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Blower Housing Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.A-08 3.3.1-90 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Stainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Hoses Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting L_ _Components (B.2.1.25)_
LaSalle Countvftio Units 1 and 2 License ReneW plication.Page 3.3-99 9 0 Section 3 -Aging Managemten Review Results Table 3.3.2-2 Combustible Gas Control System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Leakage Boundary Glass Air- Indoor None None VII.J.AP-14 3.3.1-117 A components, and Uncontrolled (External) piping elements Waste Water (Internal)
None None VII.J.AP-277 3.3.1-119 A Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.A-08 3.3.1-90 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Structural Integrity Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.A-08 3.3.1-90 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Recombiners Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 C Surfaces in Miscellaneous Piping and Ducting I Components (B.2.1.25)
I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-100 Section 3 -Aging Management Review Results Table 3.3.2-2 Combustible Gas Control System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78 A Waste Water (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.E5.AP-281 3.3.1-91 A Pressure Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII. I.A-77 3.3.1-78 A Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.A-08 3.3.1-90 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.E5.AP-281 3.3.1-91 Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.E5.AP-278 3.3.1-95 A+ + 4 Structural Integrity Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78 A t I +/- F I Condensation (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.F3.A-08 3.3.1-90 C LaSalle Countrylion, Units 1 and 2 License ReneW plication.Page 3.3-101 0 Section 3 -Aging Management Review Results Table 3.3.2-2 Combustible Gas Control System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: None.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-102 Section 3 -Aging Management Review Results Table 3.3.2-3 Compressed Air System Summary of Aging Management Evaluation Table 3.3.2-3 Compressed Air System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Piping, piping Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Condensation (Internal)
Loss of Material Compressed Air VII.D.A-26 3.3.1-55 B Monitoring (B.2.1.15)
Structural Integrity Carbon Steel Air- Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Compressed Air VII.D.A-26 3.3.1-55 B Monitoring (B.2.1.15)
Valve Body Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Compressed Air VII.D.A-26 3.3.1-55 B Monitoring (B.2.1.15)
Structural Integrity Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Compressed Air VII.D.A-26 3.3.1-55 B Monitoring (B.2.1.15)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc LaSalle Countftion, Units 1 and 2 License ReneW plication* Page 3.3-103 Section 3 -Aging Managemeview Results Table 3.3.2-3 Compressed Air System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Valve Body Structural Integrity Copper Alloy with Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-240 3.3.1-54 B less than 15% Monitoring (B.2.1.15)
Zinc LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-104 Section 3 -Aging Management Review Results Table 3.3.2-3 Compressed Air System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: None.LaSalle Units 1 and 2 Page 3.3-105 License Rene W licationVW Section 3 -Aging Manage ReviewResults Table 3.3.2-4 Control Rod Drive System Summary of Aging Management Evaluation Table 3.3.2-4 Control Rod Drive System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Accumulator Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.A-23 3.3.1-89 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 D Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 C Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-1 10 3.3.1-25 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-1 10 3.3.1-25 D Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VlII.AP-124 3.3.1-15 A Bolting Stainless Steel Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-106 Section 3 -Aging Management Review Results Table 3.3.2-4 Control Rod Drive System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Drip Pan Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Gearbox (CRD Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.E4.AP-127 3.3.1-97 C (B.2.1.26)
One-Time Inspection VII.E4.AP-127 3.3.1-97 C (B.2.1.21)
Heat Exchanger-Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (CRD Feed Pump Uncontrolled (External)
Monitoring of Mechanical Bearing and Gear Components (B.2.1.24)
Oil Cooler) Shell Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.E4.AP-127 3.3.1-97 C Side Components (B.2.1.26)
One-Time Inspection VII.E4.AP-127 3.3.1-97 C (B.2.1.21)
Piping, piping Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.E4.AP-127 3.3.1-97 A (B.2.1.26)
One-Time Inspection VII.E4.AP-127 3.3.1-97 A (B.2.1.21)
LaSalle Countyw n, Units 1 and 2 License Renevlication 9 Page 3.3-107 Section 3- Aging Managemt Review Results Table 3.3.2-4 Control Rod Drive System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Leakage Boundary Carbon Steel Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
VII.E4.AP-106 3.3.1-21+ 4. .4-Water Chemistry (B.2.1.2)VII.E4.AP-106 3.3.1-21 B I 4 + +Waste Water (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Comoonents (B.2.1.25)
VII.E5.AP-281 3.3.1-91 A Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Treated Water (Internal)
None None VII.J.AP-51 3.3.1-117 A Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A ,44.4 Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
VII.E4.AP-1 10 3.3.1-25 A Water Chemistry (B.2.1.2)VII.E4.AP-1 10 3.3.1-25 B Pressure Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Comoonents (B.2.1.24)
VII.I.A-77 3.3.1-78 A Condensation (Internal)
Loss of Material Inspection of Internal VII.G.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Cumulative Fatigue Damaae TLAA V.D2.E-10 3.2.1-1 A, 1-. 4 4 +Loss of Material One-Time Inspection (B.2.1.21)
VII.E4.AP-106 3.3.1-21 A Water Chemistrv (B.2.1.2)VII.E4.AP-106 3.3.1-21 B 4 1 + -. ~4 + 4 Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-117 3.3.1-120 A+, 4 Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
VII.E4.AP-110 3.3.1-25 A Water Chemistry (B.2.1.2)VII.E4.AP-110 3.3.1-25 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-108 Section 3 -Aging Management Review Results Table 3.3.2-4 Control Rod Drive System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing Leakage Boundary Gray Cast Iron Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (CRD Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.E4.AP-127 3.3.1-97 A (B.2.1.26)
One-Time Inspection VII.E4.AP-127 3.3.1-97 A (B.2.1.21)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-1 10 3.3.1-25 B Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-1 10 3.3.1-25 B Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (8.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B LaSalle Count, ylfon, Units 1 and 2 License Rene 1W lication 0 Page 3.3-109 Section 3 -Aging Manage Review Results Table 3.3.2-4 Control Rod Drive System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-110 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-110 3.3.1-25 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-110 Section 3 -Aging Management Review Results Table 3.3.2-4 Control Rod Drive System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The TLAA designation in the Aging Management Review column indicates that fatigue of this component is evaluated in Section 4.3.LaSalle Countlyon, Units 1 and 2 License
.Page 3.3-111 0 0 Section 3 -Aging ManagetReview Results Table 3.3.2-5 Control Room Ventilation System Summary of Aging Management Evaluation Table 3.3.2-5 Control Room Ventilation System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Galvanized Steel Air -Indoor None None VII.J.AP-13 3.3.1-116 C Uncontrolled (External)
Stainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Ducting and Leakage Boundary Stainless Steel Condensation Loss of Material Inspection of Internal VII.F1.AP-99 3.3.1-94 A, 1 Components (External)
Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Aluminum Alloy Air- Indoor None None VII.J.AP-135 3.3.1-113 C Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Carbon Steel Air -Indoor Loss of Material External Surfaces VII.F .A-10 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical I_ 1 1 Components (B.2.1.24)
I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-112 Section 3 -Aging Management Review Results Table 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Ducting and Pressure Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.A-08 3.3.1-90 A Components Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Elastomers Air -Indoor Hardening and Loss of External Surfaces VII.F .AP-102 3.3.1-76 A Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 3 Strength Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Galvanized Steel Air -Indoor None None VII.J.AP-13 3.3.1-116 C Uncontrolled (External)
Condensation Loss of Material External Surfaces VII.F1.A-405 3.3.1-132 A, 4 (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.A-08 3.3.1-90 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 C Uncontrolled (External)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 C Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 C Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F .AP-99 3.3.1-94 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Flexible Pressure Boundary Elastomers Air -Indoor Hardening and Loss of External Surfaces VII.F1.AP-102 3.3.1-76 A Connection Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.F1.AP-113 3.3.1-82 A Monitoring of Mechanical Components (B.2.1.24)
LaSalle CountYpion, Units 1 and 2 License Rene W plication 0 Page 3.3-113 Section 3 -Aging Managent Review Results Table 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Flexible Pressure Boundary Elastomers Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 3 Connection Strength Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Loss of Material Inspection of Internal G, 3 Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Heat Exchanger
-Heat Transfer Aluminum Alloy Condensation Reduction of Heat Inspection of Internal G, 2 (Control Room and (External)
Transfer Surfaces in Miscellaneous Aux Elec Equip Piping and Ducting Room HVAC Air- Components (B.2.1.25)
Cooled Condenser)
Fins Heat Exchanger
-Pressure Boundary Galvanized Steel Air -Indoor None None VII.J.AP-13 3.3.1-116 C (Control Room and Uncontrolled (External)
Aux Elec Equip Condensation (Internal)
Loss of Material Inspection of Internal VII.F1 .A-08 3.3.1-90 C Room HVAC Air- Surfaces in Miscellaneous Cooled Condenser)
Piping and Ducting Shell Side Pipingnd Ducting Components Components (8.2.1.25)
Heat Exchanger
-Heat Transfer Copper Alloy with Air/Gas -Dry (Internal)
None None VII.J.AP-9 3.3.1-114 C (Control Room and less than 15% Condensation Reduction of Heat Inspection of Internal G, 2 Aux Elec Equip Zinc (External)
Transfer Surfaces in Miscellaneous Cooled Condenser)
Piping and Ducting Tubens Components (B.2.1.25)
Tubes LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-114 Section 3 -Aging Management Review Results Table 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Pressure Boundary Copper Alloy with Air/Gas -Dry (Internal)
None None VII.J.AP-9 3.3.1-114 C (Control Room and less than 15% Condensation Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 C Aux Elec Equip Zinc (External)
Surfaces in Miscellaneous Room HVACo Air- Piping and Ducting Cooled Condenser)
Components (B.2.1.25)
Tubes Heat Exchanger
-Heat Transfer Aluminum Alloy Condensation Reduction of Heat Inspection of Internal G, 2 (Control Room and (External)
Transfer Surfaces in Miscellaneous Aux Elec Equip Piping and Ducting Room HVAC Components (B.2.1.25)
Supply Coolers)Fins Heat Exchanger-Pressure Boundary Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 C (Control Room and Uncontrolled (External)
Aux Elec Equip Condensation (Internal)
Loss of Material Inspection of Internal VII.F1 .A-08 3.3.1-90 C Room HVAC Surfaces in Miscellaneous Supply Coolers) Piping and Ducting Shell Side Components (B.2.1.25)
Components Heat Exchanger
-Heat Transfer Copper Alloy with Air/Gas -Dry (Internal)
None None VII.J.AP-9 3.3.1-114 C (Control Room and less than 15% Condensation Reduction of Heat Inspection of Internal G, 2 Aux Elec Equip Zinc (External)
Transfer Surfaces in Miscellaneous Room HVAC Supply Coolers) Piping and Ducting ubers) Components (B.2.1.25)
Tubes LaSalle Countyiion, Units 1 and 2 License Rene !Wp lication.Page 3.3-115 Section 3 -Aging Managemt Review Results Table 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Pressure Boundary Copper Alloy with Air/Gas -Dry (Internal)
None None VII.J.AP-9 3.3.1-114 C (Control Room and less than 15% Condensation Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 C Aux Elec Equip Zinc (External)
Surfaces in Miscellaneous Room HVAC Supply Coolers) Piping and Ducting ubers) Components (B.2.1.25)
Tubes Heat Exchanger
-Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.F1.AP-41 3.3.1-80 A (Control Room and Uncontrolled (External)
Monitoring of Mechanical Aux Equip Room Components (B.2.1.24)
HVAC Refrigerant Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 C Compressor Oil Cooler) Shell Side Components Heat Exchanger
-Heat Transfer Copper Alloy with Air/Gas -Dry (External)
None None VII.J.AP-9 3.3.1-114 C (Control Room and less than 15% Lubricating Oil (Internal)
Reduction of Heat Lubricating Oil Analysis V.D2.EP-78 3.2.1-51 A Aux Equip Room ZincTrnfr(.126 HVAC Refrigerant Transfer (B.2.1.26)
Compressor Oil One-Time Inspection V.D2.EP-78 3.2.1-51 A Cooler) Tubes (B.2.1.21)
Pressure Boundary Copper Alloy with Air/Gas -Dry (External)
None None VII.J.AP-9 3.3.1-114 C less than 15% Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-133 3.3.1-99 C Zinc (B.2.1.26)
One-Time Inspection VII.H2.AP-133 3.3.1-99 C (B.2.1.21)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-116 Section 3 -Aging Management Review Results Table 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Pressure Boundary I Aluminum Alloy Air -Indoor Uncontrolled (External)
None None VII.J.AP-135 3.3.1-113 A Air/Gas -Dry (Internal)
None None VII.J.AP-1 34 3.3.1-113 A Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 A Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.F .AP-127 3.3.1-97 A (B.2.1.26)
One-Time Inspection VII.F1.AP-127 3.3.1-97 A (B.2.1.21)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A 15% Zinc or More Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Copper Alloy with less than 15%Zinc Air -Indoor Uncontrolled (External)
None None VII.J.AP-144 3.3.1-114 A Air/Gas -Dry (Internal)
None None VII.J.AP-9 3.3.1-114 A Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 4 (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
I Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis (B.2.1.26)
VII.H2.AP-133 3.3.1-99 A-I. t +One-Time Inspection (B.2.1.21)
VII.H2.AP-133 3.3.1-99 A LaSalle County ion, Units 1 and 2 License Rene1W lication O Page 3.3-117 0 Section 3 -Aging Managerl eview Results Table 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Glass Air- Indoor None None VII.J.AP-14 3.3.1-117 A components, and Uncontrolled (External) piping elements Air/Gas -Dry (Internal)
None None VII.J.AP-98 3.3.1-117 A Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-138 3.3.1-100 A (B.2.1.26)
One-Time Inspection VII.H2.AP-138 3.3.1-100 A (B.2.1.21)
Tanks (Control Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 C Room and Aux Uncontrolled (External)
Monitoring of Mechanical Elec Equip Room Components (8.2.1.24)
HVAC Refrigerant Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 C Receiver)Valve Body Pressure Boundary Copper Alloy with Air- Indoor None None VII.J.AP-144 3.3.1-114 A 15% Zinc or More Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc Air/Gas -Dry (Internal)
None None VII.J.AP-9 3.3.1-114 A Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 4 (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-118 Section 3 -Aging Management Review Results Table 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Ductile Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
L Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 A LaSalle County&#xfd;! on, Units 1 and 2 License lication.Page 3.3-119 0 0 Section 3-Aging Managem~eReview Results Table 3.3.2-5 Control Room Ventilation System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The stainless steel drip pans are located internal to the ventilation ductwork, and therefore the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the applicable aging effects.2. The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the reduction of heat transfer aging effect applicable to this component type, material, and environment combination.
The component is located within HVAC ducting and components, and the external surfaces of this component are subject to the internal HVAC environment of condensation during normal operation.
The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program performs visual inspections which are capable of identifying aging mechanisms which cause reduction of heat transfer.3. The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the aging effect(s)applicable to this component type, material, and environment combination.
: 4. These components are in an air-indoor, uncontrolled environment, and are insulated.
Because of the potential for air in-leakage through minor gaps in insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dew point of the air on the external surfaces of the insulation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-120 Section 3 -Aging Management Review Results Table 3.3.2-6 Cranes, Hoists and Refueling Equipment System Summary of Aging Management Evaluation Table 3.3.2-6 Cranes, Hoists and Refueling Equipment System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Structural Integrity Carbon and Low Air -Indoor Loss of Material Inspection of Overhead III.B5.TP-248 3.5.1-80 E, 1 Alloy Steel Uncontrolled (External)
Heavy Load and Light Bolting Load (Related to Refueling)
Handling Systems (B.2.1.14)
Loss of Preload Inspection of Overhead III.B5.TP-261 3.5.1-88 E, 1 Heavy Load and Light Load (Related to Refueling)
Handling Systems (B.2.1.14)
Stainless Steel Air -Indoor Loss of Preload Inspection of Overhead III.B5.TP-261 3.5.1-88 E, 1 Bolting Uncontrolled (External)
Heavy Load and Light Load (Related to Refueling)
Handling Systems (B.2.1.14)
Treated Water Loss of Material Inspection of Overhead III.B1.2.TP-232 3.5.1-85 E, 1 (External)
Heavy Load and Light Load (Related to Refueling)
Handling Systems (B.2.1.14)
Water Chemistry (B.2.1.2)
III.B1.2.TP-232 3.5.1-85 B Loss of Preload Inspection of Overhead III.B5.TP-261 3.5.1-88 E, 1 Heavy Load and Light Load (Related to Refueling)
Handling Systems (B.2.1.14)
Crane/Hoist Structural Integrity Carbon Steel Air -Indoor Cumulative Fatigue TLAA VII.B.A-06 3.3.1-1 A, 2 (Bridge/Girders/Tro Uncontrolled (External)
Damage Iley/Beam/Jib Boom)LaSalle Countywon, Units 1 and 2 License Rene 1W lication* Page 3.3-121 0 Section 3 -Aging Management Review Results Table 3.3.2-6 Cranes, Hoists and Refueling Equipment System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Crane/Hoist Structural Integrity Carbon Steel Air -Indoor Loss of Material Inspection of Overhead VII.B.A-07 3.3.1-52 A (Bridge/Girders/Tro Uncontrolled (External)
Heavy Load and Light Iley/Beam/Jib Load (Related to Boom) Refueling)
Handling Systems (B.2.1.14)
Crane/Hoist (Fuel Structural Integrity Aluminum Alloy Air -Indoor None None III.B5.TP-8 3.5.1-95 C Prep Machine) Uncontrolled (External)
Treated Water Loss of Material Inspection of Overhead VII.A4.AP-130 3.3.1-25 E, 1 (External)
Heavy Load and Light Load (Related to Refueling)
Handling Systems (B.2.1.14)
Water Chemistry (B.2.1.2)
VII.A4.AP-130 3.3.1-25 D Crane/Hoist (Rail Structural Integrity Carbon Steel Air -Indoor Loss of Material Inspection of Overhead VII.B.A-07 3.3.1-52 A Systems) Uncontrolled (External)
Heavy Load and Light VII.B.A-05 3.3.1-53 A Load (Related to Refueling)
Handling Systems (B.2.1.14)
Crane/Hoist Structural Integrity Carbon Steel Air -Indoor Loss of Material Inspection of Overhead VII.B.A-07 3.3.1-52 A (Refueling Uncontrolled (External)
Heavy Load and Light Platform)
Load (Related to Refueling)
Handling Systems (B.2.1.14)
Crane/Hoist Structural Integrity Carbon Steel Air -Indoor Loss of Material Inspection of Overhead VII.B.A-07 3.3.1-52 A (Scorpion Work Uncontrolled (External)
Heavy Load and Light Platform)
Load (Related to Refueling)
Handling Systems (B.2.1.14)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 C Uncontrolled (External)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-122 Section 3 -Aging Management Review Results Table 3.3.2-6 Cranes, Hoists and Refueling Equipment System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The Inspection of Overhead Heavy Load and Light Load (Related to Fuel Handling)
Systems (B.2.1.14) program is substituted to manage the aging effect(s) applicable to this component type, material and environment combination.
: 2. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.7.LaSalle County.Jon, Units 1 and 2 Page 3.3-123 License ReneW lication V P 0 Section 3 -Aging Managment Review Results Table 3.3.2-7 Demineralized Water Makeup System Summary of Aging Management Evaluation Table 3.3.2-7 Demineralized Water Makeup System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Heat Exchanger-Leakage Boundary Glass Air- Indoor None None VII.J.AP-14 3.3.1-117 C (Electric Hot Uncontrolled (External)
Water) Shell Side Treated Water (Internal)
None None VII.J.AP-51 3.3.1-117 C Components Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.F1.AP-41 3.3.1-80 A (Steam Generator)
Uncontrolled (External)
Monitoring of Mechanical Shell Side Components (B.2.1.24)
Components Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-77 3.4.1-15 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-77 3.4.1-15 B Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-77 3.4.1-15 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-77 3.4.1-15 D Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-140 3.3.1-22 A L_ (B.2.1.21)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-124 Section 3 -Aging Management Review Results Table 3.3.2-7 Demineralized Water Makeup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Leakage Boundary CopperAlloy with Treated Water (Internal)
Loss of Material Water Chemistry (B.2.1.2)
VII.E4.AP-140 3.3.1-22 B components, and less than 15%piping elements Zinc Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 A Uncontrolled (External)
Treated Water (Internal)
Loss of Coating Integrity Service Level III and H, 2 Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)I VII.E4.AP-106 3.3.1-21 A Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Treated Water (Internal)
None None VII.J.AP-51 3.3.1-117 A Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-87 3.4.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-87 3.4.1-16 A Pump Casing Leakage Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A (Evaporative Uncontrolled (External)
Monitoring of Mechanical Cooler) Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 A Selective Leaching VII.A4.AP-31 3.3.1-72 A (B.2.1.22)
Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical
__ _Components (B.2.1.24)
LaSalle Count yftjon, Units 1 and 2 License ReneW lication.Page 3.3-125 0 O Section 3-Aging Manage4 Review Results Table 3.3.2-7 Demineralized Water Makeup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Carbon Steel Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A 15% Zinc or More Uncontrolled (External)
Treated Water (Internal)
Cracking One-Time Inspection H, 1 (B.2.1.21)
Water Chemistry (B.2.1.2)
H, 1 Loss of Material One-Time Inspection VII.E4.AP-140 3.3.1-22 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-140 3.3.1-22 B Selective Leaching VII.E4.AP-32 3.3.1-72 A (B.2.1.22)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-140 3.3.1-22 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-140 3.3.1-22 B Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 A Selective Leaching VII.A4.AP-31 3.3.1-72 A (B.2.1.22)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-126 Section 3 -Aging Management Review Results Table 3.3.2-7 Demineralized Water Makeup System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1 801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. Vent valves in supply pipe to the clean gland water tank are brass, ASTM B584, alloy material which has a zinc content of 15 percent. The One-Time Inspection (B.2.1.21) program and Water Chemistry (B.2.1.2) program are used to manage cracking in treated water for this component, material, and environment combination.
: 2. The aging effects for galvanized steel in a treated water environment include loss of coating integrity.
The Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable to galvanized steel in a treated water environment.
LaSalle Count ytlion, Units 1 and 2 _ Page 3.3-127 License ReneW lication 0 Section 3 -Aging Manage*eeview Results Table 3.3.2-8 Diesel Generator and Auxiliaries System Summary of Aging Management Evaluation Table 3.3.2-8 Diesel Generator and Auxiliaries System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Air Dryer (Housing)
Structural Integrity Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1 .24)Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Bird Screen Filter Stainless Steel Air -Outdoor (External)
Cracking External Surfaces VII.H2.AP-209 3.3.1-4 A Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.H2.AP-221 3.3.1-6 A Monitoring of Mechanical Components (B.2.1.24)
Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Stainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Electric Heaters Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Housing)
Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-189 3.3.1-46 A Water (Internal)
Systems (B.2.1.13)
Expansion Joints Pressure Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A I__ I_ _ &#xfd;Uncontrolled (External)
I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-128 Section 3 -Aging Management Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item[ t Management Expansion Joints Pressure Boundary Stainless Steel Diesel Exhaust Cracking Inspection of Internal VII.H2.AP-128 3.3.1-83 A (Internal)
Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Loss of Material Inspection of Internal VII.H2.AP-104 3.3.1-88 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Flame Arrestor Pressure Boundary Ductile Cast Iron Air -Outdoor (External)
Loss of Material External Surfaces VII.I.A-78 3.3.1-78 A Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Flow Device Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry VII.H1.AP-105 3.3.1-70 A (B.2.1.19)
One-Time Inspection VII.HI.AP-105 3.3.1-70 A (B.2.1.21)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-138 3.3.1-100 A (B.2.1.26)
One-Time Inspection VII.H2.AP-138 3.3.1-100 A (B.2.1.21)
Throttle Carbon Steel Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry VII.H1.AP-105 3.3.1-70 A (B.2.1.19)
One-Time Inspection VII.HI.AP-105 3.3.1-70 A (B.2.1.21)
Stainless Steel Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-138 3.3.1-100 A L__ (B.2.1.26)
LaSalle Countyaltjon, Units 1 and 2 License Rene1W lication.Page 3.3-129 0 Section 3- Aging Managem eview Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Flow Device Throttle Stainless Steel Lubricating Oil (Internal)
Loss of Material One-Time Inspection VII.H2.AP-138 3.3.1-100 A (B.2.1.21)
Heat Exchanger-Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.H2.AP-41 3.3.1-80 A (DIG Cooler) Shell Uncontrolled (External)
Monitoring of Mechanical Side Components Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-189 3.3.1-46 A Water (Internal)
Systems (B.2.1.13)
Heat Exchanger
-Pressure Boundary Copper Alloy with Closed Cycle Cooling Cracking Closed Treated Water H, 3 (D/G Cooler) Tube 15% Zinc or More Water (External)
Systems (B.2.1.13)
Sheet Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 C Systems (B.2.1.13)
Selective Leaching VII.C2.AP-43 3.3.1-72 C (B.2.1.22)
Heat Exchanger
-Heat Transfer Copper Alloy with Closed Cycle Cooling Reduction of Heat Closed Treated Water VII.C2.AP-205 3.3.1-50 A (D/G Cooler) 15% Zinc or More Water (External)
Transfer Systems (B.2.1.13)
Tubes Pressure Boundary Copper Alloy with Closed Cycle Cooling Cracking Closed Treated Water H, 3 15% Zinc or More Water (External)
Systems (B.2.1.13)
Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 C Systems (B.2.1.13)
Selective Leaching VII.C2.AP-43 3.3.1-72 C (B.2.1.22)
Heat Exchanger-Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.H2.AP-41 3.3.1-80 A (Lube Oil Cooler) Uncontrolled (External)
Monitoring of Mechanical Shell Side Components (B.2.1.24)
Components Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-131 3.3.1-98 A (B.2.1.26)
One-Time Inspection VII.H2.AP-131 3.3.1-98 A (B.2.1.21)
Heat Exchanger-Pressure Boundary Copper Alloy with Closed Cycle Cooling Cracking Closed Treated Water H, 3 (Lube Oil Cooler) 15% Zinc or More Water (External)
Systems (B.2.1.13)
Tube Sheet LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-130 Section 3 -7 Aging Management Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Pressure Boundary Copper Alloy with Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 C (Lube Oil Cooler) 15% Zinc or More Water (External)
Systems (B.2.1.13)
Tube Sheet Selective Leaching VII.C2.AP-43 3.3.1-72 C (B.2.1.22)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-133 3.3.1-99 C (B.2.1.26)
One-Time Inspection VII.H2.AP-133 3.3.1-99 C (B.2.1.21)
Heat Exchanger-Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.H2.AP-41 3.3.1-80 A (Lube Oil Cooler) Uncontrolled (External)
Monitoring of Mechanical Tube Side Components (B.2.1.24)
Components Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-189 3.3.1-46 A Water (Internal)
Systems (B.2.1.13)
Heat Exchanger
-Heat Transfer Aluminum Alloy Lubricating Oil Reduction of Heat Lubricating Oil Analysis VII.H2.AP-154 3.3.1-101 A (Lube Oil Cooler) (External)
Transfer (B.2.1.26)
Tubes One-Time Inspection VII.H2.AP-154 3.3.1-101 A (B.2.1.21)
Copper Alloy with Closed Cycle Cooling Reduction of Heat Closed Treated Water VII.C2.AP-205 3.3.1-50 A 15% Zinc or More Water (Internal)
Transfer Systems (B.2.1.13)
Lubricating Oil Reduction of Heat Lubricating Oil Analysis V.D2.EP-78 3.2.1-51 A (External)
Transfer (B.2.1.26)
One-Time Inspection V.D2.EP-78 3.2.1-51 A (B.2.1.21)
Pressure Boundary Copper Alloy with Closed Cycle Cooling Cracking Closed Treated Water H, 3 15% Zinc or More Water (Internal)
Systems (B.2.1.13)
Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 C Systems (B.2.1.13)
Selective Leaching VII.C2.AP-43 3.3.1-72 C (B.2.1.22)
LaSalle County )on, Units 1 and 2 License Rene~W lication 0 Page 3.3-131 0 Section 3 -Aging ManagemeReview Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Pressure Boundary Copper Alloy with Lubricating Oil Loss of Material Lubricating Oil Analysis VII.H2.AP-133 3.3.1-99 C (Lube Oil Cooler) 15% Zinc or More (External) (B.2.1.26)
Tubes One-Time Inspection VII.H2.AP-133 3.3.1-99 C (B.2.1.21)
Hoses Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Elastomers Air- Indoor Hardening and Loss of External Surfaces VII.F1.AP-102 3.3.1-76 A Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 2 Strength Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry VII.H1.AP-136 3.3.1-71 A (B.2.1.19)
One-Time Inspection VII.H1.AP-136 3.3.1-71 A (B.2.1.21)
Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
I I __LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-132 Section 3 -Aging Management Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Leakage Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.H2.A-23 3.3.1-89 A Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry (B.2.1.19)
VII.H .AP-105 3.3.1-70 A One-Time Inspection (B.2.1.21)
VII.H1 .AP-105 3.3.1-70 A~1- 1 1- 1 Glass Air -Indoor Uncontrolled (External)
None None VII.J.AP-14 3.3.1-117 A I + I Fuel Oil (Internal)
None None VII.J.AP-49 3.3.1-117 A Pressure Boundary Aluminum Alloy Air- Indoor Uncontrolled (External)
None None VII.J.AP-135 3.3.1-113 A I I +/- F I Condensation (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Com[)onents (B.2.1.25)
VII.F .AP-142 3.3.1-92 A 1- t I +/- I Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.L.A-77 3.3.1-78 A Air -Outdoor (External)
Loss of Material External Surfaces VII.I.A-78 3.3.1-78 A Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Diesel Exhaust (Internal)
Cumulative Fatigue Damage TLAA H, 1 LaSalle Count'"on, Units 1 and 2 License Rene W lication.Page 3.3-133 Section 3- Aging Managel Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Pressure Boundary Carbon Steel Diesel Exhaust (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.H2.AP-104 3.3.1-88 A Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry VII.H1.AP-105 3.3.1-70 A (B.2.1.19)
One-Time Inspection VII.H1.AP-105 3.3.1-70 A (B.2.1.21)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-127 3.3.1-97 A (B.2.1.26)
One-Time Inspection VII.H2.AP-127 3.3.1-97 A (B.2.1.21)
Soil (External)
Loss of Material Buried and Underground VII.H1.AP-198 3.3.1-106 A I Piping (B.2.1.28)
Waste Water (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.E5.AP-281 3.3.1-91 A Copper Alloy with Air -Indoor 15% Zinc or More Uncontrolled (External)
None None VII.J.AP-144 3.3.1-114 A Closed Cycle Cooling Cracking Closed Treated Water H, 3 Water (Internal)
Systems (B.2.1.13)
Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 A Systems (B.2.1.13)
Selective Leaching VII.C2.AP-43 3.3.1-72 A (B.2.1.22)
I I Condensation (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.G.AP-143 3.3.1-89 A Copper Alloy with less than 15%Zinc Air -Indoor Uncontrolled (External)
None None VII.J.AP-144 3.3.1-114 A LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-134 Section 3 -Aging Management Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item_ _ _ _ _ _ _ _ _ _ _ _ _ _ Management___
__ __Piping, piping components, and piping elements Pressure Boundary Copper Alloy with less than 15%Zinc Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry (B.2.1.19)
VII.Hl .AP-132 3.3.1-69 A+ +One-Time Inspection (B.2.1 .21'i VII.H1.AP-132 3.3.1-69 A Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Closed Cycle Cooling None None VII.J.AP-166 3.3.1-117 A Water (Internal)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 A Lubricating Oil (Internal)
None None VII.J.AP-15 3.3.1-117 A Gray Cast Iron Air- Indoor Loss of Material External Surfaces VII.L.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-127 3.3.1-97 A (B.2.1.26)
One-Time Inspection VII.H2.AP-127 3.3.1-97 A (B.2.1.21)
Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry (B.2.1.19)
VII.HI .AP-136 3.3.1-71 A One-Time Inspection (B.2.1.21)
VII.H1 .AP-136 3.3.1-71 A LaSalle Countlon, Units I and 2 License Rene W lication* Page 3.3-135 Section 3 -Aging Management Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Stainless Steel Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-138 3.3.1-100 A components, and (B.2.1.26) piping elements One-Time Inspection VII.H2.AP-138 3.3.1-100 A (B.2.1.21)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Structural Integrity Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing (Fuel Pressure Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Oil Transfer)
Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry VII.H1.AP-105 3.3.1-70 A (B.2.1.19)
One-Time Inspection VII.HI.AP-105 3.3.1-70 A (B.2.1.21)
Pump Casing Pressure Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Lube Oil) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-127 3.3.1-97 A (B.2.1.26)
One-Time Inspection VII.H2.AP-127 3.3.1-97 A (B.2.1.21)
Silencer/Muffler Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical I I_ Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-136 Section 3 -Aging Management Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1 801 Table I Item Notes Type Function Requiring Programs Item Management Silencer/Muffler Pressure Boundary Carbon Steel Diesel Exhaust Loss of Material Inspection of Internal VII.H2.AP-104 3.3.1-88 A (Internal)
Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Strainer Element Filter Stainless Steel Condensation Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A (External)
Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Fuel Oil (External)
Loss of Material Fuel Oil Chemistry VII.H1.AP-136 3.3.1-71 A (B.2.1.19)
One-Time Inspection VII.H1.AP-136 3.3.1-71 A (B.2.1.21)
Lubricating Oil Loss of Material Lubricating Oil Analysis VII.H2.AP-138 3.3.1-100 A (External) (B.2.1.26)
One-Time Inspection VII.H2.AP-138 3.3.1-100 A (B.2.1.21)
Tanks (Air Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Receivers)
Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Tanks (Closed Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Cooling Water Uncontrolled (External)
Monitoring of Mechanical Expansion Tanks) Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Tanks (Fuel Oil Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Storage and Day Uncontrolled (External)
Monitoring of Mechanical Tanks) I I I I Components (B.2.1.24)
I LaSalle Count~iftion, Units 1 and 2 License Rene /plication 0 Page 3.3-137 0 Section 3 -Aging Managem t Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Tanks (Fuel Oil Pressure Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 A Storage and Day Surfaces in Miscellaneous Tanks) Piping and Ducting Components (B.2.1.25)
Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry VII.H1.AP-105 3.3.1-70 A (B.2.1.19)
One-Time Inspection VII.Hi.AP-105 3.3.1-70 A (B.2.1.21)
Tanks (Lube Oil Pressure Boundary Aluminum Alloy Air -Indoor None None VII.J.AP-135 3.3.1-113 A Strainer Tank) Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F .AP-142 3.3.1-92 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-162 3.3.1-99 C (B.2.1.26)
One-Time Inspection VII.H2.AP-162 3.3.1-99 C (B.2.1.21)
Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-127 3.3.1-97 C (B.2.1.26)
One-Time Inspection VII.H2.AP-127 3.3.1-97 C (B.2.1.21)
Valve Body Leakage Boundary Copper Alloy with Air- Indoor None None VII.J.AP-144 3.3.1-114 A 15% Zinc or More Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical I __ Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-138 Section 3 -Aging Management Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Carbon Steel Closed Cycle Cooling Water (internal)
Loss of Material Closed Treated Water Svstems (B.2.1.13'l VII.C2.AP-202 3.3.1-45 A Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry (B.2.1.19)
VII.H1 .AP-105 3.3.1-70 A One-Time Inspection (B.2.1.21)
VII.H .AP-105 3.3.1-70 A 1 1 -~ t +Copper Alloy with Air -Indoor 15% Zinc or More Uncontrolled (External)
None None VII.J.AP-144 3.3.1-114 A Closed Cycle Cooling Cracking Closed Treated Water H, 3 Water (Internal)
Systems (B.2.1.13)
Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 A Systems (B.2.1.13)
Selective Leaching VII.C2.AP-43 3.3.1-72 A (B.2.1.22)
Fuel Oil (Internal)
Loss of Material Fuel Oil Chemistry VII.H1.AP-132 3.3.1-69 A (B.2.1.19)
One-Time Inspection VII.H1.AP-132 3.3.1-69 A (B.2.1.21)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis (B.2.1.26)
VII.H2.AP-133 3.3.1-99 A"1 q-+ F +One-Time Inspection (B.2.1.21)
VII.H2.AP-133 3.3.1-99 A+/- + 4 + _____Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-1 7 3.3.1-120 A Closed Cycle Cooling Water (Internal)
Loss of Material Closed Treated Water Systems (B.2.1.13)
VII.C2.A-52 3.3.1-49 A LaSalle CountYm"ion, Units 1 and 2 License Renew plication O Page 3.3-139 0 0 Section 3- Aging Managem Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Stainless Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-138 3.3.1-100 A (B.2.1.26)
One-Time Inspection VII.H2.AP-138 3.3.1-100 A (B.2.1.21)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-140 Section 3 -Aging Management Review Results Table 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. This component is associated with carbon steel EDG engine exhaust piping in a diesel exhaust environment.
TLAA is used to manage the aging effect(s) applicable to this component type, material and environment combination.
The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.2. The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the aging effect(s)applicable to this component type, material, and environment combination.
: 3. The aging effects for copper alloy with 15% zinc or more in a closed cycle cooling water environment include cracking.
The Closed Treated Water Systems (B.2.1.13) program is used to manage cracking for this component, material, and environment combination.
LaSalle County" on, Units 1 and 2 Page 3.3-141 License Rene VP lication w 0 Section 3 -Aging Managem Review Results Table 3.3.2-9 Drywell Pneumatic System Summary of Aging Management Evaluation Table 3.3.2-9 Drywell Pneumatic System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Accumulator Pressure Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 C Uncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 C Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 D, 1 Monitoring (B.2.1.15)
Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Stainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Compressor Leakage Boundary Ductile Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Housing Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Selective Leaching VII.C2.A-50 3.3.1-72 A (B.2.1.22)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VIIFi .AP-127 3.3.1-97 A I___ (B.2.1.26)
I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-142 Section 3 -Aging Management Review Results Table 3.3.2-9 Drywell Pneumatic System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Compressor Leakage Boundary Gray Cast Iron Lubricating Oil (Internal)
Loss of Material One-Time Inspection VII.Fl.AP-127 3.3.1-97 A Housing (B.2.1.21)
Hoses Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A, 2 Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 A Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 B, 1 Monitoring (B.2.1.15)
Piping, piping Leakage Boundary Aluminum Alloy Air -Indoor None None VII.J.AP-135 3.3.1-113 A components, and Uncontrolled (External) piping elements Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 A, 2 Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.A-08 3.3.1-90 C, 2 Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.F .AP-127 3.3.1-97 A (B.2.1.26)
One-Time Inspection VII.F1.AP-127 3.3.1-97 A (B.2.1.21)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A 15% Zinc or More Uncontrolled (External)
LaSalle County ion, Units 1 and 2 License ReneW lication.Page 3.3-143 Section 3 -Aging Manage 9 Review Results Table 3.3.2-9 Drywell Pneumatic System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Leakage Boundary Copper Alloy with 15% Zinc or More Condensation (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.G.AP-143 3.3.1-89 A, 2 Waste Water (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.E5.AP-272 3.3.1-95 A, 5 Selective Leaching (B.2.1.22)
VII. E5.A-407 3.3.1-72 A, 5 Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-133 3.3.1-99 A (B.2.1.26)
One-Time Inspection VII.H2.AP-133 3.3.1-99 A (B.2.1.21)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Lubricating Oil (Internal)
None None VII.J.AP-15 3.3.1-117 A Nickel Alloy Air -Indoor None None VII.J.AP-16 3.3.1-118 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-274 3.3.1-95 A, 2 Surfaces in Miscellaneous Piping and Ducting I Components (B.2.1.25)
Polymers Air -Indoor Uncontrolled (External)
Change in Material Properties External Surfaces Monitoring of Mechanical Components (B.2.1.24)
G, 3 t. .+Condensation (Internal)
Change in Material Properties, Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
G, 4 LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-144 Section 3 -Aging Management Review Results Table 3.3.2-9 Drywell Pneumatic System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A components, and Uncontrolled (External) piping elements Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 B, 1 Monitoring (B.2.1.15)
Inspection of Internal VII.E5.AP-273 3.3.1-95 A, 2 Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 A Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 B, 1 Monitoring (B.2.1.15)
Inspection of Internal VII.E5.AP-273 3.3.1-95 A, 2 Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Structural Integrity Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 B, 1 Monitoring (B.2.1.15)
Inspection of Internal VII.E5.AP-273 3.3.1-95 A, 2 Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Strainer Element Filter Stainless Steel Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 A Valve Body Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.IA-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F1 .A-08 3.3.1-90 C, 2 Surfaces in Miscellaneous Piping and Ducting I Components (B.2.1.25)
I LaSalle Countyftion, Units 1 and 2 License Rene1W lication.Page 3.3-145 e Section 3 -Aging Manage9enReview Results Table 3.3.2-9 Drywell Pneumatic System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Copper Alloy with less than 15%Zinc Air -Indoor Uncontrolled (External)
None None VII.J.AP-144 3.3.1-114 Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis (B.2.1.26)
VII.H2.AP-133 3.3.1-99 A One-Time Inspection (B.2.1.21)
VII.H2.AP-133 3.3.1-99 A+ 4 4 + + 4 Stainless Steel Air -Indoor Uncontrolled (External)
Condensation (Internal)
None None VII.J.AP-17 3.3.1-120 A , -4 Loss of Material Compressed Air Monitoring (B.2.1.15)
VII.D.AP-81 3.3.1-56 B, 1 Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.E5.AP-273 3.3.1-95 A, 2 Pressure Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78 A Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 A t + 4 + 4 Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 A Condensation (Internal)
Loss of Material Compressed Air Monitorina (B.2.1.15)
VII.D.AP-81 3.3.1-56 B, 1 4 4 4 Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Comoonents (B.2.1.25)
VII.E5.AP-273 3.3.1-95 A, 2 I 4 4 '4 4 +Structural Integrity Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A--'I. I. 4 4 Condensation (Internal)
Loss of Material Compressed Air Monitoring (B.2.1.15)
VII.D.AP-81 3.3.1-56 B, 1 LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-146 Section 3 -Aging Management Review Results Table 3.3.2-9 Drywell Pneumatic System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. SSCs downstream of N2 compressors/dryers have an internal environment of condensation which will be managed by the Compressed Air Monitoring (B.2.1.15) program.2. SSCs upstream of the compressors/dryers, and, portions of drain traps and their associated piping components and piping elements have an internal environment of condensation which will be managed by the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program.3. Material is translucent epoxy fiberglass.
The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program will be used to manage the aging effect applicable to this component type, material, and environment combination.
: 4. Material is translucent epoxy fiberglass.
The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program will be used to manage the aging effect applicable to this component type, material, and environment combination.
: 5. Water accumulated in drain traps is considered waste water for the purposes of assigning aging effects and aging management programs.LaSalle County~ on, Units 1 and 2 O Page 3.3-147 License W lication 0 Section 3 -Aging Managemt Review Results Table 3.3.2-10 Electrical Penetration Pressurization System Summary of Aging Management Evaluation Table 3.3.2-10 Electrical Penetration Pressurization System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 A Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 A Valve Body Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 A Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 A LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-148 Section 3 -Aging Management Review Results Table 3.3.2-10 Electrical Penetration Pressurization System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: None.LaSalle Countyu ion, Units 1 and 2 Page 3.3-149 License Rene WP licationww 0 Section 3 -Aging Management Review Results Table 3.3.2-11 Essential Cooling Water System Summary of Aging Management Evaluation Table 3.3.2-11 Essential Cooling Water System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item I q Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Stainless Steel Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Air -Outdoor (External)
Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-126 3.3.1-12 A Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-263 3.3.1-15 A Fish Barrier Filter Stainless Steel Air -Outdoor (External)
Loss of Material Open-Cycle Cooling Water III.B2.TP-6 3.5.1-93 E, 2 System (B.2.1.12)
Raw Water (External)
Loss of Material Open-Cycle Cooling Water VII.C .A-54 3.3.1-40 A System (B.2.1.12)
Flow Device Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Throttle Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.Cl.AP-183 3.3.1-38 C System (B.2.1.12)
Heat Exchanger
-Heat Transfer Copper Alloy with Raw Water (Internal)
Reduction of Heat Open-Cycle Cooling Water VII.Cl.A-72 3.3.1-42 A (CSCS Equipment less than 15% Transfer System (B.2.1.12)
Area Cubicle Zinc Coolers Tubes LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-150 Section 3 -Aging Management Review Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item q I Management Heat Exchanger
-Pressure Boundary Copper Alloy with Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-179 3.3.1-38 A (CSCS Equipment less than 15% System (B.2.1.12)
Area Cubicle Zinc Coolers) Tubes Heat Exchanger
-Pressure Boundary Copper Alloy with Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 3 (DIG Cooler) Tube 15% Zinc or More Service Level III Sheet (with internal Augmented Coatings coating) Monitoring and Maintenance Program (B.2.2.1)Loss of Material Open-Cycle Cooling Water VII.C1.AP-179 3.3.1-38 A System (B.2.1.12)
Selective Leaching VII.C1.A-66 3.3.1-72 A (B.2.1.22)
Heat Exchanger-Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (D/G Cooler) Tube (with internal Uncontrolled (External)
Monitoring of Mechanical Side Components coating) Components (B.2.1.24)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 4 Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)Loss of Material Open-Cycle Cooling Water VII.Cl.AP-194 3.3.1-37 C System (B.2.1.12)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 C 15% Zinc or More Uncontrolled (External)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-179 3.3.1-38 A System (B.2.1.12)
Selective Leaching VII.C1.A-66 3.3.1-72 A (8.2.1.22)
LaSalle CountYlrion, Units 1 and 2 License RenempWlication
.Page 3.3-151 0 Section 3 -Aging Managemt Review Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Pressure Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 C (DIG Cooler) Tube Uncontrolled (External)
Side Components Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 C System (B.2.1.12)
Heat Exchanger
-Heat Transfer Copper Alloy with Raw Water (Internal)
Reduction of Heat Open-Cycle Cooling Water VII.C1 .A-72 3.3.1-42 A (D/G Cooler) 15% Zinc or More Transfer System (B.2.1.12)
Tubes Pressure Boundary Copper Alloy with Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-179 3.3.1-38 A 15% Zinc or More System (B.2.1.12)
Selective Leaching VII.C1.A-66 3.3.1-72 A (B.2.1.22)
Heat Exchanger
-Pressure Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A LPCS Pump Motor Uncontrolled (External)
Monitoring of Mechanical Cooler) Shell Side Components (B.2.1.24)
Components Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-131 3.3.1-98 A (B.2.1.26)
One-Time Inspection VII.H2.AP-131 3.3.1-98 A (B.2.1.21)
Heat Exchanger-Pressure Boundary Stainless Steel Lubricating Oil Loss of Material Lubricating Oil Analysis VII.C2.AP-138 3.3.1-100 C (LPCS Pump Motor (External) (B.2.1.26)
Cooler) Tube Side One-Time Inspection VII.C2.AP-138 3.3.1-100 C Components (B.2.1.21)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C .A-54 3.3.1-40 C System (B.2.1.12)
Heat Exchanger
-Heat Transfer Stainless Steel Lubricating Oil Reduction of Heat Lubricating Oil Analysis V.D2.EP-79 3.2.1-51 A (LPCS Pump Motor (External)
Transfer (B.2.1.26)
Cooler) Tubes One-Time Inspection V.D2.EP-79 3.2.1-51 A (B.2.1.21)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-152 Section 3 -Aging Management Review Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Heat Transfer Stainless Steel Raw Water (Internal)
Reduction of Heat Open-Cycle Cooling Water VII.C1.AP-187 3.3.1-42 A (LPCS Pump Motor Transfer System (B.2.1.12)
Cooler) Tubes Pressure Boundary Stainless Steel Lubricating Oil Loss of Material Lubricating Oil Analysis VII.C2.AP-138 3.3.1-100 C (External) (B.2.1.26)
One-Time Inspection VII.C2.AP-138 3.3.1-100 C (B.2.1.21)
Raw Water (internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 C System (B.2.1.12)
Heat Exchanger
-Pressure Boundary Stainless Steel Raw Water (internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 C (RHR Heat System (B.2.1.12)
Exchanger)
Tube Sheet Heat Exchanger
-Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (RHR Heat Uncontrolled (External)
Monitoring of Mechanical Exchanger)
Tube Components (B.2.1.24)
Side Components Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 A System (B.2.1.12)
Heat Exchanger
-Heat Transfer Stainless Steel Raw Water (Internal)
Reduction of Heat Open-Cycle Cooling Water VII.C1.AP-187 3.3.1-42 A (RHR Heat Transfer System (B.2.1.12)
Exchanger)Tubes Pressure Boundary Stainless Steel Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 C System (B.2.1.12)
Heat Exchanger
-Pressure Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (RHR Pump Seal Uncontrolled (External)
Monitoring of Mechanical Cooler) Shell Side Components (B.2.1.24)
Components Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 A System (B.2.1.12)
LaSalle County on, Units 1 and 2 License ReneVW lication* Page 3.3-153 Section 3 -Aging Manageme Review Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger-Pressure Boundary Gray Cast Iron Raw Water (Internal)
Loss of Material Selective Leaching VII.C1.A-51 3.3.1-72 C (RHR Pump Seal (B.2.1.22)
Cooler) Shell Side Components Heat Exchanger
-Pressure Boundary Stainless Steel Raw Water (External)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 C (RHR Pump Seal System (B.2.1.12)
Cooler) Tube Side Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 C Components (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-110 3.3.1-25 D Heat Exchanger-Heat Transfer Stainless Steel Raw Water (External)
Reduction of Heat Open-Cycle Cooling Water VII.C1.AP-187 3.3.1-42 A (RHR Pump Seal Transfer System (B.2.1.12)
Cooler) Tubes Treated Water (Internal)
Reduction of Heat One-Time Inspection VII.E3.AP-139 3.3.1-27 A Transfer (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-139 3.3.1-27 B Pressure Boundary Stainless Steel Raw Water (External)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 C System (B.2.1.12)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 D Hoses Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C .A-54 3.3.1-40 A System (B.2.1.12)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-154 Section 3 -Aging Management Review Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Leakage Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78 A Raw Water (Internal)
Loss of Material Open-Cycle Cooling Watei System (B.2.1.12)
VII.C .AP-183 3.3.1-38 C VII.C .A-400 3.3.1-127 E, 5 Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Raw Water (Internal)
Loss of Material Open-Cycle Cooling Watei System (B.2.1.12)
VII.C .A-54 3.3.1-40 A Pressure Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1 .24'i VII.I.A-77 3.3.1-78 A Air -Outdoor (External)
Loss of Material Buried and Underground VII.H1.A-24 3.3.1-80 E, 1 Piping (B.2.1.28)
Concrete (External)
None None VII.J.AP-282 3.3.1-112 A Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
VII.C1.A-400 3.3.1-127 E, 5 Soil (External)
Loss of Material Buried and Underground Piping (B.2.1.28)
VII.G.AP-198 3.3.1-106 A Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Condensation (External)
Cracking External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.C .A-405 3.3.1-132 A, 6 Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.C .A-405 3.3.1-132 A, 6 LaSalle Countyon, Units 1 and 2 License Rene W lication.Page 3.3-155 Section 3 -Aging Managetneview Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Stainless Steel Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 A components, and System (B.2.1.12) piping elements Pump Casing (DIG Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-123 3.3.1-120 A Cooling Water Uncontrolled (External)
ODG01 P) Condensation Cracking External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 6 Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1 .A-54 3.3.1-40 A System (B.2.1.12)
Pump Casing (D/G Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Cooling Water Uncontrolled (External)
Monitoring of Mechanical 1DG01P/2DG01 P) Components (B.2.1.24)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Pump Casing (Fuel Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Pool Emergency Uncontrolled (External)
Monitoring of Mechanical Makeup) Components (B.2.1.24)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Carbon or Low Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1 .A-54 3.3.1-40 A Alloy Steel with System (B.2.1.12)
Stainless Steel Cladding LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-156 Section 3 -Aging Management Review Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (HPCS DIG Uncontrolled (External)
Monitoring of Mechanical Cooling Water) Components (B.2.1.24)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Pump Casing Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A (RHR Service Uncontrolled (External)
Water) Condensation Cracking External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.Cl .A-405 3.3.1-132 A, 6 Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 A System (B.2.1.12)
Strainer Body Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII .I.A-77 3.3.1-78 A (with internal Uncontrolled (External)
Monitoring of Mechanical coating) Components (B.2.1.24)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 4 Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)Loss of Material Open-Cycle Cooling Wate VII.C1.AP-194 3.3.1-37 A System (B.2.1.12)
I I _ I LaSalle County" on, Units 1 and 2 License ReneW lication.Page 3.3-157 0 Section 3 -Aging Manageteview Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item I Management Strainer Body Pressure Boundary Carbon or Low Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 A Alloy Steel with System (B.2.1.12)
Stainless Steel Cladding Strainer Element Filter Stainless Steel Raw Water (External)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 A System (B.2.1.12)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 A System (B.2.1.12)
Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C .A-54 3.3.1-40 A System (B.2.1.12)
Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Air -Outdoor (External)
Loss of Material Buried and Underground VII.H1 .A-24 3.3.1-80 E, 1 Piping (B.2.1.28)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation Cracking External Surfaces VII.C1.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical I____ _ I__ Components (B.2.1.24)
I I I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-158 Section 3 -Aging Management Review Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Stainless Steel Condensation Loss of Material External Surfaces VII.CI.A-405 3.3.1-132 A, 6 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Wate VII.C1 .A-54 3.3.1-40 A System (B.2.1.12)
_ _ I LaSalle Countliftion, Units 1 and 2 License ReneWplication
.Page 3.3-159 Section 3 -Aging Manage 9 enReview Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The Buried and Underground Piping (B.2.1.28) program is substituted to manage the aging effect applicable to this component type, material, and environment combination.
: 2. The Open-Cycle Cooling Water System (B.2.1.12) program is substituted to manage the aging effect applicable to this component type, material, and environment combination.
: 3. The aging effects for copper alloy (ASTM SB-171) with 15% zinc or more (with internal coating) in a raw water environment include loss of coating integrity.
The Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable to copper alloy with 15% zinc or more (with internal coating) in a raw water environment.
: 4. The aging effects for carbon steel (D/G cooler channel shell SA-106 Gr. B, channel flanges SA-285 Gr. C, channel covers SA-285, nozzle flanges SA-181/SA-105; strainer body carbon steel) with internal coating in a raw water environment include loss of coating integrity.
The Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable to carbon steel (with internal coating) in a raw water environment.
LaSalle County Station, Units 1 and 2 Page 3.3-160 License Renewal Application Section 3 -Aging Management Review Results Table 3.3.2-11 Essential Cooling Water System (Continued)
Plant Specific Notes: (continued)
: 5. NUREG-1 801, as amended by LR-ISG-2012-02, specifies a plant-specific program. The Open-Cycle Cooling Water System (B.2.1.12) program is used to manage the aging effect applicable to this component type, material, and environment combination.
: 6. These components are in an air-indoor, uncontrolled environment, and are insulated.
Because of the potential for air in-leakage through minor gaps in insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dew point of the air on the external surfaces of the insulation.
LaSalle Countwftion, Units 1 and 2 License ReneW plication 0.Page 3.3-161 0 Section 3 -Aging Manageet Review Results Table 3.3.2-12 Fire Protection System Summary of Aging Management Evaluation Table 3.3.2-12 Fire Protection System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Raw Water (External)
Loss of Material Bolting Integrity (B.2.1.11)
VII.G.A-33 3.3.1-64 E, 1 Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-264 3.3.1-15 A Soil (External)
Loss of Material Buried and Underground VII.I.AP-241 3.3.1-109 A Piping (B.2.1.28)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-242 3.3.1-14 A Stainless Steel Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Fire Barriers Fire Barrier Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 C (Damper Housing) Uncontrolled (External)
Condensation (Internal)
Loss of Material Fire Protection (B.2.1.16)
VII.F1.A-08 3.3.1-90 E, 10 Fire Barriers Fire Barrier Carbon Steel Air -Indoor Loss of Material Fire Protection (B.2.1.16)
VII.I.A-77 3.3.1-78 E, 2 (Doors) Uncontrolled (External)
VII.G.A-21 3.3.1-59 A Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 C Uncontrolled (External)
Air -Outdoor (External)
Loss of Material Fire Protection (B.2.1.16)
VII.I.A-78 3.3.1-78 E, 2 VII.G.A-22 3.3.1-59 A Fire Barriers (For Fire Barrier Aluminum Air- Indoor Cracking Fire Protection (B.2.1.16)
F, 3 Steel Components)
Silicate Uncontrolled (External)
III LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-162 Section 3 -Aging Management Review Results Table 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Fire Barriers (For Fire Barrier Ceramic Fiber Air -Indoor None Fire Protection (B.2.1.16)
F, 4 Steel Components)
Uncontrolled (External)
Pyrocrete Air -Indoor Cracking Fire Protection (B.2.1.16)
F, 3 Uncontrolled (External)
Fire Barriers Fire Barrier Calcium Silicate Air- Indoor None Fire Protection (B.2.1.16)
F, 4 (Penetration Seals Uncontrolled (External) and Fire Stops) Ceramic Fiber Air- Indoor None Fire Protection (B.2.1.16)
F, 4 Uncontrolled (External)
Elastomers Air- Indoor Change in Material Fire Protection (B.2.1.16)
VII.G.A-19 3.3.1-57 A Uncontrolled (External)
Properties Grout Air- Indoor Cracking Fire Protection (B.2.1.16)
VII.G.A-90 3.3.1-60 A, 5 Uncontrolled (External)
Structures Monitoring VII.G.A-90 3.3.1-60 A, 5 (B.2.1.34)
Gypsum Air -Indoor Cracking Fire Protection (B.2.1.16)
F, 3 Uncontrolled (External)
Mineral Fiber Air- Indoor None Fire Protection (B.2.1.16)
F, 4 Uncontrolled (External)
Fire Barriers (Walls Fire Barrier Concrete Block Air- Indoor Concrete Cracking and Fire Protection (B.2.1.16)
VII.G.A-90 3.3.1-60 A and Slabs) Uncontrolled (External)
Spalling Structures Monitoring VII.G.A-90 3.3.1-60 A (B.2.1.34)
Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 C Uncontrolled (External)
Gypsum Air -Indoor Cracking Fire Protection (B.2.1.16)
F, 3 Uncontrolled (External)
Reinforced Air- Indoor Concrete Cracking and Fire Protection (B.2.1.16)
VII.G.A-90 3.3.1-60 A Concrete Uncontrolled (External)
Spalling Structures Monitoring VII.G.A-90 3.3.1-60 A (B.2.1.34)
Loss of Material Fire Protection (B.2.1.16)
VII.G.A-91 3.3.1-62 A LaSalle Count~j~ ion, Units 1 and 2 License ReneW plication 0 Page 3.3-163 Section 3 -Aging Managemt Review Results Table 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Fire Barriers (Walls Fire Barrier Reinforced Air -Indoor Loss of Material Structures Monitoring VII.G.A-91 3.3.1-62 A and Slabs) Concrete Uncontrolled (External) (B.2.1.34)
Air- Outdoor (External)
Concrete Cracking and Fire Protection (B.2.1.16)
VII.G.A-92 3.3.1-61 A Spalling Structures Monitoring VII.G.A-92 3.3.1-61 A (B.2.1.34)
Loss of Material Fire Protection (B.2.1.16)
VII.G.A-93 3.3.1-62 A Structures Monitoring VII.G.A-93 3.3.1-62 A (B.2.1.34)
Fire Hydrant Pressure Boundary Ductile Cast Iron Air -Outdoor (External)
Loss of Material Fire Water System VII.G.AP-149 3.3.1-63 B (B.2.1.17)
Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-33 3.3.1-64 B (B.2.1.17)
Soil (External)
Loss of Material Buried and Underground VII.G.AP-198 3.3.1-106 A Piping (B.2.1.28)
Hose Stations Structural Support Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Racks, Reels, and Uncontrolled (External)
Monitoring of Mechanical Supports)
Components (B.2.1.24)
Hoses (Diesel Fire Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Pump) Uncontrolled (External)
Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-55 3.3.1-66 B (B.2.1.17)
Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 A LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-164 Section 3 -Aging Management Review Results Table 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Fire Protection (B.2.1.16)
VII.G.AP-150 3.3.1-58 A, 9 Air -Outdoor (External)
Loss of Material External Surfaces VII.I.A-78 3.3.1-78 A Monitoring of Mechanical Components (B.2.1.24)
Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 A Condensation (Internal)
Loss of Material Fire Water System VII.G.A-404 3.3.1-131 B (B.2.1.17)
Diesel Exhaust Cumulative Fatigue TLAA H, 6 (Internal)
Damage Loss of Material Inspection of Internal VII.H2.AP-104 3.3.1-88 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-33 3.3.1-64 B (B.2.1.17)
VII.G.A-400 3.3.1-127 E, 8 Soil (External)
Loss of Material Buried and Underground VII.G.AP-198 3.3.1-106 A Piping (B.2.1.28)
Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 A Uncontrolled (External)
Air -Outdoor (External)
Loss of Material External Surfaces VII.I.A-78 3.3.1-78 A Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
LaSalle County lition, Units 1 and 2 License Rene plication* Page 3.3-165 9 0 Section 3-Aging Managemeview Results Table 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Galvanized Steel Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 7 components, and Service Level III piping elements Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)Loss of Material Fire Water System VII.G.A-33 3.3.1-64 B (B.2.1.17)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Air -Indoor Loss of Material Fire Water System VII.G.A-404 3.3.1-131 B Uncontrolled (Internal) (B.2.1.17)
Condensation Loss of Material Fire Water System VII.G.A-404 3.3.1-131 B (External) (B.2.1.17)
Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-55 3.3.1-66 B (B.2.1.17)
Pump Casing Pressure Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.L.A-77 3.3.1-78 A (Diesel Fire Pump) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (External)
Loss of Material Fire Water System VII.G.A-33 3.3.1-64 B (B.2.1.17)
Selective Leaching VII.G.A-51 3.3.1-72 A (B.2.1.22)
Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-33 3.3.1-64 B (B.2.1.17)
Selective Leaching VII.G.A-51 3.3.1-72 A (B.2.1.22)
Pump Casing (Fire Pressure Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Intermediate Uncontrolled (External)
Pump) Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-55 3.3.1-66 B (B.2.1.17)
Pump Casing (Fire Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Jockey Pump) _ _ Uncontrolled (External)
_ _ __LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-166 Section 3 -Aging Management Review Results Table 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing (Fire Pressure Boundary Stainless Steel Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-55 3.3.1-66 B Jockey Pump) (B.2.1.17)
Spray Nozzles Spray Copper Alloy with Air -Indoor Loss of Material Fire Water System VII.G.A-403 3.3.1-130 B less than 15% Uncontrolled (External) (B.2.1.17)
Zinc Air -Outdoor (External)
Loss of Material Fire Water System VII.G.A-403 3.3.1-130 B (B.2.1.17)
Condensation (Internal)
Loss of Material Fire Water System VII.G.A-403 3.3.1-130 B (B.2.1.17)
Sprinkler Heads Pressure Boundary Copper Alloy with Air -Indoor Loss of Material Fire Water System VII.G.A-403 3.3.1-130 B less than 15% Uncontrolled (External) (B.2.1.17)
Zinc Condensation (Internal)
Loss of Material Fire Water System VII.G.A-403 3.3.1-130 B (B.2.1.17)
Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-403 3.3.1-130 B (B.2.1.17)
Spray Copper Alloy with Air -Indoor Loss of Material Fire Water System VII.G.A-403 3.3.1-130 B less than 15% Uncontrolled (External) (B.2.1.17)
Zinc Condensation (Internal)
Loss of Material Fire Water System VII.G.A-403 3.3.1-130 B (B.2.1.17)
Strainer Element Filter Stainless Steel Raw Water (External)
Loss of Material Fire Water System VII.G.A-55 3.3.1-66 B (B.2.1.17)
Tanks (Cardox Pressure Boundary Carbon Steel Air- Indoor Loss of Material Fire Protection (B.2.1.16)
VII.G.AP-150 3.3.1-58 A, 9 Storage) Uncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 C Tanks (Retard Pressure Boundary Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 C Chamber) less than 15% Uncontrolled (External)
Zinc Raw Water (Internal)
Loss of Material Fire Water System VII.G.AP-197 3.3.1-64 D I_ (B.2.1.17)
LaSalle County~lton, Units 1 and 2 License ReneV P lication.Page 3.3-167 0 0 Section 3 -Aging Managem 9 Review Results Table 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Tanks (Retard Pressure Boundary Ductile Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Chamber) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-33 3.3.1-64 D (B.2.1.17)
Valve Body Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc Air/Gas -Dry (Internal)
None None VII.J.AP-8 3.3.1-114 A Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Raw Water (Internal)
Loss of Material Fire Water System VII.G.AP-197 3.3.1-64 B (B.2.1.17)
Ductile Cast Iron Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-33 3.3.1-64 B (B.2.1.17)
Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (8.2.1.24)
Fire Protection (B.2.1.16)
VII.G.AP-150 3.3.1-58 A, 9 Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 A LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-168 Section 3 -Aging Management Review Results Table 3.3.2-12 Fire Protection System (Continued)
Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Requiring Programs Item Management Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-33 3.3.1-64 B (B.2.1.17)
I I I Selective Leaching VII.G.A-51 3.3.1-72 A (B.2.1.22)
I I I Soil (External)
Loss of Material Buried and Underground PiDina (B.2.1.28)
VII.G.AP-1198 3.3.1-106 A-. + 4 Selective Leaching (B.2.1.221 VII.G.A-02 3.3.1-72 A LaSalle Countydion, Units 1 and 2 License Renelw lication.Page 3.3-169 0 0 Section 3- Aging Managemt Review Results Table 3.3.2-12 Fire Protection System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The Bolting Integrity (B.2.1.11) program is substituted to manage the aging effect applicable to this component type, material, and environment combination.
Inspection activities for bolting in a submerged environment are performed in conjunction with associated component maintenance activities.
: 2. The Fire Protection (B.2.1.16) program is substituted to manage the aging effect(s) applicable to this component type, material, and environment combination.
The visual periodic inspection of fire-rated doors is within the scope of the Fire Protection (B.2.1.16) program.3. The Fire Protection (B.2.1.16) program will be used to manage the aging effect(s) applicable to this component type, material, and environment combination.
: 4. Based on plant operating experience, there are no aging effects requiring aging management for calcium silicate, ceramic fiber, and mineral fiber in an Air-Indoor Uncontrolled environment.
These materials do not experience aging effects unless exposed to temperatures, radiation, or chemicals capable of attacking the specific chemical composition.
These materials in this non-aggressive air environment are not expected to experience significant aging effects. Nonetheless, the Fire Protection (B.2.1.16) program is credited for assuring the absence of any aging effects.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-170 Section 3 -Aging Management Review Results Table 3.3.2-12 Fire Protection System (Continued)
Plant Specific Notes: (continued)
: 5. NUREG-1 801 does not include grout fire barriers, however, grout is similar to concrete in terms of characteristics and is considered to be susceptible to the same aging effects and mechanisms as reinforced concrete.
These aging effects and mechanisms are managed by the Fire Protection (B.2.1.16) and Structures Monitoring (B.2.1.34) programs.6. This component is associated with carbon steel (ASTM A-106 Gr. B) diesel-driven fire pump engine exhaust piping in a diesel exhaust environment.
TLAA is used to manage cumulative fatigue damage for this component type, material, and environment combination.
The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.7. The aging effects for galvanized steel (ASTM A-53 Gr. B) in a raw water environment include loss of coating integrity.
The Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable to galvanized steel in a raw water environment.
: 8. NUREG-1801, as amended by LR-ISG-2012-02, specifies a plant-specific program. The Fire Water System (B.2.1.17) program is used to manage the aging effect applicable to this component type, material, and environment combination.
: 9. The Fire Protection (B.2.1.16) program manages the external surfaces of carbon dioxide fire suppression system carbon steel piping, piping components, and piping elements and tanks exposed to an air -indoor uncontrolled (external) environment.
: 10. The Fire Protection (B.2.1.16) program is added to supplement the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program in managing the aging effect(s) applicable to this component type, material, and environment combination.
The damper housings for dampers with a fire barrier intended function are evaluated with the Fire Protection System and are inspected in accordance with Fire Protection (B.2.1.16) program requirements.
Fire barrier damper housings located within the in scope boundary of the various ventilation systems also have a pressure boundary intended function and are inspected in accordance with the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program. The pressure boundary intended function is evaluated with the various ventilation systems.LaSalle CountwK'on, Units 1 and 2 License ReneWOFplication 0 Page 3.3-171 Section 3 -Aging Manage#eReview Results Table 3.3.2-13 Fuel Pool Cooling and Storage System Summary of Aging Management Evaluation Table 3.3.2-13 Fuel Pool Cooling and Storage System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.l.AP-124 3.3.1-15 A Bolting Stainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Control Rod Blade Structural Integrity Stainless Steel Treated Water Loss of Material One-Time Inspection VII.A2.A-98 3.3.1-125 C Storage Racks (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A2.A-98 3.3.1-125 D Fuel Storage Structural Integrity Stainless Steel Treated Water Loss of Material One-Time Inspection VII.A2.A-98 3.3.1-125 C Racks (Defective (External) (B.2.1.21)
Fuel) Water Chemistry (B.2.1.2)
VII.A2.A-98 3.3.1-125 D Fuel Storage Structural Integrity Aluminum Alloy Air- Indoor None None VII.J.AP-135 3.3.1-113 C Racks (New Fuel Uncontrolled (External)
Storage) Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 C Uncontrolled (External)
Fuel Storage Absorb Neutrons Boral Treated Water Reduction of Neutron Monitoring of Neutron- VII.A2.AP-236 3.3.1-102 A Racks (Unit 1 (External)
Absorbing Capacity; Absorbing Materials Other Spent Fuel) Change in Dimensions Than Boraflex (B.2.1.27) and Loss of Material Structural Integrity Stainless Steel Treated Water Loss of Material One-Time Inspection VII.A2.A-98 3.3.1-125 A (External) (B.2.1.21)
_ _ Water Chemistry (B.2.1.2)
VII.A2.A-98 3.3.1-125 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-172 Section 3 -Aging Management Review Results Table 3.3.2-13 Fuel Pool Cooling and Storage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item t Management Fuel Storage Absorb Neutrons Rio-Tinto Alcan Treated Water Reduction of Neutron Monitoring of Neutron- VII.A2.AP-236 3.3.1-102 A Racks (Unit 2 Composite (External)
Absorbing Capacity; Absorbing Materials Other Spent Fuel) Change in Dimensions Than Boraflex (B.2.1.27) and Loss of Material Structural Integrity Stainless Steel Treated Water Loss of Material One-Time Inspection VII.A2.A-98 3.3.1-125 A (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A2.A-98 3.3.1-125 B Heat Exchanger-Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Fuel Pool Cooling) Uncontrolled (External)
Monitoring of Mechanical Shell Side Components (B.2.1.24)
Components Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 D Hoses Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Piping, piping Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Waste Water (Internal)
None None VII.J.AP-277 3.3.1-119 A LaSalle Countylion, Units 1 and 2 License ReneWplication O Page 3.3-173 Section 3 -Aging Manage 9 Review Results Table 3.3.2-13 Fuel Pool Cooling and Storage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Piping, piping Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A components, and Uncontrolled (External) piping elements Treated Water (Internal)
Loss of Material One-Time Inspection VII.A4.AP-1 10 3.3.1-25 A (8.2.1.21)
Water Chemistry (B.2.1.2)
VII.A4.AP-1 10 3.3.1-25 B Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.A4.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A4.AP-110 3.3.1-25 B Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing (Fuel Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Pool Cooling Uncontrolled (External)
Monitoring of Mechanical Pump) Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-174 Section 3 -Aging Management Review Results Table 3.3.2-13 Fuel Pool Cooling and Storage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing (Fuel Leakage Boundary Carbon Steel Treated Water (Internal)
Loss of Material Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B Pool Cooling Pump)Strainer Element Filter Stainless Steel Treated Water Loss of Material One-Time Inspection VII.A4.AP-1 10 3.3.1-25 C (Inside Skimmer (External) (B.2.1.21)
Surge Tank) Water Chemistry (B.2.1.2)
VII.A4.AP-110 3.3.1-25 D Tanks (Skimmer Pressure Boundary Stainless Steel Air -Indoor None None VII.J AP-17 3.3.1-120 C Surge Tanks) Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.A4.AP-1 10 3.3.1-25 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A4.AP-110 3.3.1-25 D Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.A4.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A4.AP-110 3.3.1-25 B LaSalle Count-lMion, Units 1 and 2 License ReneW plication.Page 3.3-175 Section 3 -Aging Manage Review Results Table 3.3.2-13 Fuel Pool Cooling and Storage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Stainless Steel Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.A4.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A4.AP-110 3.3.1-25 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-176 Section 3 -Aging Management Review Results Table 3.3.2-13 Fuel Pool Cooling and Storage System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1 801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1801.
Plant Specific Notes: None.LaSalle Countvition, Units 1 and 2 i sc o Page 3.3-177 License Rene W licationWw 0 O Section 3 -Aging Managem#Review Results Table 3.3.2-14 Nonessential Cooling Water System Summary of Aging Management Evaluation Table 3.3.2-14 Nonessential Cooling Water System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.L.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.L.AP-124 3.3.1-15 A Bolting Raw Water (External)
Loss of Material Bolting Integrity (B.2.1.11)
VII.G.A-33 3.3.1-64 E, 2, 6 Loss of Preload Bolting Integrity (B.2.1.11)
VII.L.AP-264 3.3.1-15 A, 2 Structural Integrity Carbon and Low Raw Water (External)
Loss of Material Bolting Integrity (B.2.1.11)
VII.G.A-33 3.3.1-64 E, 6 Alloy Steel Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-264 3.3.1-15 A Bolting Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Aux Bldg. HVAC (with internal Uncontrolled (External)
Monitoring of Mechanical Condenser Unit) coating) Components (B.2.1.24)
Tube Side Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 Components (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 3 Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)Loss of Material Open-Cycle Cooling Wate VII.C1.AP-194 3.3.1-37 C System (B.2.1.12) rl LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-178 Section 3 -Aging Management Review Results Table 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item qI Management Heat Exchanger-Leakage Boundary Copper Alloy with Air/Gas -Dry (External)
None None VII.J.AP-9 3.3.1-114 C (Aux Bldg. HVAC less than 15% Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-179 3.3.1-38 A Condenser Unit) Zinc Tubes System (B.2.1.12)
Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.L.A-77 3.3.1-78 A (Counting Room (with internal Uncontrolled (External)
Monitoring of Mechanical HVAC Condenser coating) Components (B.2.1.24)
Unit) Tube Side Raw Water (Internal)
Loss of Coating Integrity Service Level Ill and H, 3 Components Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)Loss of Material Open-Cycle Cooling Water VII.C1.AP-194 3.3.1-37 C System (B.2.1.12)
Heat Exchanger
-Leakage Boundary Copper Alloy with Air/Gas -Dry (External)
None None VII.J.AP-9 3.3.1-114 C (Counting Room less than 15% Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-179 3.3.1-38 A HVAC Condenser Zinc Unit) Tubes System (B.2.1.12)
Heat Exchanger-Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Fuel Pool Cooling) (with internal Uncontrolled (External)
Monitoring of Mechanical Tube Side coating) Components (B.2.1.24)
Components Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 (External)
Monitoring of Mechanical 1_ _ 1__ _Components (B.2.1.24)
I I LaSalle Countydion, Units 1 and 2 License Rene W lication 0 Page 3.3-179 Section 3-Aging Managemeview Results Table 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management H Heat Exchanger
-Leakage Boundary Carbon Steel Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 3 (Fuel Pool Cooling) (with internal Service Level III Tube Side coating) Augmented Coatings Components Monitoring and Maintenance Program (B.2.2.1)Loss of Material Open-Cycle Cooling Water VII.C1.AP-194 3.3.1-37 C System (B.2.1.12)
Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.A-77 3.3.1-78 A (Primary (with internal Uncontrolled (External)
Monitoring of Mechanical Containment coating) Components (B.2.1.24)
Ventilation Chiller Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 Condenser)
Tube (External)
Monitoring of Mechanical Side Components Components (B.2.1.24)
Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 3 Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)Loss of Material Open-Cycle Cooling Water VII.C1.AP-194 3.3.1-37 C System (B.2.1.12)
Heat Exchanger
-Leakage Boundary Copper Alloy with Air/Gas -Dry (External)
None None VII.J.AP-9 3.3.1-114 C (Primary less than 15% Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-179 3.3.1-38 A Containment Zinc Ventilation Chiller System (B.2.1.12)
Service Water Condenser)
Tubes LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-180 Section 3 -Aging Management Review Results Table 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item T_ Management Heat Exchanger-Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Process Computer Uncontrolled (External)
Monitoring of Mechanical Room A/C Unit) Components (B.2.1.24)
Tube Side Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 A Components System (B.2.1.12)
Heat Exchanger-Leakage Boundary Copper Alloy with Air/Gas -Dry (External)
None None VII.J.AP-9 3.3.1-114 C (Process Computer less than 15% Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-179 3.3.1-38 A Room A/C Unit) Zinc System (B.2.1.12)
Tubes Heat Exchanger
-Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Reactor Building (with internal Uncontrolled (External)
Monitoring of Mechanical Closed Cooling coating) Components (B.2.1.24)
Water Heat Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 Exchanger)
Tube (External)
Monitoring of Mechanical Side Components Components (B.2.1.24)
Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 3 Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)Loss of Material Open-Cycle Cooling Water VII.C1.AP-194 3.3.1-37 C System (B.2.1.12)
Piping, piping Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
LaSalle County.i~on, Units 1 and 2 License RenelW lication 0 Page 3.3-181 Section 3 -Aging Managem 9 Review Results Table 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item I __ __ _Management Piping, piping components, and piping elements Leakage Boundary Carbon Steel Condensation (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.C .A-405 3.3.1-132 A, 7 Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water System (B.2.1.12)
VII.C1.AP-183 3.3.1-38 C VIICI .A-400 3.3.1-127 E. 4 I 4 4 + 4 Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Condensation Cracking External Surfaces VII.C1.A-405 3.3.1-132 A, 7 (External)
Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water System (B.2.1.12)
VII.C .A-54 3.3.1-40 A V t 1~ 4 4 4 Pressure Boundary Aluminum Alloy Raw Water (External)
Loss of Material Open-Cycle Cooling Water Svstem (B.2.1.12)
VII.G.AP-180 3.3.1-65 E, 1 1- ~. -.+ 4 _______Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water Svstem (B.2.1.12)
VII.G.AP-1180 3.3.1-65 E, 1+ + -4 4 _____Carbon Steel Air- Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII. I.A-77 3.3.1-78 A Air -Outdoor (External)
Loss of Material Buried and Underground VII.H1 .A-24 3.3.1-80 E, 5 Piping (B.2.1.28)
External Surfaces VII.C1.A-405 3.3.1-132 A Monitoring of Mechanical Components (B.2.1.24)
Concrete (External)
None None VII.J.AP-282 3.3.1-112 A Condensation (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.C1 .A-405 3.3.1-132 A, 7 LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-182 Section 3 -Aging Management Review Results Table 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Carbon Steel Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C components, and System (B.2.1.12)
VII.C1.A-400 3.3.1-127 E, 4 piping elements Soil (External)
Loss of Material Buried and Underground VII.C3.AP-198 3.3.1-106 A Piping (B.2.1.28)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 A System (B.2.1.12)
Pump Casing Pressure Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Service Water) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Selective Leaching VII.C1.A-51 3.3.1-72 A (B.2.1.22)
Tanks (Clean Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Gland Water) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Traveling Water Structural Integrity Carbon Steel Raw Water (External)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-194 3.3.1-37 C Screen Framework (with external System (B.2.1.12) coating)Gray Cast Iron Concrete (External)
None None VII.J.AP-282 3.3.1-112 C LaSalle Countyiltion, Units 1 and 2 License ReneW plication.Page 3.3-183 9 0 Section 3 -Aging Management Review Results Table 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Traveling Water Structural Integrity Gray Cast Iron Raw Water (External)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C Screen Framework System (B.2.1.12)
Selective Leaching VII.C .A-51 3.3.1-72 C (B.2.1.22)
Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-196 3.3.1-36 A System (B.2.1.12)
Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Selective Leaching VII.C .A-51 3.3.1-72 A (B.2.1.22)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation Cracking External Surfaces VII.C1.A-405 3.3.1-132 A, 7 (External)
Monitoring of Mechanical Components_(B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-184 Section 3 -Aging Management Review Results Table 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Stainless Steel Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1 .A-54 3.3.1-40 A System (B.2.1.12)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Air -Outdoor (External)
Loss of Material Buried and Underground VII.H1 .A-24 3.3.1-80 E, 5 Piping (B.2.1.28)
External Surfaces VII.C1.A-405 3.3.1-132 A Monitoring of Mechanical Components (B.2.1.24)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 7 (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 C System (B.2.1.12)
Selective Leaching VII.C1 .A-51 3.3.1-72 A (B.2.1.22)
LaSalle Count~liton, Units 1 and 2 License ReneW plication 9 Page 3.3-185 0 0 Section 3 -Aging Management Review Results Table 3.3.2-14 Nonessential Cooling Water System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The Open Cycle Cooling Water System (B.2.1.12) program is substituted to manage the aging effect applicable to this component type, material, and environment combination.
: 2. Components in the Raw Water (External) environment are associated with the Service Water pump suction line safety barrier.3. The aging effects for carbon steel (with internal coating) in a raw water environment include loss of coating integrity.
The Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable to carbon steel (with internal coating) in a raw water environment.
: 4. NUREG-1801, as amended by LR-ISG-2012-02, specifies a plant-specific program. The Open-Cycle Cooling Water System (B.2.1.12) program is used to manage the aging effect applicable to this component type, material, and environment combination.
: 5. The Buried and Underground Piping (B.2.1.28) program is substituted to manage the aging effect applicable to this component type, material, and environment combination.
: 6. The Bolting Integrity (B.2.1.11) program is substituted to manage the aging effect applicable to this component type, material, and environment combination.
: 7. These components are in an air-indoor, uncontrolled environment, and are insulated.
Because of the potential for air in-leakage through minor gaps in insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dew point of the air on the external surfaces of the insulation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-186 Section 3 -Aging Management Review Results Table 3.3.2-15 Nonsafety-Related Ventilation System Summary of Aging Management Evaluation Table 3.3.2-15 Nonsafety-Related Ventilation System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Heat Exchanger-Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Primary Uncontrolled (External)
Monitoring of Mechanical Containment Vent Components (B.2.1.24)
Chiller Glycol Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-189 3.3.1-46 A Condenser)
Tube Water (Internal)
Systems (B.2.1.13)
Side Components Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 2 (External)
Monitoring of Mechanical Components (B.2.1.24)
Heat Exchanger-Leakage Boundary Copper Alloy with Air/Gas -Dry (External)
None None VII.J.AP-9 3.3.1-114 C (Primary less than 15% Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 C Containment Vent Zinc Water (Internal)
Systems (B.2.1.13)
Chiller Glycol Condenser)
Tubes LaSalle County,4Kon, Units 1 and 2 License ReneW lication.Page 3.3-187 0 0 Section 3 -Aging Management Review Results Table 3.3.2-15 Nonsafety-Related Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.L.A-77 3.3.1-78 A (Reactor Bldg., Uncontrolled (External)
Monitoring of Mechanical Turb Bldg., Components (B.2.1.24)
Switchgear Rm Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-189 3.3.1-46 A Supply and Water (Internal)
Systems (B.2.1.13)
Exhaust Coils)Tube Side Components Heat Exchanger-Leakage Boundary Copper Alloy with Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 C (Reactor Bldg., less than 15% Water (Internal)
Systems (B.2.1.13)
Turb Bldg., Zinc Condensation Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 C, 1 Switchgear Rm (External)
Surfaces in Miscellaneous Supply and Piping and Ducting Exhaust Coils) Components (B.2.1.25)
Tubes Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation Loss of Material External Surfaces VII.Cl A-405 3.3.1-132 A, 2 (External)
Monitoring of Mechanical Components (B.2.1.24)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Closed Cycle Cooling None None VII.J.AP-166 3.3.1-117 A Water (Internal)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 A LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-188 Section 3 -Aging Management Review Results Table 3.3.2-15 Nonsafety-Related Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item I Management Piping, piping Leakage Boundary Stainless Steel Air -Indoor None None VII J.AP-17 3.3.1-120 A components, and Uncontrolled (External) piping elements Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A Water (Internal)
Systems (B.2.1.13)
Pump Casing Leakage Boundary Ductile Cast Iron Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A (Heat Recovery Uncontrolled (External)
Monitoring of Mechanical Transfer Pumps, Components (B.2.1.24)
Fill Pump, Make-up Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Tank Pump, Heat Water (Internal)
Systems (B.2.1.13)
Coil Drain Pump)Condensation Loss of Material External Surfaces VII.Cl A-405 3.3.1-132 A, 2 (External)
Monitoring of Mechanical Components (B.2.1.24)
Tanks (Glycol Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 C Electric Heaters) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Tanks (Heat Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 C Recovery System Uncontrolled (External)
Monitoring of Mechanical Expansion Tank) Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Tanks (Heat Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 C Recovery System Uncontrolled (External)
Monitoring of Mechanical Make-up Tank) Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A___ Water (Internal)
Systems (B.2.1.13)
LaSalle Countfon, Units 1 and 2 License Rene W lication 0 Page 3.3-189 0 Section 3 -Aging Manage eview Results Table 3.3.2-15 Nonsafety-Related Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Tanks (Heat Leakage Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 C Recovery System Surfaces in Miscellaneous Make-up Tank) Piping and Ducting Components (B.2.1.25)
Valve Body Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 2 (External)
Monitoring of Mechanical Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-190 Section 3 -Aging Management Review Results Table 3.3.2-15 Nonsafety-Related Ventilation System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. This component is located internal to a heat exchanger, and therefore the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the applicable aging effects.2. These components are in an air-indoor, uncontrolled environment, and are insulated.
Because of the potential for air in-leakage through minor gaps in insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dew point of the air on the external surfaces of the insulation.
LaSalle Countympon, Units 1 and 2 RaPage 3.3-191 License RenevW licationWW Section 3 -Aging Managemevn Rview Results Table 3.3.2-16 Plant Drainage System Summary of Aging Management Evaluation Table 3.3.2-16 Plant Drainage System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Drywell Equipment Uncontrolled (External)
Monitoring of Mechanical Drain Sump Heat Components (B.2.1.24)
Exchanger)
Tube Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 C Side Components Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Reactor Building Uncontrolled (External)
Monitoring of Mechanical Equipment Drain Components (B.2.1.24)
Tank Heat Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 C Exchanger)
Tube Surfaces in Miscellaneous Side Components Piping and Ducting Components (B.2.1.25)
Hoses Leakage Boundary Polymers Air -Indoor None None VII.J.AP-268 3.3.1-119 A Uncontrolled (External)
Waste Water (Internal)
None None G, 1 Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-192 Section 3 -Aging Management Review Results Table 3.3.2-16 Plant Drainage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Hoses Leakage Boundary Stainless Steel Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous VII.E5.A-400 3.3.1-127 E, 2 Piping and Ducting Components (B.2.1.25)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-272 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 A Uncontrolled (External)
Waste Water (Internal)
Loss of Coating Integrity Service Level III and H, 3 Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1)Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous VII.E5.A-400 3.3.1-127 E, 2 Piping and Ducting Components (B.2.1.25)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Waste Water (Internal)
None None VII.J.AP-277 3.3.1-119 A LaSalle CountyJwton, Units 1 and 2 License Renev~W lication 0 Page 3.3-193 Section 3 -Aging ManagemenReview Results Table 3.3.2-16 Plant Drainage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A components, and Uncontrolled (External) piping elements Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Concrete (External)
None None VII.J.AP-282 3.3.1-112 A Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous VII.E5.A-400 3.3.1-127 E, 2 Piping and Ducting Components (B.2.1.25)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-272 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing Leakage Boundary Ductile Cast Iron Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Drywell Floor and Uncontrolled (External)
Monitoring of Mechanical Drywell Equipment Components (B.2.1.24)
Drain Pumps) IIIIIII_LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-194 Section 3 -Aging Management Review Results Table 3.3.2-16 Plant Drainage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing Leakage Boundary Ductile Cast Iron Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A (Drywell Floor and Surfaces in Miscellaneous Drywell Equipment Piping and Ducting Drain Pumps) Components (B.2.1.25)
Pump Casing Leakage Boundary Ductile Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Reactor Building Uncontrolled (External)
Monitoring of Mechanical Equipment Drain Components (B.2.1.24)
Pump) Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Sump Pumps) Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Tanks (Gland Seal Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Leakoff Reservoir)
Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Tanks (Reactor Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Building Equipment Uncontrolled (External)
Monitoring of Mechanical Drain Tank) Components (B.2.1.24)
LaSalle Countygimon, Units 1 and 2 License Rene~W lication.Page 3.3-195 0 Section 3 -Aging Management Review Results Table 3.3.2-16 Plant Drainage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Tanks (Reactor Leakage Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 A Building Equipment Surfaces in Miscellaneous Drain Tank) Piping and Ducting Components (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting I Components (B.2.1.25)
I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-196 Section 3 -Aging Management Review Results Table 3.3.2-16 Plant Drainage System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. Some system drains include polymer hoses (Tygon tubing). Tygon tubing has no aging effects in a Waste Water environment.
Tygon is a registered trademark of Norton Performance Plastics that represents a family of various thermoplastic polymers.
Tygon is a PVC-based material that is clear or transparent and normally used for flexible tubing. It is considered non-aging and non-oxidizing, and has broad chemical resistance.
: 2. NUREG-1801, as amended by LR-ISG-2012-02, specifies a plant-specific program. The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the aging effect applicable to this component type, material, and environment combination.
: 3. The aging effects for galvanized steel in a waste water environment include loss of coating integrity.
The Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable to galvanized steel in a waste water environment.
LaSalle Countyl on, Units 1 and 2 Page 3.3-197 License Rene W lication V Section 3 -Aging Managemen Review Results Table 3.3.2-17 Primary Containment Ventilation System Summary of Aging Management Evaluation Table 3.3.2-17 Primary Containment Ventilation System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Ducting and Leakage Boundary Stainless Steel Condensation Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 A, 1 Components (External)
Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.F3.AP-41 3.3.1-80 A (Primary Uncontrolled (External)
Monitoring of Mechanical Containment Vent Components (B.2.1.24)
Chiller Compressor Closed Cycle Cooling Loss of Material Closed Treated Water VII.F3.AP-189 3.3.1-46 A Oil Cooler) Shell Water (Internal)
Systems (B.2.1.13)
Side Components Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Primary Uncontrolled (External)
Monitoring of Mechanical Containment Vent Components (B.2.1.24)
Chiller Evaporator)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.F3.AP-189 3.3.1-46 A Tube Side Water (Internal)
Systems (B.2.1.13)
Components LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-198 Section 3 -Aging Management Review Results Table 3.3.2-17 Primary Containment Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Leakage Boundary Copper Alloy with Air/Gas -Dry (External)
None None VII.J.AP-9 3.3.1-114 C (Primary less than 15% Closed Cycle Cooling Loss of Material Closed Treated Water VII.F3.AP-203 3.3.1-46 A Containment Vent Zinc Water (Internal)
Systems (B.2.1.13)
Chiller Evaporator)
Tubes Heat Exchanger
-Leakage Boundary Copper Alloy with Closed Cycle Cooling Loss of Material Closed Treated Water VII.F3.AP-203 3.3.1-46 A (Primary less than 15% Water (Internal)
Systems (B.2.1.13)
Containment Zinc Condensation Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 C, 2 Ventilation HX and (External)
Surfaces in Miscellaneous Drywell Area Piping and Ducting Cooler) Tubes Components (B.2.1.25)
Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.F3.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation Loss of Material External Surfaces VII.F1.A-405 3.3.1-132 A, 3 (External)
Monitoring of Mechanical Components (B.2.1.24)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A less than 15% Uncontrolled (External)
Zinc Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-133 3.3.1-99 A (B.2.1.26)
One-Time Inspection VII.H2.AP-133 3.3.1-99 A (B.2.1.21)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A I Uncontrolled (External)
_ --]I LaSalle County on, Units 1 and 2 License ReneAyPlication
.Page 3.3-199 0 Section 3 -Aging Managet Review Results Table 3.3.2-17 Primary Containment Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Leakage Boundary Stainless Steel Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A components, and Water (Internal)
Systems (B.2.1.13) piping elements Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.F3.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation Loss of Material External Surfaces VII.F1.A-405 3.3.1-132 A, 3 (External)
Monitoring of Mechanical Components (B.2.1.24)
Pump Casing Leakage Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Primary Uncontrolled (External)
Monitoring of Mechanical Containment Components (B.2.1.24)
Chilled Water Closed Cycle Cooling Loss of Material Closed Treated Water VII.F3.AP-202 3.3.1-45 A Pumps) Water (Internal)
Systems (B.2.1.13)
Selective Leaching VII.F3.A-50 3.3.1-72 A (B.2.1.22)
Condensation Loss of Material External Surfaces VII.F1.A-405 3.3.1-132 A, 3 (External)
Monitoring of Mechanical Components (B.2.1.24)
Tanks (Chilled Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 C Water Holdup and Uncontrolled (External)
Monitoring of Mechanical Expansion Tanks, Components (B.2.1.24)
Chilled Water Closed Cycle Cooling Loss of Material Closed Treated Water VII.F3.AP-202 3.3.1-45 A Chemical Feeders) Water (Internal)
Systems (B.2.1.13)
Condensation Loss of Material External Surfaces VII.FI.A-405 3.3.1-132 A, 3 (External)
Monitoring of Mechanical Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-200 Section 3 -Aging Management Review Results Table 3.3.2-17 Primary Containment Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Tanks (Chilled Leakage Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 C Water Holdup and Surfaces in Miscellaneous Expansion Tanks, Piping and Ducting Chilled Water Components (B.2.1.25)
Chemical Feeders)Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.F3.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation Loss of Material External Surfaces VII.F1.A-405 3.3.1-132 A, 3 (External)
Monitoring of Mechanical Components (B.2.1.24)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A 15% Zinc or More Uncontrolled (External)
Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-133 3.3.1-99 A (B.2.1.26)
One-Time Inspection VII.H2.AP-133 3.3.1-99 A (B.2.1.21)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A Water (Internal)
Systems (B.2.1.13)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.F3.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Condensation Loss of Material External Surfaces VII.FI.A-405 3.3.1-132 A, 3 (External)
Monitoring of Mechanical Components (B.2.1.24)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
I I I LaSalle County~jion, Units 1 and 2 License )lication* Page 3.3-201 0 0 Section 3 -Aging ManageReview Results Table 3.3.2-17 Primary Containment Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Stainless Steel Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A_ _ Water (Internal)
I [ Systems (B.2.1.13)
I I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-202 Section 3 -Aging Management Review Results Table 3.3.2-17 Primary Containment Ventilation System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The stainless steel drip pan is located internal to the ventilation ductwork, and therefore the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the applicable aging effects.2. This component is located internal to a heat exchanger, and therefore the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the applicable aging effects.3. These components are in an air-indoor, uncontrolled environment, and are insulated.
Because of the potential for air in-leakage through minor gaps in insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dew point of the air on the external surfaces of the insulation.
LaSalle County 4fton, Units 1 and 2 O Page 3.3-203 License )lication 0 Section 3 -Aging Managel eview Results Table 3.3.2-18 Process Radiation Monitoring System Summary of Aging Management Evaluation Table 3.3.2-18 Process Radiation Monitoring System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Stainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Hoses Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A Water (Internal)
Systems (B.2.1.13)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 A System (B.2.1.12)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Piping, piping Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A components, and Uncontrolled (External) piping elements Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A Water (Internal)
Systems (B.2.1.13)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1 .A-54 3.3.1-40 A I__ __ I__ System (B.2.1.12)
_ _ _ _LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-204 Section 3 -Aging Management Review Results Table 3.3.2-18 Process Radiation Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item t t Management Piping, piping Leakage Boundary Stainless Steel Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A components, and Surfaces in Miscellaneous piping elements Piping and Ducting Components (B.2.1.25)
Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 A Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Structural Integrity Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing ( Pressure Boundary Aluminum Alloy Air -Indoor None None VII.J.AP-135 3.3.1-113 A SGTS and SVS Uncontrolled (External)
Wide Range Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 A Sample Pumps) Surfaces in Miscellaneous Piping and Ducting I _Components (B.2.1.25)
LaSalle Countyiftion, Units 1 and 2 License ReneW lication O Page 3.3-205 0 0 Section 3 -Aging Manage 9 eview Results Table 3.3.2-18 Process Radiation Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A (RHR Service Uncontrolled (External)
Water Sample Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 A Pumps) System (B.2.1.12)
Pump Casing Structural Integrity Aluminum Alloy Air- Indoor None None VII.J.AP-135 3.3.1-113 A (SGTS Vent Uncontrolled (External)
Monitor 0PL058 Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 A Sample Pumps) Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing Leakage Boundary Copper Alloy with Air- Indoor None None VII.J.AP-144 3.3.1-114 A (Sample Pumps -less than 15% Uncontrolled (External)
Radwaste, Service Zinc Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 A Water, RBCCW) Water (Internal)
Systems (B.2.1.13)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-196 3.3.1-36 A System (B.2.1.12)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-272 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Valve Body Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A Water (Internal)
Systems (B.2.1.13)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C .A-54 3.3.1-40 A System (B.2.1.12) j LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-206 Section 3 -Aging Management Review Results Table 3.3.2-18 Process Radiation Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Stainless Steel Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Structural Integrity Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting I Components (B.2.1.25)_
LaSalle Countvftion, Units 1 and 2 License ReneW plication.Page 3.3-207 Section 3- Aging Management Review Results Table 3.3.2-18 Process Radiation Monitoring System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: None.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-208 Section 3 -Aging Management Review Results Table 3.3.2-19 Process Sampling and Post Accident Monitoring System Summary of Aging Management Evaluation Table 3.3.2-19 Process Sampling and Post Accident Monitoring System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Stainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Compressor Structural Integrity Carbon or Low Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Housing Alloy Steel with Uncontrolled (External)
Monitoring of Mechanical Stainless Steel Components (B.2.1.24)
Cladding Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Flow Device Pressure Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water Loss of Material One-Time Inspection VII.E4.AP-1 10 3.3.1-25 A, 1 (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-110 3.3.1-25 B, 1 Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-1 10 3.3.1-25 B LaSalle Countilftion, Units 1 and 2 License ReneW plication* Page 3.3-209 0 0 Section 3 -Aging Manageet Review Results Table 3.3.2-19 Process Sampling and Post Accident Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Flow Device Throttle Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water Loss of Material One-Time Inspection VII.E4.AP-1 10 3.3.1-25 A, 1 (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-1 10 3.3.1-25 B, 1 Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-1 10 3.3.1-25 B Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIDA-80 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Treated Water (internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 A Treated Water (Internal)
None None VII.J.AP-51 3.3.1-117 A Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A Water (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-210 Section 3 -Aging Management Review Results Table 3.3.2-19 Process Sampling and Post Accident Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Leakage Boundary Stainless Steel Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
VII.E4.AP-1 10 3.3.1-25 A Water Chemistry (B.2.1.2)VII.E4.AP-1 10 3.3.1-25 B t 4 -. .+ 4 Waste Water (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Comoonents (B.2.1.25)
VII.E5.AP-278 3.3.1-95 A F + F 4 '+ F 4 Pressure Boundary Glass Air -Indoor Uncontrolled (External)
None None VII.J.AP-14 3.3.1-117 A Air/Gas -Dry (Internal)
None None VII.J.AP-98 3.3.1-117 A Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 A Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 A Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water Loss of Material One-Time Inspection VII.E4.AP-1 10 3.3.1-25 A, 1 (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-110 3.3.1-25 B, 1 Treated Water (Internal)
Loss of Material One-Time Inspection (8.2.1.21)
Water Chemistry (B.2.1.2)VII.E4.AP-1 10 3.3.1-25 A+/- 4 VII.E4.AP-1 10 3.3.1-25 B Structural Integrity Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Condensation (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.F3.AP-99 3.3.1-94 C LaSalle Countvftion, Units 1 and 2 License Rene V plication.Page 3.3-211 0 0 Section 3 -Aging Management Review Results Table 3.3.2-19 Process Sampling and Post Accident Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A (H2/02 Sample Uncontrolled (External)
Pumps) Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A (HRSS Room Uncontrolled (External)
Sump Pump) Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A (HRSS Sample Uncontrolled (External)
Pump) Waste Water (Internal)
Loss of Material Inspection of Internal VIIE5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A (HRSS Waste Uncontrolled (External)
Pumps) Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Tanks (HRSS Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 C Waste Tank) Uncontrolled (External)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-212 Section 3 -Aging Management Review Results Table 3.3.2-19 Process Sampling and Post Accident Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Carbon Steel Air -Indoor Uncontrolled (External)
Loss of Material External Surfaces Monitoring of Mechanical Components (B.2.1.24)
VII.D.A-80 3.3.1-78 A Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 A Water (Internal)
Systems (B.2.1.13)
Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
VII.E4.AP-106 3.3.1-21 A.4 I. _______Water Chemistry (B.2.1.2)VII.E4.AP-106 3.3.1-21 B Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A 15% Zinc or More Uncontrolled (External)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-272 3.3.1-95 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Selective Leaching VII.E5.A-407 3.3.1-72 A (B.2.1.22)
Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 A Water (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-110 3.3.1-25 A (B.2.1.21)
I[Water Chemistry (B.2.1.2)
VII.E4.AP-1 10 3.3.1-25 B Waste Water (Internal)
Loss of Material Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
VII.E5.AP-278 3.3.1-95 A Pressure Boundary I Aluminum Alloy Air -Indoor Uncontrolled (External)
None None VII.J.AP-135 3.3.1-113 A LaSalle Count, tion, Units 1 and 2 License ReneWplication
.Page 3.3-213 0 Section 3 -Aging Manage*e eview Results Table 3.3.2-19 Process Sampling and Post Accident Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Aluminum Alloy Air/Gas -Dry (Internal)
None None VII.J.AP-37 3.3.1-113 A Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A 15% Zinc or More Uncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-9 3.3.1-114 A Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 A Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-1 10 3.3.1-25 B Structural Integrity Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 C Surfaces in Miscellaneous Piping and Ducting Components_(B.2.1.25)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-214 Section 3 -Aging Management Review Results Table 3.3.2-19 Process Sampling and Post Accident Monitoring System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. Components in the Treated Water (External) environment are associated with instrument sensing lines located below the normal water level in the suppression pool.LaSalle County on, Units 1 and 2 _ Page 3.3-215 License Rene, W ication Section 3 -Aging Manageleview Results Table 3.3.2-20 Radwaste System Summary of Aging Management Evaluation Table 3.3.2-20 Radwaste System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.1 1) VII.I.AP-124 3.3.1-15 A Bolting Stainless Steel Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Piping, piping Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 B Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 B Pump Casing Leakage Boundary Ductile Cast Iron Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Cleanup Phase Uncontrolled (External)
Monitoring of Mechanical Separator Sludge Components (B.2.1.24)
Pump) Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 A (8.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-216 Section 3 -Aging Management Review Results Table 3.3.2-20 Radwaste System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Tanks (RWCU Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 C Cleanup Phase Uncontrolled (External)
Separators)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 D Valve Body Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 B Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-110 3.3.1-25 B LaSalle Countvolon, Units 1 and 2 License Rene W plication.Page 3.3-217 0 0 Section 3 -Aging Management Review Results Table 3.3.2-20 Radwaste System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: None.LaSalle County Station, Units 1 and 2 Page 3.3-218 License Renewal Application Section 3 -Aging Management Review Results Table 3.3.2-21 Reactor Water Cleanup System Summary of Aging Management Evaluation Table 3.3.2-21 Reactor Water Cleanup System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Heat Exchanger-Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 C (Clean-Up Uncontrolled (External)
Regenerative Heat Treated Water > 140 F Cracking One-Time Inspection VII.E3.AP-120 3.3.1-19 A Exchangers)
Shell (Internal) (B.2.1.21)
Side Components Water Chemistry (B.2.1.2)
VII.E3.AP-120 3.3.1-19 B Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 D Heat Exchanger
-Leakage Boundary Carbon or Low Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Clean-Up Alloy Steel with Uncontrolled (External)
Monitoring of Mechanical Regenerative Heat Stainless Steel Components (B.2.1.24)
Exchangers)
Tube Cladding Treated Water > 140 F Cracking One-Time Inspection VII.E3.AP-120 3.3.1-19 A Side Components (Internal) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-120 3.3.1-19 B Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 D LaSalle CountY on, Units 1 and 2 License ReneW lication 0 Page 3.3-219 Section 3 -Aging Managemt Review Results Table 3.3.2-21 Reactor Water Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger-Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 C (Clean-Up Uncontrolled (External)
Regenerative Heat Treated Water > 140 F Cracking One-Time Inspection VII.E3.AP-120 3.3.1-19 A Exchangers)
Tube (Internal) (B.2.1.21)
Side Components Water Chemistry (B.2.1.2)
VII.E3.AP-120 3.3.1-19 B Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 D Heat Exchanger
-Leakage Boundary Carbon or Low Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Clean-up Non- Alloy Steel with Uncontrolled (External)
Monitoring of Mechanical Regenerative Heat Stainless Steel Components (B.2.1.24)
Exchanger)
Tube Cladding Treated Water > 140 F Cracking One-Time Inspection VII.E3.AP-112 3.3.1-20 A Side Components (Internal) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 12 3.3.1-20 B Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-110 3.3.1-25 D Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 C Uncontrolled (External)
Treated Water > 140 F Cracking One-Time Inspection VII.E3.AP-1 12 3.3.1-20 A ,(Internal) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 12 3.3.1-20 B Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 D LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-220 Section 3 -Aging Management Review Results Table 3.3.2-21 Reactor Water Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger
-Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (RWCU Pump Uncontrolled (External)
Monitoring of Mechanical Heat Exchanger)
Components (B.2.1.24)
Shell Side Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 C Components (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 D Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Treated Water (Internal)
Cumulative Fatigue TLAA V.D2.E-10 3.2.1-1 A, 1 Damage Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 B Wall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 A Corrosion (B.2.1.10)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Treated Water (Internal)
None None VII.J.AP-51 3.3,1-117 A Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 1 Damage Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 B Treated Water > 140 F Cracking One-Time Inspection VII.E3.AP-120 3.3.1-19 C (Internal) (B.2.1.21)
I Water Chemistry (B.2.1.2)
VII.E3.AP-120 3.3.1-19 D LaSalle Count. tion, Units 1 and 2 License ReneWplication 0 Page 3.3-221 Section 3 -Aging Managem eview Results Table 3.3.2-21 Reactor Water Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Piping, piping Leakage Boundary Stainless Steel Treated Water > 140 F Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 1 components, and (Internal)
Damage piping elements Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 B Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Cumulative Fatigue TLAA V.D2.E-10 3.2.1-1 A, 1 Damage Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 B Wall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 A Corrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 B Pump Casing Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Clean-Up Filter Uncontrolled (External)
Monitoring of Mechanical Demineralizer Components (B.2.1.24)
Holding Pump) Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 B Pump Casing Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Clean-Up Filter Uncontrolled (External)
Monitoring of Mechanical Demineralizer Components (B.2.1.24)
Precoat Pump)LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-222 Section 3 -Aging Management Review Results Table 3.3.2-21 Reactor Water Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Pump Casing Leakage Boundary Carbon Steel Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 A (Clean-Up Filter (B.2.1.21)
Demineralizer Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 B Precoat Pump)Pump Casing Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A (Reactor Water Uncontrolled (External)
Monitoring of Mechanical Clean-Up Components (B.2.1.24)
Recirculation Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 A Pump) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 B Tanks (Clean-Up Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Filter Demineralizer Uncontrolled (External)
Monitoring of Mechanical Precoat Tank) Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 D Tanks (Clean-Up Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Filter Uncontrolled (External)
Monitoring of Mechanical Demineralizer)
Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 D Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 B Wall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 A Corrosion (B.2.1.10)
LaSalle Countyglion, Units 1 and 2 License ReneW plication.Page 3.3-223 0 Section 3 -Aging Managemt Review Results Table 3.3.2-21 Reactor Water Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 B Treated Water > 140 F Cracking One-Time Inspection VII.E3.AP-120 3.3.1-19 C (Internal) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-120 3.3.1-19 D Loss of Material One-Time Inspection VII.E3.AP-110 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 10 3.3.1-25 B Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 B Wall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 A Corrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E3.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-110 3.3.1-25 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-224 Section 3 -Aging Management Review Results Table 3.3.2-21 Reactor Water Cleanup System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.LaSalle County. on, Units 1 and 2 Page 3.3-225 License Rene yPlication 1 0 Section 3 -Aging Managem 9 Review Results Table 3.3.2-22 Safety-Related Ventilation System Summary of Aging Management Evaluation Table 3.3.2-22 Safety-Related Ventilation System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 C Uncontrolled (External)
Ducting and Leakage Boundary Stainless Steel Condensation Loss of Material Inspection of Internal VII.F2.AP-99 3.3.1-94 A, 1 Components (External)
Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pressure Boundary Aluminum Alloy Air -Indoor None None VII.J.AP-135 3.3.1-113 C Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F2.AP-142 3.3.1-92 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Carbon Steel Air -Indoor Loss of Material External Surfaces VII.F2.A-10 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F2.A-08 3.3.1-90 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Elastomers Air- Indoor Hardening and Loss of External Surfaces VII.F2.AP-102 3.3.1-76 A Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-226 Section 3 -Aging Management Review Results Table 3.3.2-22 Safety-Related Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Ducting and Pressure Boundary Elastomers Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 2 Components Strength Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 C Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F4.A-08 3.3.1-90 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 C Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F2.AP-99 3.3.1-94 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Flexible Pressure Boundary Elastomers Air -Indoor Hardening and Loss of External Surfaces VII.F2.AP-102 3.3.1-76 A Connection Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.F2.AP-113 3.3.1-82 A Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 2 Strength Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Loss of Material Inspection of Internal G, 2 Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Heat Exchanger
-Heat Transfer Aluminum Alloy Condensation Reduction of Heat Inspection of Internal G, 3 (CSCS Equipment (External)
Transfer Surfaces in Miscellaneous Area Cubicle Piping and Ducting Coolers) Fins Components (B.2.1 .25)LaSalle Countymon, Units 1 and 2 License Rene W lication.Page 3.3-227 0 Section 3 -Aging Manager~eeview Results Table 3.3.2-22 Safety-Related Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Heat Exchanger-Pressure Boundary Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 C (CSCS Equipment Uncontrolled (External)
Area Cubicle Condensation (Internal)
Loss of Material Inspection of Internal VII.F4.A-08 3.3.1-90 C Coolers) Shell Side Surfaces in Miscellaneous Components Piping and Ducting Components (B.2.1.25)
Heat Exchanger
-Heat Transfer Copper Alloy with Condensation Reduction of Heat Inspection of Internal G, 3 (CSCS Equipment less than 15% (External)
Transfer Surfaces in Miscellaneous Area Cubicle Zinc Piping and Ducting Coolers) Tubes Components (B.2.1.25)
Pressure Boundary Copper Alloy with Condensation Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 C, 4 less than 15% (External)
Surfaces in Miscellaneous Zinc Piping and Ducting Components (B.2.1.25)
Piping, piping Pressure Boundary Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A components, and less than 15% Uncontrolled (External) piping elements Zinc Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Valve Body Pressure Boundary Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A 15% Zinc or More Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-228 Section 3 -Aging Management Review Results Table 3.3.2-22 Safety-Related Ventilation System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. This component is located internal to the ventilation ductwork, and therefore the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the applicable aging effects.2. The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the aging effect(s)applicable to this component type, material, and environment combination.
: 3. The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the reduction of heat transfer aging effect applicable to this component type, material, and environment combination.
The component is located within HVAC ducting and components, and the external surfaces of this component are subject to the internal HVAC environment of condensation during normal operation.
The Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program performs visual inspections which are capable of identifying aging mechanisms which cause reduction of heat transfer.4. This component is located internal to a heat exchanger, and therefore the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program is used to manage the applicable aging effects.LaSalle Count) on, units 1 and 2 Page 3.3-229 License ReneW lication 0 Section 3 -Aging Management Review Results Table 3.3.2-23 Standby Liquid Control System Summary of Aging Management Evaluation Table 3.3.2-23 Standby Liquid Control System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Stainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.L.AP-125 3.3.1-12 A Bolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Piping, piping Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A 15% Zinc or More Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Cracking One-Time Inspection H, 2 (B.2.1.21)
Water Chemistry (B.2.1.2)
H, 2 Loss of Material One-Time Inspection VII.E4.AP-140 3.3.1-22 A (B.2.1.21)
_Water Chemistry (B.2.1.2)
VII.E4.AP-140 3.3.1-22 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-230 Section 3 -Aging Management Review Results Table 3.3.2-23 Standby Liquid Control System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1 801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Leakage Boundary Copper Alloy with 15% Zinc or More Treated Water (Internal)
Loss of Material Selective Leaching (B.2.1.22)
VII. E4.AP-32 3.3.1-72 A Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 A Uncontrolled (External)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 A Sodium Pentaborate None None G, 1 Solution (Internal)
Treated Water (Internal)i None None VII.J.AP-51 3.3.1-117 A Stainless Steel Air- Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Sodium Pentaborate Loss of Material One-Time Inspection VII.E2.AP-141 3.3.1-25 A Solution (Internal) (B.2.1.21)
_Water Chemistry (B.2.1.2)
VII.E2.AP-141 3.3.1-25 B Treated Water (Internal)l Loss of Material One-Time Inspection (B.2.1.21)
VII.A4.AP-1 10 3.3.1-25 A Water Chemistry (B.2.1.2)VII.A4.AP-1 10 3.3.1-25 B Pressure Boundary I Stainless Steel Air -Indoor Uncontrolled (External)
None None VII.J.AP-17 3.3.1-120 A Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Sodium Pentaborate Loss of Material One-Time Inspection VII.E2.AP-141 3.3.1-25 A Solution (Internal) (B.2.1.21)
_Water Chemistry (B.2.1.2)
VII.E2.AP-141 3.3.1-25 B Treated Water (Internal)
Loss of Material One-Time Inspection (B.2.1.21)
VII.A4.AP-1 10 3.3.1-25 A LaSalle CountwiLion, Units 1 and 2 License Rene plication.Page 3.3-231 0 0 Section 3 -Aging Management Review Results Table 3.3.2-23 Standby Liquid Control System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Stainless Steel Treated Water (Internal)
Loss of Material Water Chemistry (B.2.1.2)
VII.A4.AP-1 10 3.3.1-25 B components, and Structural Integrity Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 A piping elements Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.A-23 3.3.1-89 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Pump Casing (SLC Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Pump) Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.A4.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A4.AP-1 10 3.3.1-25 B Tanks (SLC Pressure Boundary Stainless Steel Air- Indoor None None VII.JAP-17 3.3.1-120 A Solution Tank) Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 C Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Sodium Pentaborate Loss of Material One-Time Inspection VII.E2.AP-141 3.3.1-25 C Solution (Internal) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E2.AP-141 3.3.1-25 D Tanks (SLC Test Leakage Boundary Stainless Steel Air -Indoor None None VlI.JAP-17 3.3.1-120 C Tank) Uncontrolled (External)
_ _I LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-232 Section 3 -Aging Management Review Results Table 3.3.2-23 Standby Liquid Control System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Tanks (SLC Test Leakage Boundary Stainless Steel Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 C Tank) Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.A4.AP-1 10 3.3.1-25 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A4.AP-1 10 3.3.1-25 D Valve Body Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.A4.AP-1 10 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A4.AP-1 10 3.3.1-25 B Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Sodium Pentaborate Loss of Material One-Time Inspection VII.E2.AP-141 3.3.1-25 A Solution (Internal) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E2.AP-141 3.3.1-25 B Treated Water (Internal)
Loss of Material One-Time Inspection VII.A4.AP-110 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A4.AP-1 10 3.3.1-25 B Structural Integrity Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
I I LaSalle Countvlion, Units 1 and 2 License ReneW plication.Page 3.3-233 Section 3 -Aging Management Review Results Table 3.3.2-23 Standby Liquid Control System (Continued)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-234 Section 3 -Aging Management Review Results Table 3.3.2-23 Standby Liquid Control System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1 801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. Glass in a sodium pentaborate solution environment has no applicable aging effects requiring management.
: 2. The aging effects for copper alloy with 15% zinc or more in a treated water environment include cracking.
The One-Time Inspection (B.2.1.21) program and Water Chemistry (B.2.1.2) program are used to manage cracking for copper alloy with 15% zinc or more in a treated water environment.
LaSalle CountVAjion, Units 1 and 2 _ Page 3.3-235 License Rene V plication Section 3 -Aging Manageme*Review Results Table 3.3.2-24 Suppression Pool Cleanup System Summary of Aging Management Evaluation Table 3.3.2-24 Suppression Pool Cleanup System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 A Bolting Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-110 3.3.1-25 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-1 10 3.3.1-25 B Pump Casing Leakage Boundary Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A (Suppression Pool Uncontrolled (External)
Monitoring of Mechanical Cleanup Pump) Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B Selective Leaching VII.E4.AP-31 3.3.1-72 A (B.2.1.22)
Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 A Uncontrolled (External)
Monitoring of Mechanical
'I_ I _ Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-236 Section 3 -Aging Management Review Results Table 3.3.2-24 Suppression Pool Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Carbon Steel Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-106 3.3.1-21 A (B.2.1.21)
_Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21 B LaSalle CountYdlion, Units 1 and 2 License Rene V P lication O Page 3.3-237 0 0 Section 3 -Aging ManagemeReview Results Table 3.3.2-24 Suppression Pool Cleanup System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: None.LaSalle County Station, Units 1 and 2 Page 3.3-238 License Renewal Application Section 3 -Aging Management Review Results Table 3.3.2-25 Traversing Incore Probe System Summary of Aging Management Evaluation Table 3.3.2-25 Traversing Incore Probe System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 A components, and Uncontrolled (External) piping elements Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 B Monitoring (B.2.1.15)
Valve Body Pressure Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 A Uncontrolled (External)
Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 B Monitoring (B.2.1.15)
LaSalle Countyd~on, Units 1 and 2 License Rene1W lication 0 Page 3.3-239 Section 3 -Aging ManagemOReview Results Table 3.3.2-25 Traversing Incore Probe System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: None.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.3-240 This Page Intentionally Left Blank
 
0 Section 3 -Aging Management Review Results 3.4 AGING MANAGEMENT OF STEAM AND POWER CONVERSION SYSTEM 3.
 
==4.1 INTRODUCTION==
 
This section provides the results of the aging management review for those components identified in Section 2.3.4, Steam and Power Conversion System, as being subject to aging management review. The systems, or portions of systems, which are addressed in this section are described in the indicated sections.* Condensate System (2.3.4.1)* Condenser and Air Removal System (2.3.4.2)* Feedwater System (2.3.4.3)" Main Steam System (2.3.4.4)* Main Turbine and Auxiliaries System (2.3.4.5)3.4.2 RESULTS The following tables summarize the results of the aging management review for Steam and Power Conversion System.Table 3.4.2-1 Condensate System -Summary of Aging Management Evaluation Table 3.4.2-2 Condenser and Air Removal System -Summary of Aging Management Evaluation Table 3.4.2-3 Feedwater System -Summary of Aging Management Evaluation Table 3.4.2-4 Main Steam System -Summary of Aging Management Evaluation Table 3.4.2-5 Main Turbine and Auxiliaries System -Summary of Aging Management Evaluation 3.4.2.1 Materials, Environments, Aging Effects Requiring Management And Aging Management Programs 3.4.2.1.1 Condensate System Materials The materials of construction for the Condensate System components are:* Aluminum Alloy" Carbon Steel" Carbon and Low Alloy Steel Bolting* Copper Alloy with less than 15% Zinc* Stainless Steel LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-1 Section 3 -Aging Management Review Results Environments The Condensate System components are exposed to the following environments:
* Air -Indoor Uncontrolled" Air -Outdoor* Concrete" Condensation
* Soil" Treated Water Aging Effects Requiring Management The following aging effects associated with the Condensate System components require management:
* Cracking* Loss of Material* Loss of Preload Aging Management Programs The following aging management programs manage the aging effects for the Condensate System components:
* Aboveground Metallic Tanks (B.2.1.18)
* Bolting Integrity (B.2.1.11)
* Buried and Underground Piping (B.2.1.28)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* One-Time Inspection (B.2.1.21)
* Water Chemistry (B.2.1.2)3.4.2.1.2 Condenser and Air Removal System Materials The materials of construction for the Condenser and Air Removal System components are:* Carbon Steel" Carbon and Low Alloy Steel Bolting* Stainless Steel LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-2 Section 3 -Aging Management Review Results Environments The Condenser and Air Removal System components are exposed to the following environments: " Air -Indoor Uncontrolled
* Treated Water Aging Effects Requiring Management The following aging effects associated with the Condenser and Air Removal System components require management: " Cumulative Fatigue Damage* Loss of Material* Loss of Preload" Wall Thinning Aging Management Programs The following aging management programs manage the aging effects for the Condenser and Air Removal System components:
* Bolting Integrity (B.2.1.11)" External Surfaces Monitoring of Mechanical Components (B.2.1.24)" Flow-Accelerated Corrosion (B.2.1.10)
* One-Time Inspection (B.2.1.21)" TLAA* Water Chemistry (B.2.1.2)3.4.2.1.3 Feedwater System Materials The materials of construction for the Feedwater System components are:* Carbon Steel* Carbon and Low Alloy Steel Bolting" Stainless Steel Environments The Feedwater System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Treated Water* Treated Water > 140 F LaSalle County Station, Units 1 and 2 Page 3.4-3 License Renewal Application Section 3 -Aging Management Review Results Aging Effects Requiring Management The following aging effects associated with the Feedwater System components require management:
* Cracking" Cumulative Fatigue Damage" Loss of Material* Loss of Preload* Wall Thinning Aging Management Programs The following aging management programs manage the aging effects for the Feedwater System components: " Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Flow-Accelerated Corrosion (B.2.1.10)" One-Time Inspection (B.2.1.21)
* TLAA" Water Chemistry (B.2.1.2)3.4.2.1.4 Main Steam System Materials The materials of construction for the Main Steam System components are: " Carbon Steel" Carbon and Low Alloy Steel Bolting* Stainless Steel Environments The Main Steam System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Condensation
* Steam* Treated Water" Treated Water > 140 F LaSalle County Station, Units 1 and 2 Page 3.4-4 License Renewal Application Section 3 -Aging Management Review Results Aging Effects Requiring Management The following aging effects associated with the Main Steam System components require management:
* Cracking* Cumulative Fatigue Damage* Loss of Material" Loss of Preload* Wall Thinning Aging Management Programs The following aging management programs manage the aging effects for the Main Steam System components:
* Bolting Integrity (B.2.1.11)
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Flow-Accelerated Corrosion (B.2.1.10)
* Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
* One-Time Inspection (B.2.1.21)" TLAA* Water Chemistry (B.2.1.2)3.4.2.1.5 Main Turbine and Auxiliaries System Materials The materials of construction for the Main Turbine and Auxiliaries System components are:* Carbon Steel Environments The Main Turbine and Auxiliaries System components are exposed to the following environments:
* Air -Indoor Uncontrolled
* Treated Water Aging Effects Requiring Management The following aging effects associated with the Main Turbine and Auxiliaries System components require management:
* Loss of Material LaSalle County Station, Units 1 and 2 Page 3.4-5 License Renewal Application Section 3 -Aging Management Review Results* Wall Thinning Aging Management Programs The following aging management programs manage the aging effects for the Main Turbine and Auxiliaries System components:
* External Surfaces Monitoring of Mechanical Components (B.2.1.24)
* Flow-Accelerated Corrosion (B.2. 1.10)* One-Time Inspection (B.2.1.21)
* Water Chemistry (B.2.1.2)3.4.2.2 AMR Results for Which Further Evaluation is Recommended by the GALL Report NUREG-1 801 provides the basis for identifying those programs that warrant further evaluation by the reviewer in the license renewal application.
For the Steam and Power Conversion System, those programs are addressed in the following subsections.
3.4.2.2.1 Cumulative Fatigue Damage Fatigue is a time-limited aging analysis (TLAA) as defined in 10 CFR 54.3. TLAAs are required to be evaluated in accordance with 10 CFR 54.21(c).
The evaluation of metal fatigue as a TLAA for the Condenser and Air Removal System, Feedwater System, Main Steam System, and Reactor Coolant Pressure Boundary System is discussed in Section 4.3.3.4.2.2.2 Cracking due to Stress Corrosion Cracking (SCC)Cracking due to stress corrosion cracking could occur for stainless steel piping, piping components, piping elements, and tanks exposed to outdoor air. The possibility of cracking also extends to components exposed to air which has recently been introduced into buildings, i.e., components near intake vents. Cracking is only known to occur in environments containing sufficient halides (primarily chlorides) and in which condensation or deliquescence is possible.
Condensation or deliquescence should generally be assumed to be possible.
Applicable outdoor air environments (and associated indoor air environments) include, but are not limited to, those within approximately 5 miles of a saltwater coastline, those within 1/2 mile of a highway which is treated with salt in the wintertime, those areas in which the soil contains more than trace chlorides, those plants having cooling towers where the water is treated with chlorine or chlorine compounds, and those areas subject to chloride contamination from other agricultural or industrial sources. This item is applicable for the environments described above.GALL AMP Xl. M36, "External Surfaces Monitoring, "is an acceptable method to manage the aging effect. The applicant may demonstrate that this item is not applicable by describing the outdoor air environment present at the plant and demonstrating that external chloride stress corrosion cracking is not expected.
The GALL Report recommends further evaluation to determine whether an adequate aging management program is used to manage this aging effect based on the environmental conditions LaSalle County Station, Units 1 and 2 Page 3.4-6 License Renewal Application Section 3 -Aging Management Review Results applicable to the plant and ASME Code Section X1 requirements applicable to the components.
LSCS will implement the External Surfaces Monitoring of Mechanical Components (B.2.1.24) program to manage cracking due to stress corrosion cracking in stainless steel piping, piping components, and piping elements exposed to an outdoor air environment in the Condensate System. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program provides for management of aging effects through periodic inspection of external surfaces for evidence of cracking.
Visual inspection activities will be performed by qualified personnel in accordance with site controlled procedures and processes.
Any visible evidence of cracking will be evaluated for acceptability of continued service. Deficiencies will be documented in accordance with the 10 CFR Part 50, Appendix B Corrective Action Program. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program is described in Appendix B.3.4.2.2.3 Loss of Material due to Pitting and Crevice Corrosion Loss of material due to pitting and crevice corrosion could occur for stainless steel piping, piping components, piping elements, and tanks exposed to outdoor air. The possibility of pitting and crevice corrosion also extends to components exposed to air which has recently been introduced into buildings, i.e., components near intake vents.Pitting and crevice corrosion is only known to occur in environments containing sufficient halides (primarily chlorides) and in which condensation or deliquescence is possible.Condensation or deliquescence should generally be assumed to be possible.
Applicable outdoor air environments (and associated indoor air environments) include, but are not limited to, those within approximately 5 miles of a saltwater coastline, those within 1/2 mile of a highway which is treated with salt in the wintertime, those areas in which the soil contains more than trace chlorides, those plants having cooling towers where the water is treated with chlorine or chlorine compounds, and those areas subject to chloride contamination from other agricultural or industrial sources. This item is applicable for the environments described above.GALL AMP X1. M36, "External Surfaces Monitoring," is an acceptable method to manage the aging effect. The applicant may demonstrate that this item is not applicable by describing the outdoor air environment present at the plant and demonstrating that external pitting or crevice corrosion is not expected.
The GALL Report recommends further evaluation to determine whether an adequate aging management program is used to manage this aging effect based on the environmental conditions applicable to the plant and ASME Code Section X1 requirements Quality Assurance for Aging Management of Nonsafety-Related Components.
LSCS will implement the External Surfaces Monitoring of Mechanical Components (B.2.1.24) program to manage the loss of material in stainless steel piping, piping components, and piping elements exposed to an outdoor air environment in the Condensate System. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program provides for management of aging effects through periodic visual inspection of external surfaces for evidence of loss of material.
Visual inspection activities will be performed by qualified personnel in accordance with site controlled procedures and processes.
Any visible evidence of loss of material will be evaluated for LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-7 Section 3 -Aging Management Review Results acceptability of continued service. Deficiencies will be documented in accordance with 10 CFR Part 50, Appendix B corrective Action Program. The External surfaces Monitoring of Mechanical Components (B.2.1.24) program is described in Appendix B.3.4.2.2.4 Quality Assurance for Aging Management of Nonsafety-Related Components QA provisions applicable to License Renewal are discussed in Section 8.1.3.3.4.2.2.5 Ongoing Review of Operating Experience Ongoing review of operating experience is addressed in Appendix A, Section A. 1.6 and Appendix B, Section B.1.4.3.4.2.2.6 Loss of Material due to Recurring Internal Corrosion Recurring internal corrosion can result in the need to augment AMPs beyond the recommendations in the GALL Report. During the search of plant-specific OE conducted during the LRA development, recurring internal corrosion can be identified by the number of occurrences of aging effects and the extent of degradation at each localized corrosion site. This further evaluation item is applicable if the search of plant-specific OE reveals repetitive occurrences (e.g., one per refueling outage cycle that has occurred over: (a)three or more sequential or nonsequential cycles for a 10-year OE search, or (b) two or more sequential or nonsequential cycles for a 5-year OE search) of aging effects with the same aging mechanism in which the aging effect resulted in the component either not meeting plant-specific acceptance criteria or experiencing a reduction in wall thickness greater than 50 percent (regardless of the minimum wall thickness.)
The GALL Report recommends that a plant-specific AMP, or a new or existing AMP, be evaluated for inclusion of augmented requirements to ensure the adequate management of any recurring aging effect(s).
Potential augmented requirements include: alternative examination methods (e.g., volumetric versus external visual), augmented inspections (e.g., a greater number of locations, additional locations based on risk insights based on susceptibility to aging effect and consequences of failure, a greater frequency of inspections), and additional trending parameters and decision points where increased inspections would be implemented.
Acceptance criteria are described in Appendix A. 1,"Aging Management Review -Generic (Branch Technical Position RSLB-1)." The applicant states: (a) why the program's examination methods will be sufficient to detect the recurring aging effect before affecting the ability of a component to perform its intended function, (b) the basis for the adequacy of augmented or lack of augmented inspections, (c) what parameters will be trended as well as the decision points where increased inspections would be implemented (e.g., the extent of degradation at individual corrosion sites, the rate of degradation change), (d) how inspections of components that are not easily accessed (i.e., buried, underground) will be conducted, and (e) how leaks in any involved buried or underground components will be identified.
Each plant-specific operating experience example should be evaluated to determine if the chosen AMP should be augmented even if the thresholds for significance of aging effect or frequency of occurrence of aging effect have not been exceeded.
For example, during a 10-year search of plant specific operating experience, two instances of 360 LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-8 Section 3 -Aging Management Review Results degree 30 percent wall loss occurred at copper alloy to steel joints. Neither the significance of the aging effect nor the frequency of occurrence of aging effect threshold has been exceeded.
Nevertheless, the operating experience should be evaluated to determine if the AMP that is proposed to manage the aging effect is sufficient (e.g., method of inspection, frequency of inspection, number of inspections) to provide reasonable assurance that the CLB intended functions of the component will be met throughout the period of extended operation.
Likewise, the GALL Report AMR items associated with the new FE items only cite raw water and waste water environments because OE indicates that these are the predominant environments associated with recurring internal corrosion; however, if the search of plant-specific OE reveals recurring internal corrosion in other water environments (e.g., treated water), the aging effect should be addressed in a similar manner.LR-ISG-2012-02 has been issued which addresses instances of recurring internal corrosion identified during review of plant-specific operating experience.
The operating experience for LSCS has been reviewed and instances of internal corrosion in the Steam and Power Conversion System have not been identified with a frequency that is consistent with the thresholds discussed in LR-ISG-2012-02.
3.4.2.3 Time-Limited Aging Analysis The time-limited aging analyses identified below are associated with the Steam and Power Conversion System components:
Section 4.3, Metal Fatigue Analyses* Section 4.3.2, ASME Section III, Class 2 and 3 and ANSI B31.1 Allowable Stress Analyses* Section 4.3.5, High-Energy Line Break (HELB) Analysis Based on Fatigue" Section 4.3.6, Main Steam Relief Valve Discharge Piping Fatigue Analyses LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-9 Section 3 -Aging Management Review Results 3.
 
==4.3 CONCLUSION==
 
The Steam and Power Conversion System piping, fittings, and components that are subject to aging management review have been identified in accordance with the requirements of 10 CFR 54.4. The aging management programs selected to manage aging effects for the Steam and Power Conversion System components are identified in the summaries in Section 3.4.2.1 above.A description of these aging management programs is provided in Appendix B, along with the demonstration that the identified aging effects will be managed for the period of extended operation.
Therefore, based on the conclusions provided in Appendix B, the effects of aging associated with the Steam and Power Conversion System components will be adequately managed so that there is reasonable assurance that the intended functions are maintained consistent with the current licensing basis during the period of extended operation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-10 O O Section 3 -Aging Managemeneview Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-1 Steel Piping, piping Cumulative fatigue Fatigue is a time-limited Yes, TLAA Fatigue is a TLAA; further evaluation is components, and piping damage aging analysis (TLAA) to documented in Subsection 3.4.2.2.1.
elements exposed to due to fatigue be evaluated for the Steam or Treated water period of extended operation.
See the SRP, Section 4.3 "Metal Fatigue," for acceptable methods for meeting the requirements of 10 CFR 54.21 (c)(1).3.4.1-2 Stainless steel Piping, Cracking Chapter XI.M36, Yes, environmental Consistent with NUREG-1801.
The piping components, and due to stress "External Surfaces conditions need to External Surfaces Monitoring of Mechanical piping elements; tanks corrosion cracking Monitoring of Mechanical be evaluated Components (B.2.1.24) program will be exposed to Air -outdoor Components" used to manage cracking of the stainless steel piping, piping components, and piping elements exposed to air -outdoor in the Condensate System.See Subsection 3.4.2.2.2.
3.4.1-3 Stainless steel Piping, Loss of material Chapter XL.M36, Yes, environmental Consistent with NUREG-1801.
The piping components, and due to pitting and "External Surfaces conditions need to External Surfaces Monitoring of Mechanical piping elements; tanks crevice corrosion Monitoring of Mechanical be evaluated Components (B.2.1.24) program will be exposed to Air -outdoor Components" used to manage loss of material of the stainless steel piping, piping components, and piping elements exposed to air -outdoor in the Condensate System.See subsection 3.4.2.2.3.
3.4.1-4 PWR Only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-11 Section 3 -Aging Management Review Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-5 Steel Piping, piping Wall thinning Chapter XI.M17, "Flow- No Consistent with NUREG-1801.
The Flow-components, and piping due to flow- Accelerated Corrosion" Accelerated Corrosion (B.2.1.10) program elements exposed to accelerated corrosion will be used to manage wall thinning of the Steam, Treated water carbon steel piping, piping components, and piping elements, and turbine casings exposed to steam and treated water in the Condenser and Air Removal System, Feedwater System, Main Steam System, and Main Turbine and Auxiliaries System.3.4.1-6 Steel, Stainless Steel Loss of preload Chapter XI.M18, "Bolting No Not Applicable.
Bolting exposed to Soil Integrity" There are no steel or stainless steel bolting exposed to soil in the Steam and Power Conversion System.3.4.1-7 High-strength steel Cracking Chapter XI.M18, "Bolting No Not Applicable.
Closure bolting exposed due to cyclic loading, Integrity" There are no high strength steel closure to Air with steam or water stress corrosion th e xpose to ai r with steam or e leakae crakingbolting exposed to air with steam or water leakage cracking leakage in the Steam and Power Conversion System.3.4.1-8 Steel; stainless steel Loss of material Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Bolting Bolting, Closure bolting due to general (steel Integrity" Integrity (B.2.1.11) program will be used to exposed to Air -outdoor only), pitting, and manage loss of material of the carbon and (External), Air -indoor, crevice corrosion low alloy steel bolting exposed to air -uncontrolled (External) indoor uncontrolled and air -outdoor in the Condensate System, Condenser and Air Removal System, Feedwater System, and Main Steam System.LaSalle County Station, Units 1 and 2 License Renewal Application 0 Page 3.4-12 Section 3 -Aging Managemen:eview Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-9 Steel Closure bolting Loss of material Chapter XI.M18, "Bolting No Not Applicable.
exposed to Air with due to general Integrity" steam or water leakage corrosion There is no steel closure bolting exposed to air with steam or water leakage in the Steam and Power Conversion System.3.4.1-10 Copper alloy, Nickel Loss of preload Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Bolting alloy, Steel; stainless due to thermal Integrity" Integrity (B.2.1.11) program will be used to steel, Steel; stainless effects, gasket creep, manage loss of preload of the carbon and steel Bolting, Closure and self-loosening low alloy steel bolting exposed to air -bolting exposed to Any indoor uncontrolled and air -outdoor in the environment, Air -Condensate System, Condenser and Air outdoor (External), Air- Removal System, Feedwater System, and indoor, uncontrolled Main Steam System.(External) 3.4.1-11 Stainless steel Piping, Cracking Chapter XI.M2, 'Water No Consistent with NUREG-1801 with piping components, and due to stress Chemistry," and exceptions.
The One-Time Inspection piping elements, Tanks, corrosion cracking Chapter XI.M32, "One- (B.2.1.21) program and Water Chemistry Heat exchanger Time Inspection" (B.2.1.2) program will be used to manage components exposed to cracking of the stainless steel piping, piping Steam, Treated water components, and piping elements exposed>601C (>140&deg;F) to steam and treated water > 140 F in the Feedwater System, Main Steam System, and Reactor Coolant Pressure Boundary System.An exception applies to the NUREG-1801 recommendations for the Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-13 Section 3 -Aging Management Review Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-12 Steel; stainless steel Loss of material Chapter XI.M2, 'Water No Consistent with NUREG-1801 with Tanks exposed to due to general (steel Chemistry," and exceptions.
The One-Time Inspection Treated water only), pitting, and Chapter XI.M32, "One- (B.2.1.21) program and Water Chemistry crevice corrosion Time Inspection" (B.2.1.2) program will be used to manage loss of material of the carbon steel tanks exposed to treated water in the Condensate System.An exception applies to the NUREG-1801 recommendations for the Water Chemistry (B.2.1.2) program implementation.
3.4.1-13 PWR Only 3.4.1-14 Steel Piping, piping Loss of material Chapter XI.M2, 'Water No Consistent with NUREG-1801 with components, and piping due to general, Chemistry," and exceptions.
The One-Time Inspection elements, PWR heat pitting, and crevice Chapter XI.M32, "One- (B.2.1.21) program and Water Chemistry exchanger components corrosion Time Inspection" (B.2.1.2) program will be used to manage exposed to Steam, loss of material of the carbon steel piping, Treated water piping components, and piping elements and turbine casings exposed to steam and treated water in the Condensate System, Condenser and Air Removal System, Feedwater System, Main Steam System, Main Turbine and Auxiliaries System, Reactor Coolant Pressure Boundary System, and Reactor Core Isolation Cooling System.An exception applies to the NUREG-1 801 recommendations for the Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application 0 Page 3.4-14 0 0 Section 3-Aging Managementiew Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Component Aging Aging Management Further Discussion Effect/Mechanism Programs Evaluation Recommended Steel Heat exchanger components exposed to Treated water Loss of material due to general, pitting, crevice, and galvanic corrosion Chapter XI.M2, "Water Chemistry," and Chapter XI.M32, "One-Time Inspection" No Consistent with NUREG-1801 with exceptions.
The One-Time Inspection (B.2.1.21) program and Water Chemistry (B.2.1.2) program will be used to manage loss of material of the carbon steel heat exchanger components and piping, piping components, and piping elements exposed to treated water in the Condenser and Air Removal System and Demineralized Water Makeup System.An exception applies to the NUREG-1 801 recommendations for the Water Chemistry (B.2.1.2) program implementation.
+ i I I 3.4.1-16 Copper alloy, Stainless steel, Nickel alloy, Aluminum Piping, piping components, and piping elements, Heat exchanger components and tubes, PWR heat exchanger components exposed to Treated water, Steam Loss of material due to pitting and crevice corrosion Chapter XI.M2, 'Water Chemistry," and Chapter XI.M32, "One-Time Inspection" No Consistent with NUREG-1801 with exceptions.
The One-Time Inspection (B.2.1.21) program and Water Chemistry (B.2.1.2) program will be used to manage loss of material of the aluminum alloy, copper alloy, and stainless steel heat exchanger components and piping, piping components, and piping elements exposed to steam and treated water in the Condensate System, Condenser and Air Removal System, Demineralized Water Makeup System, Feedwater System, Low Pressure Core Spray System, Main Steam System, Reactor Coolant Pressure Boundary System , and Reactor Core Isolation Cooling System.An exception applies to the NUREG-1 801 recommendations for the Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-15 Section 3 -Aging Management Review Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-17 PWR Only 3.4.1-18 Copper alloy, Stainless Reduction of heat Chapter XI.M2, "Water No Consistent with NUREG-1801 with steel Heat exchanger transfer Chemistry," and exceptions.
The One-Time Inspection tubes exposed to Treated due to fouling Chapter XI.M32, "One- (B.2.1.21) program and Water Chemistry water Time Inspection" (B.2.1.2) program will be used to manage reduction of heat transfer of the copper alloy heat exchanger tubes exposed to treated water in the Reactor Core Isolation Cooling System.An exception applies to the NUREG-1 801 recommendations for the Water Chemistry (B.2.1.2) program implementation.
3.4.1-19 Stainless steel, Steel Loss of material Chapter XI.M20, "Open- No Not Applicable.
Heat exchanger due to general, Cycle Cooling Water There are no stainless steel, steel heat components exposed to pitting, crevice, System" Th er compo ness se d t o raw Raw water galvanic, and exchanger components exposed to raw microbiologically-water in the Steam and Power Conversion influenced corrosion; System.fouling that leads to corrosion 3.4.1-20 Copper alloy, Stainless Loss of material Chapter XI.M20, "Open- No Not Applicable.
steel Piping, piping due to pitting, crevice, Cycle Cooling Water There are no copper alloy, stainless steel components, and piping and microbiologically-System" There piping copp e nts, a in g elements exposed to influenced corrosion piping, piping components, and piping Raw water elements exposed to raw water in the Steam and Power Conversion System.3.4.1-21 PWR Only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-16 0 Section 3 -Aging Managerne view Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-22 Stainless steel, Copper Reduction of heat Chapter XI.M20, "Open- No Not Applicable.
alloy, Steel Heat transfer Cycle Cooling Water exchanger tubes, Heat due to fouling System" There are no stainless steel, copper alloy, exchanger components steel heat exchanger tubes, and heat exposed to Raw water exchanger components exposed to raw water in the Steam and Power Conversion System.3.4.1-23 Stainless steel Piping, Cracking Chapter XI.M21A, No Not Applicable.
piping components, and due to stress "Closed Treated Water piping elements exposed corrosion cracking Systems" There are no stainless steel piping, piping to Closed-cycle cooling components, and piping elements exposed water >60&deg;C (>140cF) to closed-cycle cooling water >60 0 C (>140 0 F) in the Steam and Power Conversion System.3.4.1-24 Steel Heat exchanger Loss of material Chapter XI.M21A, No Not Applicable.
components exposed to due to general, "Closed Treated Water There are no steel heat exchanger Closed-cycle cooling pitting, crevice, and Systems" Therenarexposed t ex c le water galvanic corrosion components exposed to closed-cycle cooling water in the Steam and Power Conversion System.3.4.1-25 Steel Heat exchanger Loss of material Chapter XI.M21A, No Not Applicable.
components exposed to due to general, "Closed Treated Water There are no steel heat exchanger Closed-cycle cooling pitting, crevice, and Systems" Therenarexposed t ex c le water galvanic corrosion components exposed to closed-cycle cooling water in the Steam and Power Conversion System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-17 Section 3 -Aging Management Review Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-26 Stainless steel Heat Loss of material Chapter XI.M21A, No Not Applicable.
exchanger components, due to pitting and "Closed Treated Water Piping, piping crevice corrosion Systems" There are no stainless steel heat components, and piping exchanger components, piping, piping elements exposed to components, and piping elements exposed Closed-cycle cooling to closed-cycle cooling water in the Steam water and Power Conversion System.3.4.1-27 Copper alloy Piping, Loss of material Chapter XI.M21A, No Not Applicable.
piping components, and due to pitting, crevice, "Closed Treated Water There are no copper alloy piping, piping piping elements exposed and galvanic Systems" to Closed-cycle cooling corrosion components, and piping elements exposed water to closed-cycle cooling water in the Steam and Power Conversion System.3.4.1-28 Steel, Stainless steel, Reduction of heat Chapter XI.M21A, No Not Applicable.
Copper alloy Heat transfer "Closed Treated Water There are no steel, stainless steel, copper exchanger components due to fouling Systems" and tubes, Heat alloy heat exchanger components and exchanger tubes tubes, heat exchanger tubes exposed to exposed to Closed-cycle closed-cycle cooling water in the Steam cooling water and Power Conversion System.3.4.1-29 Steel Tanks exposed to Loss of material Chapter XI.M29, No Not Applicable.
Air- outdoor (External) due to general, "Aboveground Metallic pitting, and crevice Tanks" There are no steel tanks exposed to air-corrosion outdoor (external) in the Steam and Power Conversion System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-18 Section 3 -Aging Management wl e Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-30 Steel, Stainless Steel, Loss of material due Chapter XI.M29, No Not Applicable.
Aluminum Tanks (within to general, (steel "Aboveground Metallic the scope of Chapter only) pitting, and Tanks" There ate no steel or stainless steel tanks XI.M29, "Aboveground crevice corrosion; (within the scope of chapter X.M29, Metallic Tanks") exposed cracking due to stress "Aboveground Metallic Tanks") exposed to to Soil or Concrete, or the corrosion cracking soil or concrete, or the following external following external (stainless steel and environments of air-outdoor, air-indoor environments air-outdoor, aluminum only) uncontrolled, moist air, condensation in the air-indoor uncontrolled, Steam and Power Conversion System.moist air, condensation Aluminum tanks (within the scope of chapter XI.M29, "Aboveground Metallic Tanks) are evaluated in 3.4.1-31.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-19 Section 3 -Aging Management Review Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-31 Stainless steel, Loss of material due Chapter XI.M29, Yes-Plant-Specific Consistent with NUREG-1801.
The Aluminum Tanks (within to pitting, and crevice "Aboveground Metallic Aboveground Metallic Tanks (B.2.1.18) the scope of Chapter corrosion; cracking Tanks" program will be used to manage loss of XI.M29, "Aboveground due to stress material of the aluminum alloy tanks (cycled Metallic Tanks") exposed corrosion cracking condensate storage tank) exposed to air-to Soil or Concrete, or the outdoor, condensation, concrete, and soil in following external the Condensate System. The aging effect environments air-outdoor, of cracking due to stress corrosion cracking air-indoor uncontrolled, does not apply. Cracking in aluminum alloy moist air, condensation of these environments occurs when the aluminum alloy chemical composition includes greater than 12% zinc or greater than 6% magnesium (ref. EPRI Report 1010639, Non-Class 1 Mechanical Implementation Guideline and Mechanical Tools, Revision 4 dated January 2006).The cycled condensate storage tank is constructed of ASTM B209 alloy 5454 plates and ASTM B308 alloy 6061-T6 structural members. Both these alloys contain less than 12% zinc and less than 6% magnesium.
See 3.4.2.2.2 for further evaluation.
3.4.1-32 Gray cast iron Piping, Loss of material Chapter XI.M33, No Not Applicable.
piping components, and due to selective "Selective Leaching" There are no gray cast iron piping, piping piping elements exposed leaching components, and piping elements exposed to Soil to soil in the Steam and Power Conversion System.LaSalle County Station, Units 1 and 2 License Renewal Application 0 Page 3.4-20 Section 3 -Aging Management iew Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-33 Gray cast iron, Copper Loss of material Chapter XI.M33, No Not Applicable.
alloy (>15% Zn or >8% due to selective "Selective Leaching" There are no gray cast iron or copper alloy Al) Piping, piping leachingThrarnogacstinoropealy components, and piping piping, piping components or piping elements exposed to elements exposed to treated water or raw Treated water, Raw water in the Steam and Power Conversion water, Closed-cycle System.cooling water 3.4.1-34 Steel External surfaces Loss of material Chapter XI.M36, No Consistent with NUREG-1801.
The exposed to Air -indoor, due to general "External Surfaces External Surfaces Monitoring of Mechanical uncontrolled (External), corrosion Monitoring of Mechanical Components (B.2.1.24) program will be Air -outdoor (External), Components" used to manage loss of material of the Condensation (External) carbon steel heat exchanger components, piping, piping components, and piping elements, and tanks exposed to air -indoor uncontrolled and air -outdoor in the Condensate System, Condenser and Air Removal System, Feedwater System, Main Steam System, and Main Turbine and Auxiliaries System.3.4.1-35 Aluminum Piping, piping Loss of material Chapter XI.M36, No Consistent with NUREG-1801.
The components, and piping due to pitting and "External Surfaces External Surfaces Monitoring of Mechanical elements exposed to Air -crevice corrosion Monitoring of Mechanical Components (B.2.1.24) program will be outdoor Components" used to manage loss of material of the aluminum alloy piping, piping components, and piping elements exposed to air -outdoor in the Condensate System.3.4.1-36 PWR Only LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-21 Section 3 -Aging Management Review Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number EffectlMechanism Programs Evaluation Recommended 3.4.1-37 Steel Piping, piping Loss of material Chapter XI.M38, No Consistent with NUREG-1801.
The components, and piping due to general, "Inspection of Internal Inspection of Internal Surfaces in elements exposed to pitting, and crevice Surfaces in Miscellaneous Piping and Ducting Condensation (Internal) corrosion Miscellaneous Piping and Components (B.2.1.25) program will be Ducting Components" used to manage loss of material of the carbon steel piping, piping components, and piping elements and tanks exposed to condensation in the Condensate System and Main Steam System.3.4.1-38 PWR Only 3.4.1-39 Stainless steel Piping, Loss of material Chapter XI.M38, No Not Applicable.
piping components, and due to pitting and "Inspection of Internal There are no stainless steel piping, piping piping elements exposed crevice corrosion Surfaces in componeno and piping p osed to Condensation Miscellaneous Piping and components, and piping elements exposed (Internal)
Ducting Components" to condensation (internal) in the Steam and Power Conversion System.3.4.1-40 Steel Piping, piping Loss of material Chapter XI.M39, No Not Applicable.
components, and piping due to general, "Lubricating Oil Analysis," There are no steel piping, piping elements exposed to pitting, and crevice and components, and piping elements exposed Lubricating oil corrosion Chapter XI.M32, "One- to lubricating oil in Steam and Power Time Inspection" Conversion System.3.4.1-41 PWR Only 3.4.1-42 PWR Only LaSalle County Station, Units 1 and 2 License Renewal Application 0 Page 3.4-22 0 0 Section 3 -Aging Managemenl ew Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-43 Copper alloy Piping, Loss of material Chapter XI.M39, No Not Applicable.
piping components, and due to pitting and "Lubricating Oil Analysis," There are no copper alloy piping, piping piping elements exposed crevice corrosion and There and piping posed to Lubricating oil Chapter XI.M32, 'One- components, and piping elements exposed Time Inspection" to lubricating oil in the Steam and Power Conversion System.3.4.1-44 Stainless steel Piping, Loss of material Chapter XI.M39, No Not Applicable.
piping components, and due to pitting, crevice, "Lubricating Oil Analysis," There are no stainless steel piping, piping piping elements, Heat and microbiologically-and The no and piping piping exchanger components influenced corrosion Chapter XI.M32, "One-exchanger components exposed to exposed to Lubricating oil Time Inspection" lubricating oil in the Steam and Power Conversion System.3.4.1-45 PWR Only 3.4.1-46 PWR Only 3.4.1-47 Steel (with coating or Loss of material due Chapter XI.M41, "Buried No Consistent with NUREG-1801.
The Buried wrapping), stainless to general (steel and Underground Piping and Underground Piping (B.2.1.28) steel, nickel-alloy piping, only), pitting, crevice, and Tanks" program will be used to manage loss of piping components, and and microbiologically-material of the carbon steel piping, piping piping elements; tanks influenced corrosion components, and piping elements exposed exposed to Soil or to soil in the Condensate System.Concrete 3.4.1-48 Stainless steel, nickel Loss of material Chapter XI.M41, "Buried No Not Applicable.
alloy bolting exposed to due to pitting and and Underground Piping There is no stainless steel or nickel alloy soil crevice corrosion and Tanks" bolting exposed to soil in the Steam and Power Conversion System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-23 Section 3 -Aging Management Review Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-49 Stainless steel, nickel Loss of material due Chapter XI.M41, "Buried No Not Applicable.
alloy piping, piping to pitting and crevice and Underground Piping There are no stainless steel or nickel alloy components, and piping corrosion and Tanks" pipi n o pip ing e ns , and or pn g elements exposed to soil piping, piping components, and piping or concrete elements exposed to soil or concrete in the Steam and Power Conversion System.3.4.1-50 Steel Bolting exposed to Loss of material Chapter XI.M41, "Buried No Not Applicable.
Soil due to general, and Underground Piping There is no steel bolting exposed to soil in pitting and crevice and Tanks" the Steam and Power Conversion System.corrosion 3.4.1-50x Underground stainless Loss of material Chapter XI.M41, "Buried No Not Applicable.
steel, nickel alloy, steel due to general (steel and Underground Piping There are no underground stainless steel, piping, piping only), pitting and and Tanks" Thel allo ordere oundipin lessiteel components, and piping crevice corrosion nickel alloy, or steel piping, piping elements components, and piping elements in the Steam and Power Conversion System.3.4.1-51 Steel Piping, piping None None, provided No, if conditions are Not applicable.
components, and piping 1) attributes of the met. There are no steel piping, piping elements exposed to concrete are consistent components, and piping elements exposed Concrete with ACI 318 or ACI 349 to concrete in the Steam and Power (low water-to-cement Concrsin System.ratio, low permeability, Conversion System.and adequate air entrainment) as cited in NUREG-1557, and 2) plant OE indicates no degradation of the concrete LaSalle County Station, Units 1 and 2 License Renewal Application 0 Page 3.4-24 Section 3 -Aging Management~eview Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-52 Aluminum Piping, piping None None NA -No AEM or Not Applicable.
components, and piping AMP elements exposed to There are no aluminum piping, piping Gas, Air- indoor, components, and piping elements exposed uncontrolled to gas, air-indoor, uncontrolled onteroll/xed ) (internal/external) in the Steam and Power (internal/External)
Conversion System.3.4.1-53 PWR Only 3.4.1-54 Copper alloy Piping, None None NA -No AEM or Consistent with NUREG-1 801.piping components, and AMP piping elements exposed to Gas, Air -indoor, uncontrolled (External) 3.4.1-55 Glass Piping elements None None NA -No AEM or Consistent with NUREG-1801.
exposed to Lubricating AMP oil, Air -outdoor, Condensation (Internal/External), Raw water, Treated water, Air with borated water leakage, Gas, Closed-cycle cooling water, Air -indoor, uncontrolled (External) 3.4.1-56 Nickel alloy Piping, piping None None NA -No AEM or Not Applicable.
components, and piping AMP elements exposed to Air There are no nickel alloy piping, piping eeindoor, uncontrolled components, and piping elements exposed (External) to air-indoor, uncontrolled (external) in the Steam and Power Conversion System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-25 Section 3 -Aging Management Review Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-57 Nickel alloy, PVC Piping, None None NA -No AEM or Not Applicable.
piping components, and AMP piping elements exposed There are no nickel alloy or PVC piping, to Air with borated water piping components, and piping elements leakage, Air -indoor, exposed to air-indoor, uncontrolled or uncontrolled, condensation (internal) in the Steam and Condensation (Internal)
Power Conversion System.3.4.1-58 Stainless steel Piping, None None NA -No AEM or Consistent with NUREG-1801.
piping components, and AMP piping elements exposed to Air -indoor, uncontrolled (External), Concrete, Gas, Air-indoor, uncontrolled (Internal) 3.4.1-59 Steel Piping, piping None None NA -No AEM or Not Applicable.
components, and piping AMP elements exposed to Air There are no steel piping, piping-indoor controlled components, and piping elements exposed (External), Gas to air-indoor controlled (external) or gas in the Steam and Power Conversion System.3.4.1-60 Any material, piping, Wall thinning due to Chapter XI.M17, "Flow- No Consistent with NUREG-1801.
The Flow-piping components, and erosion Accelerated Corrosion" Accelerated Corrosion (B.2.1.10) program piping elements exposed will be used to manage wall thinning of the to treated water carbon steel heat exchanger components exposed to treated water in the Condensate and Air Removal System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-26 0 Section 3 -Aging Managementeiew Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number EffectlMechanism Programs Evaluation Recommended 3.4.1-61 Metallic piping, piping Loss of material due A plant-specific aging Yes, plant-specific See subsection 3.4.2.2.6.
components, and tanks to recurring internal management program is exposed to raw water or corrosion to be evaluated to waste water address recurring internal corrosion 3.4.1-62 Steel, stainless steel or Loss of material due Chapter XL.M29, No Consistent with NUREG-1801.
The aluminum tanks (within to general (steel "Aboveground Metallic Aboveground Metallic Tanks (B.2.1.18) the scope of Chapter only), pitting, and Tanks" program will be used to manage loss of XI.M29, "Aboveground crevice corrosion material of the aluminum alloy tanks Metallic Tanks") exposed exposed to treated water in the Condensate to treated water System.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-27 Section 3 -Aging Management Review Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-63 Insulated steel, stainless Loss of material due Chapter XI.M36, No Consistent with NUREG-1801.
The steel, copper alloy, to general (steel, and "External Surfaces External Surfaces Monitoring of Mechanical aluminum, or copper copper alloy), pitting, Monitoring of Mechanical Components (B.2.1.24) program will be alloy (> 15% Zn) piping, or crevice corrosion, Components" or Chapter used to manage loss of material of the piping components, and and cracking due to XI.M29, "Aboveground aluminum alloy, carbon steel, and stainless tanks exposed to stress corrosion Metallic Tanks" (for tanks steel piping, piping components and piping condensation, air-outdoor cracking (aluminum, only) elements and cracking of the stainless steel stainless steel and piping, piping components, and piping copper alloy (>15% elements exposed to air-outdoor in the Zn) only) Condensate System. The aging effect of cracking due to stress corrosion cracking in aluminum does not apply. Cracking in aluminum alloy of these environments occurs when the aluminum alloy chemical composition includes greater than 12% zinc or greater than 6% magnesium (ref. EPRI Report 1010639, Non-Class 1 Mechanical Implementation Guideline and Mechanical Tools, Revision 4 dated January 2006).The cycled condensate storage tank is constructed of ASTM B209 alloy 5454 plates and ASTM B308 alloy 6061-T6 structural members. Both these alloys contain less than 12% zinc and less than 6% magnesium.
3.4.1-64 Jacketed calcium silicate Reduced thermal Chapter XI.M36, No Consistent with NUREG-1801.
The or fiberglass insulation in insulation resistance "External Surfaces External Surfaces Monitoring of Mechanical an air-indoor uncontrolled due to moisture Monitoring of Mechanical Components (B.2.1.24) program will be or air-outdoor intrusion Components" used to manage reduced thermal insulation environment resistance of the jacketed calcium silicate or fiberglass insulation exposed to air-indoor uncontrolled and air-outdoor in the Structural Commodity Group.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-28 0 0 Section 3 -Aging Managemerteview Results Table 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion System Item Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-65 Jacketed foamglas  Reduced thermal Chapter XI.M36, No Consistent with NUREG-1801.
The (glass dust) insulation in insulation resistance "External Surfaces External Surfaces Monitoring of Mechanical an air-indoor uncontrolled due to moisture Monitoring of Mechanical Components (B.2.1,24) program will be or air-outdoor intrusion Components" used to manage reduced thermal insulation environment resistance of the jacketed foamed plastic insulation and stainless steel insulation and insulation jacketing exposed to air-indoor uncontrolled and air-outdoor in the Structural Commodity Group.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-29 Section 3 -Aging Management Review Results Table 3.4.2-1 Condensate System Summary of Aging Management Evaluation Table 3.4.2-1 Condensate System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VIII.H.SP-84 3.4.1-8 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VIII.H.SP-83 3.4.1-10 A Bolting Air -Outdoor (External)
Loss of Material Bolting Integrity (B.2.1.11)
VIII.H.SP-82 3.4.1-8 A Loss of Preload Bolting Integrity (B.2.1.11)
VIII.H.SP-1 51 3.4.1-10 A Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Condensation Loss of Material External Surfaces VIII.E.S-402 3.4.1-63 A, 4 (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-73 3.4.1-14 B Stainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-87 3.4.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-87 3.4.1-16 B Pressure Boundary Aluminum Alloy Air -Outdoor (External)
Loss of Material External Surfaces VIII.H.SP-147 3.4.1-35 A Monitoring of Mechanical VIII.E.S-402 3.4.1-63 A Components (B.2.1.24)
I.S4416_ None None VIII.E.S-402 3.4.1-63 I, 3 LaSalle County,"'on, Units 1 and 2 License Rene W lication.Page 3.4-30 Section 3 -Aging Management Review Results Table 3.4.2-1 Condensate System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Aluminum Alloy Condensation Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 A, 1 components, and (External)
Surfaces in Miscellaneous piping elements Piping and Ducting Components (B.2.1.25)
Treated Water Loss of Material One-Time Inspection VIII.E.SP-90 3.4.1-16 A, 2 (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-90 3.4.1-16 B, 2 Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-90 3.4.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-90 3.4.1-16 B Carbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Air -Outdoor (External)
Loss of Material External Surfaces VIII.H.S-41 3.4.1-34 A Monitoring of Mechanical Vlll.E.5A02 3.4.1-63 A Components (B.2.1.24)
Soil (External)
Loss of Material Buried and Underground VIII.E.SP-145 3.4.1-47 A Piping (B.2.1.28)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-73 3.4.1-14 B Stainless Steel Air -Indoor None None VIII.I.SP-12 3.4.1-58 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-87 3.4.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-87 3.4.1-16 B Tanks (Cycled Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A Condensate Gland Uncontrolled (External)
Monitoring of Mechanical Seal Head Tank) Components (B.2.1.24)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-31 Section 3 -Aging Management Review Results Table 3.4.2-1 Condensate System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Tanks (Cycled Leakage Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VIII.G.SP-60 3.4.1-37 C Condensate Gland Surfaces in Miscellaneous Seal Head Tank) Piping and Ducting Components (B.2.1.25)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-75 3.4.1-12 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-75 3.4.1-12 B Tanks (Cycled Pressure Boundary Aluminum Alloy Air- Outdoor (External)
Loss of Material Aboveground Metallic VIII.E.SP-139 3.4.1-31 A Condensate Tanks (B.2.1.18)
Storage Tank) None None VIII.E.SP-139 3.4.1-31 I, 3 Concrete (External)
Loss of Material Aboveground Metallic VIII.E.SP-139 3.4.1-31 A Tanks (B.2.1.18)
None None VIII.E.SP-139 3.4.1-31 I, 3 Condensation (Internal)
Loss of Material Aboveground Metallic VIII.E.SP-139 3.4.1-31 A Tanks (B.2.1.18)
None None VIII.E.SP-139 3.4.1-31 I, 3 Soil (External)
Loss of Material Aboveground Metallic VIII.E.SP-139 3.4.1-31 A Tanks (B.2.1.18)
None None VIII.E.SP-139 3.4.1-31 I, 3 Treated Water (Internal)
Loss of Material Aboveground Metallic VIII.E.S-405 3.4.1-62 A Tanks (B.2.1.18)
Valve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-73 3.4.1-14 B Copper Alloy with Air -Indoor None None VIII.I.SP-6 3.4.1-54 A less than 15% Uncontrolled (External)
Zinc LaSalle Countyfton, Units 1 and 2 License Rene W lication 0 Page 3.4-32 0 e Section 3 -Aging Management Review Results Table 3.4.2-1 Condensate System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Leakage Boundary Copper Alloy with Treated Water (Internal)
Loss of Material One-Time Inspection VIII.A.SP-101 3.4.1-16 A less than 15% (B.2.1.21)
Zinc Water Chemistry (B.2.1.2)
VIII.A.SP-101 3.4.1-16 B Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Air -Outdoor (External)
Loss of Material External Surfaces VIII.H.S-41 3.4.1-34 A Monitoring of Mechanical VIII.E.S-402 3.4.1-63 A Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-73 3.4.1-14 B Stainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 A Uncontrolled (External) i Air -Outdoor (External)
Cracking External Surfaces VIII.E.SP-1 18 3.4.1-2 A Monitoring of Mechanical VIII.E.S-402 3.4.1-63 A Components (B.2.1.24)
VIE-2.13 Loss of Material External Surfaces VIII.E.SP-127 3.4.1-3 A Monitoring of Mechanical VIII.E.S-402 3.4.1-63 A Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-87 3.4.1-16 A (B.2.1.21)
___ Water Chemistry (B.2.1.2)
VIII.E.SP-87 3.4.1-16 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-33 Section 3 -Aging Management Review Results Table 3.4.2-1 Condensate System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. Aluminum piping exposed to a condensation (external) environment is located in the airspace of the Cycled Condensate Storage Tank. This piping will be inspected using the Inspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) aging management program.The external surfaces of this piping will be made accessible for inspection during internal tank inspections performed under the Aboveground Metallic Tanks (B.2.1.18) aging management program.2. Aluminum piping exposed to a treated water (external) environment is submerged piping located in the Cycled Condensate Storage Tank.3. The aging effect of cracking due to stress corrosion cracking does not apply. Cracking in aluminum alloy in this environment occurs when the aluminum alloy chemical composition includes greater than 12% zinc or greater than 6% magnesium (ref. EPRI Report 1010639, Non-Class 1 Mechanical Implementation Guideline and Mechanical Tools, Revision 4 dated January 2006). The cycled condensate storage tank is constructed of ASTM B209 alloy 5454 plates and ASTM B308 alloy 6061-T6 structural members and piping. Both these alloys contain less than 12% zinc and less than 6% magnesium.
: 4. These components are in an air-indoor, uncontrolled environment, and are insulated.
Because of the potential for air in-leakage through minor gaps in insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dew point of the air on the external surfaces of the insulation.
LaSalle County,@Kon, Units 1 and 2 _ Page 3.4-34 License Rene~ Wplication Section 3 -Aging Management Review Results Table 3.4.2-2 Condenser and Air Removal System Summary of Aging Management Evaluation Table 3.4.2-2 Condenser and Air Removal System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notes pe Function Requiring Programs Item t IManagement Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VIII.H.SP-84 3.4.1-8 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VIII.H.SP-83 3.4.1-10 A Bolting Heat Exchanger
-Containment, Holdup Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A (Main Condenser) and Plateout Uncontrolled (External)
Monitoring of Mechanical Shell Side Components (B.2.1.24)
Components Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-77 3.4.1-15 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIlI.E.SP-77 3.4.1-15 B Wall Thinning Flow-Accelerated VIII.D2.S-408 3.4.1-60 C Corrosion (B.2.1.10)
Piping, piping Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Treated Water (Internal)
Cumulative Fatigue TLAA VIII.B2.S-08 3.4.1-1 A, 1 Damage Loss of Material One-Time Inspection VIII.E.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-73 3.4.1-14 B Wall Thinning Flow-Accelerated VIII.E.S-16 3.4.1-5 A Corrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-87 3.4.1-16 A (B.2.1.21)
LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-35 Section 3 -Aging Management Review Results Table 3.4.2-2 Condenser and Air Removal System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Stainless Steel Treated Water (Internal)
Loss of Material Water Chemistry (B.2.1.2)
VIII.E.SP-87 3.4.1-16 B components, and piping elements Valve Body Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.E.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-73 3.4.1-14 B Wall Thinning Flow-Accelerated VIII.E.S-16 3.4.1-5 A Corrosion (B.2.1.10)
-1 LaSalle County~on, Units 1 and 2 License Rene~Vlication
.Page 3.4-36 Section 3 -Aging Management Review Results Table 3.4.2-2 Condenser and Air Removal System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-37 Section 3 -Aging Management Review Results Table 3.4.2-3 Feedwater System Summary of Aging Management Evaluation Table 3.4.2-3 Feedwater System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VIII.H.SP-84 3.4.1-8 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VIII.H.SP-83 3.4.1-10 A Bolting Piping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Treated Water (Internal)
Cumulative Fatigue TLAA VIII.D2.S-11 3.4.1-1 A, 1 Damage Loss of Material One-Time Inspection VIII.D2.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.D2.SP-73 3.4.1-14 B Wall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 A Corrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.D2.SP-87 3.4.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.D2.SP-87 3.4.1-16 B Treated Water > 140 F Cracking One-Time Inspection VIII.E.SP-88 3.4.1-11 A (Internal) (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-88 3.4.1-11 B Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 1 Damage Loss of Material One-Time Inspection VIII.D2.SP-87 3.4.1-16 A F_ (B.2.1.21)
LaSalle CountA tion, Units 1 and 2 License ReneV plication.Page 3.4-38 Section 3 -Aging Management Review Results Table 3.4.2-3 Feedwater System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Leakage Boundary Stainless Steel Treated Water > 140 F Loss of Material Water Chemistry (B.2.1.2)
VIII.D2.SP-87 3.4.1-16 B components, and (Internal) piping elements Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Cumulative Fatigue TLAA VIII.D2.S-11 3.4.1-1 A, 1 Damage Loss of Material One-Time Inspection VIII.D2.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.D2.SP-73 3.4.1-14 B Wall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 A Corrosion (B.2.1.10)
Valve Body Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.D2.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.D2.SP-73 3.4.1-14 B Wall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 A Corrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 A Uncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.D2.SP-87 3.4.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.D2.SP-87 3.4.1-16 B Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.D2.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemisty (B.2.1.2)
VIII.D2.SP-73 3.4.1-14 B LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-39 Section 3 -Aging Management Review Results Table 3.4.2-3 Feedwater System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Valve Body Pressure Boundary Carbon Steel Treated Water (Internal)
Wall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 A I I ~~Corrosion (B.2.1.10)
I LaSalle Country~ion, Units 1 and 2 License ReneWv plication 0 Page 3.4-40 Section 3 -Aging Management Review Results Table 3.4.2-3 Feedwater System (Continued)
Notes Definition of Note A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-41 Section 3 -Aging Management Review Results Table 3.4.2-4 Main Steam System Summary of Aging Management Evaluation Table 3.4.2-4 Main Steam System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Bolting Mechanical Closure Carbon and Low Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VIII.H.SP-84 3.4.1-8 A Alloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VIII.H.SP-83 3.4.1-10 A Bolting Piping, piping Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A components, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.B2.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-73 3.4.1-14 B Wall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 A Corrosion (B.2.1.10)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VIII.B1.SP-60 3.4.1-37 A Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25)
Steam (Internal)
Cumulative Fatigue TLAA VIII.B2.S-08 3.4.1-1 A, 1 Damage Loss of Material One-Time Inspection VIII.B2.SP-160 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-160 3.4.1-14 B Wall Thinning Flow-Accelerated VIII.B2.S-15 3.4.1-5 A Corrosion (B.2.1.10)
LaSalle Countvfion, Units 1 and 2 License Rene1Plication O Page 3.4-42 Section 3 -Aging Management Review Results Table 3.4.2-4 Main Steam System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping components, and piping elements Pressure Boundary Carbon Steel Treated Water (External)
Cumulative Fatigue Damage TLAA VIII.B2.S-08 3.4.1-1 A, 1 Loss of Material One-Time Inspection (B.2.1.21)
VIII.B2.SP-73 3.4.1-14 A Water Chemistry (B.2.1.2)VIII.B2.SP-73 3.4.1-14 B Treated Water (Internal)l Cumulative Fatigue Damage TLAA VIII.B2.S-08 3.4.1-1 A, I Loss of Material One-Time Inspection VIII.B2.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-73 3.4.1-14 B Wall Thinning Flow-Accelerated Corrosion (B.2.1.10)
VIII.D2.S-16 3.4.1-5 A Stainless Steel Air -Indoor Uncontrolled (External)
None None VIII.I.SP-12 3.4.1-58 A Steam (Internal)
Cracking One-Time Inspection VIII.B2.SP-98 3.4.1-11 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-98 3.4.1-11 B Loss of Material One-Time Inspection VIII.B2.SP-155 3.4.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-155 3.4.1-16 B Treated Water Loss of Material One-Time Inspection VIII.C.SP-87 3.4.1-16 A (External) (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.C.SP-87 3.4.1-16 B Treated Water (Internal)
Loss of Material One-Time Inspection VIII.C.SP-87 3.4.1-16 A (B.2.1.21)
_Water Chemistry (B.2.1.2)
VIII.C.SP-87 3.4.1-16 B Treated Water > 140 F (Internal)
Cracking One-Time Inspection (B.2.1.21)
VIII.C.SP-88 3.4.1-11 A Water Chemistry (B.2.1.2)VIII.C.SP-88 3.4.1-11 B+ -. __________
_________Loss of Material One-Time Inspection (B.2.1.21)
VIII.C.SP-87 3.4.1-16 A LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-43 Section 3 -Aging Management Review Results Table 3.4.2-4 Main Steam System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Piping, piping Pressure Boundary Stainless Steel Treated Water > 140 F Loss of Material Water Chemistry (B.2.1.2)
VIII.C.SP-87 3.4.1-16 B components, and (Internal) piping elements Valve Body Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Loss of Material One-Time Inspection VIII.B2.SP-73 3.4.1-14 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-73 3.4.1-14 B Wall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 A Corrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 A Uncontrolled (External)
Treated Water > 140 F Cracking One-Time Inspection VIII.C.SP-88 3.4.1-11 A (Internal) (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.C.SP-88 3.4.1-11 B Loss of Material One-Time Inspection VIII.C.SP-87 3.4.1-16 A (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.C.SP-87 3.4.1-16 B LaSalle CountKtion, Units 1 and 2 License ReneW plication 0 Page 3.4-44 Section 3 -Aging Management Review Results Table 3.4.2-4 Main Steam System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1 801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: 1. The TLAA designation in the Aging Management Program column indicates that fatigue of this component is evaluated in Section 4.3.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-45 Section 3 -Aging Management Review Results Table 3.4.2-5 Main Turbine and Auxiliaries System Summary of Aging Management Evaluation Table 3.4.2-5 Main Turbine and Auxiliaries System Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item Notes Type Function Requiring Programs Item Management Turbine Casings Containment, Holdup Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 A (Low Pressure and Plateout Uncontrolled (External)
Monitoring of Mechanical Turbine Exhaust Components (B.2.1.24)
Hoods) Treated Water (Internal)
Loss of Material One-Time Inspection VIII.B2.SP-73 3.4.1-14 C (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.B2.SP-73 3.4.1-14 D Wall Thinning Flow-Accelerated VIII.E.S-16 3.4.1-5 C____. _Corrosion (B.2.1.10)
LaSalle Countydilon, Units I and 2 License Renevw lication.Page 3.4-46 Section 3 -Aging Management Review Results Table 3.4.2-5 Main Turbine and Auxiliaries System (Continued)
Notes Definition of Note A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.
G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination.
I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable.
J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Plant Specific Notes: None.LaSalle County Station, Units 1 and 2 License Renewal Application Page 3.4-47 This Page Intentionally Left Blank}}

Latest revision as of 15:30, 10 January 2025

License Renewal Application, Title Page -Section 3, Table 3.4.2-5
ML14343A841
Person / Time
Site: LaSalle  Constellation icon.png
Issue date: 12/09/2014
From:
Exelon Generation Co
To:
Office of Nuclear Reactor Regulation
Shared Package
ML14343A849 List:
References
RA14-059
Download: ML14343A841 (776)
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