ML14343A841
| ML14343A841 | |
| Person / Time | |
|---|---|
| Site: | LaSalle  |
| 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) | |
Text
LICENSE RENEWAL APPLICATION LaSalle County Station, Units 1 and 2Facility Operating License Nos.NPF-11 and NPF-18 This Page Intentionally Left Blank Table of ContentsTABLE OF CONTENTSSECTION 1Administrative Information 1.0 ADMINISTRATIVE INFORMATION
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1-11.1 GENERAL INFORMATION
-10 CFR 54.19 ..........................................
1-11.1.1 N am e of A pplica nt ...................................................................................
1-11.1.2 A dd ress of A pplicant
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1-11.1.3 Descriptions of Business or Occupation of Applicant
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1-11.1.4 Descriptions of Organization and Management of Applicant
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1-11.1.5 Class of License, Use of the Facility, and Period of Time forW hich the License Is Sought ..................................................................
1-21.1.6 Earliest and Latest Dates for Alterations, If Proposed
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1-21.1.7 Restricted Data ...............
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1-31.1.8 R eg ulatory A ge ncies ...............................................................................
1-31.1.9 Local N ew s P ublications
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1-31.1.10 Conforming Changes to Standard Indemnity Agreement
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1-41.2 GENERAL LICENSE INFORMATION
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1-51.2.1 Application
- Updates, Renewed Licenses, and RenewalT e rm O pe ratio n ......................................................................................
1-51.2.2 Incorporation by R eference
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1-51.2 .3 C ontact Inform ation .................................................................................
1-51 .3 P U R P O S E ..............................................................................................
1-61.4 DESCRIPTION OF THE PLANT ............................................................
1-61.5 APPLICATION STRUCTURE
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1-61.6 A C R O N Y M S .........................................................................................
1-101.7 GENERAL REFERENCES
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1-13LaSalle County Station, Units 1 and 2License Renewal Application Page ii Table of ContentsSECTION 22.0 SCOPING AND SCREENING METHODOLOGY FOR IDENTIFYING STRUCTURES AND COMPONENTS SUBJECT TO AGINGMANAGEMENT REVIEW, AND IMPLEMENTATION RESULTS .............
2.0-12.1 SCOPING AND SCREENING METHODOLOGY
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2.1-12 .1 .1 Intro d u ctio n ..........................................................................................
2 .1-12.1.2 Information Sources Used for Scoping and Screening
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2.1-42.1.3 Technical Basis Documents
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2.1-52.1.4 Interim Staff Guidance Discussion
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2.1-152.1.5 S coping P rocedure
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2.1-172.1.6 S creening P rocedure
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2.1-272.1.7 G eneric Safety Issues .......................................................................
2.1-352 .1 .8 C o n clus io n .........................................................................................
2 .1-3 52.2 PLANT LEVEL SCOPING RESULTS ........................................................
2.2-12.3 SCOPING AND SCREENING RESULTS:
MECHANICAL
.......................
2.3-12.3.1 Reactor Vessel, Internals, and Reactor Coolant System ...............
2.3-12.3.1.1 Reactor Coolant Pressure Boundary System .............................
2.3-22 .3.1.2 R eactor V esse l ...........................................................................
2 .3-72.3.1.3 Reactor Vessel Internals
...........................................................
2.3-122.3.2 Engineered Safety Features Systems ...........................................
2.3-162.3.2.1 High Pressure Core Spray System ...........................................
2.3-172.3.2.2 Low Pressure Core Spray System ............................................
2.3-212.3.2.3 Reactor Core Isolation Cooling System ....................................
2.3-252.3.2.4 Residual Heat Removal System ...............................................
2.3-292.3.2.5 Standby Gas Treatment System ...............................................
2.3-342.3.3 A uxiliary S ystem s ............................................................................
2.3-372.3.3.1 Closed Cycle Cooling Water System ........................................
2.3-382.3.3.2 Combustible Gas Control System .............................................
2.3-422.3.3.3 Compressed Air System ...........................................................
2.3-462.3.3.4 Control Rod Drive System ........................................................
2.3-482.3.3.5 Control Room Ventilation System .............................................
2.3-532.3.3.6 Cranes, Hoists and Refueling Equipment System ....................
2.3-582.3.3.7 Demineralizer Water Makeup System ......................................
2.3-612.3.3.8 Diesel Generator and Auxiliaries System .................................
2.3-642.3.3.9 Drywell Pneumatic System .......................................................
2.3-702.3.3.10 Electrical Penetration Pressurization System ...........................
2.3-742.3.3.11 Essential Cooling Water System ..............................................
2.3-762.3.3.12 Fire Protection System .............................................................
2.3-81LaSalle County Station, Units 1 and 2License Renewal Application Page iii Table of Contents2.3.3.13 Fuel Pool Cooling and Storage System ....................................
2.3-862.3.3.14 Nonessential Cooling Water System ........................................
2.3-902.3.3.15 Nonsafety-Related Ventilation System .....................................
2.3-952.3.3.16 Plant Drainage System .............................................................
2.3-982.3.3.17 Primary Containment Ventilation System ...............................
2.3-1052.3.3.18 Process Radiation Monitoring System ....................................
2.3-1092.3.3.19 Process Sampling and Post Accident Monitoring System ...... 2.3-1142.3.3.20 Radw aste System ...................................................................
2.3-1192.3.3.21 Reactor Water Cleanup System .............................................
2.3-1222.3.3.22 Safety-Related Ventilation System .........................................
2.3-1262.3.3.23 Standby Liquid Control System ..............................................
2.3-1312.3.3.24 Suppression Pool Cleanup System ........................................
2.3-1342.3.3.25 Traversing Incore Probe System ............................................
2.3-1362.3.4 Steam and Power Conversion System .....................
2.3-1392.3.4.1 Condensate System ...............................................................
2.3-1402.3.4.2 Condenser and Air Removal System ......................................
2.3-1452.3.4.3 Feedw ater System ..................................................................
2.3-1482.3.4.4 Main Steam System ................................................................
2.3-1522.3.4.5 Main Turbine and Auxiliaries System ....................................
2.3-1562.4 SCOPING AND SCREENING RESULTS:
STRUCTURES ANDCOMPONENT SUPPORTS
........................................................................
2.4-12 .4 .1 A uxiliary B uild ing ........................................................................
2 .4-22.4.2 Component Supports Commodity Group ....................................
2.4-72 .4 .3 C oo ling Lake .............................................................................
2 .4 -112.4.4 Diesel Generator Building
.........................................................
2.4-162.4.5 Lake Screen House ..................................................................
2.4-202 .4 .6 O ffgas B uilding .........................................................................
2.4-252.4.7 Prim ary C ontainm ent ................................................................
2.4-282.4.8 R adw aste B uilding ....................................................................
2.4-372.4 .9 R eactor B uilding .......................................................................
2.4-4 12.4.10 Structural Commodity Group ....................................................
2.4-472.4.11 Sw itchyard Structures
...............................................................
2.4-532.4.12 Tank Foundations and Dikes ....................................................
2.4-562 .4 .13 T urbine B uilding ........................................................................
2 .4-592.4 .14 Y ard S tructures
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2.4-632.5 SCOPING AND SCREENING RESULTS:
ELECTRICAL
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2.5-12.5.1 Electrical Systems ................................
2.5-12.5.2 Electrical C om m odities ...............................................................
2.5-12.5.2.1 Identification of Electrical Commodities
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2.5-12.5.2.2 Application of Screening Criterion 10 CFR 54.21 (a)(1)(i) to theElectrical Components and Commodities
...................................
2.5-32.5.2.3 Elimination of Electrical Commodity Groups WithNo License Renewal Intended Functions
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2.5-32.5.2.4 Application of Screening Criteria 10 CFR 54.21 (a)(1)(ii) toE lectrical C om m odities ...............................................................
2.5-4LaSalle County Station, Units 1 and 2 Page ivLicense Renewal Application Table of Contents2.5.2.5 Electrical Commodities Subject to Aging Management Review 2.5-52.5.2.5.1 Cable Connections (Metallic Parts) ............................................
2.5-52.5.2.5.2 Electrical Penetrations
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2.5-52.5.2.5.3 High Voltage Insulators
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2.5-52.5.2.5.4 Insulation Material for Electrical Cables and Connections
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2.5-52.5.2.5.5 Metal Enclosed Bus ....................................................................
2.5-62.5.2.5.6 Switchyard Bus and Connections, Transmission Conductors, and Transmission Connectors
....................................................
2.5-6LaSalle County Station, Units 1 and 2License Renewal Application Page v Table of ContentsSECTION 33.0 AGING MANAGEMENT REVIEW RESULTS ............................................
3.0-13.1 AGING MANAGEMENT OF REACTOR VESSEL, INTERNALS ANDREACTOR COOLANT SYSTEM ................................................................
3.1-13 .1 .1 Intro d u ctio n ..........................................................................................
3 .1-13 .1 .2 R e s u lts .................................................................................................
3 .1-13.1.2.1 Materials, Environments, Aging Effects Requiring Management and Aging Management Programs
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3.1-13.1.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport .............................................................................
3 .1-63.1.2.3 Time-Limited Aging Analysis
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3.1-143 .1 .3 C o n clu sio n .........................................................................................
3 .1-143.2 AGING MANAGEMENT OF ENGINEERED SAFETY FEATURES
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3.2-13 .2 .1 Intro d u ctio n ..........................................................................................
3 .2 -13 .2 .2 R e s u lts .................................................................................................
3 .2 -13.2.2.1 Materials, Environments, Aging Effects Requiring Management and Aging Management Programs
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3.2-13.2.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport .............................................................................
3.2-73.2.2.3 Time-Limited Aging Analysis
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3.2-123 .2 .3 C onclusion
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3.2-123.3 AGING MANAGEMENT OF AUXILIARY SYSTEMS ................................
3.3-13 .3 .1 Intro d uctio n ..........................................................................................
3 .3 -13 .3 .2 R e s u lts .................................................................................................
3 .3 -23.3.2.1 Materials, Environments, Aging Effects Requiring Management And Aging Management Programs
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3.3-33.3.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport ...........................................................................
3.3-303.3.2.3 Time-Limited Aging Analysis
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3.3-353 .3 .3 C o nclusio n .........................................................................................
3 .3-3 53.4 AGING MANAGEMENT OF STEAM AND POWER CONVERSION S Y S T E M ....................................................................................................
3 .4 -13 .4 .1 Intro d u ctio n ..........................................................................................
3 .4 -13 .4 .2 R e s u lts .................................................................................................
3 .4 -13.4.2.1 Materials, Environments, Aging Effects Requiring Management andAging Management Programs
.............................................................
3.4-13.4.2.2 AMR Results for Which Further Evaluation is Recommended bythe G A LL R eport ..................................................................................
3.4-63.4.2.3 Time-Limited Aging Analysis
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3.4-93 .4 .3 C o nclusio n .........................................................................................
3 .4 -10LaSalle County Station, Units 1 and 2License Renewal Application Page vi Table of Contents3.5 AGING MANAGEMENT OF STRUCTURES AND COMPONENT S U P P O R T S ................................................................................................
3 .5-13 .5 .1 Intro d u ctio n ..........................................................................................
3 .5-13 .5 .2 R e s u lts .................................................................................................
3 .5 -13.5.2.1 Materials, Environments, Aging Effects Requiring Management and Aging Management Programs
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3.5-23.5.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport ...........................................................................
3.5-193.5.2.3 Time-Limited Aging Analysis
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3.5-303 .5 .3 C o nclusio n .........................................................................................
3 .5-3 13.6 AGING MANAGEMENT OF ELECTRICAL COMPONENTS
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3.6-13 .6 .1 Intro d uctio n ..........................................................................................
3 .6 -13 .6 .2 R e s u lts .................................................................................................
3 .6 -13.6.2.1 Materials, Environments, Aging Effects Requiring Management And Aging Management Programs
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3.6-13.6.2.2 AMR Results for Which Further Evaluation is Recommended by the G A LL R eport .............................................................................
3.6-53.6.2.3 AMR Results Not Consistent With or Not Addressed in the GALLR e p o rt ................................................................................................
3 .6 -1 03.6.2.4 Time-Limited Aging Analysis
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3.6-113 .6 .3 C o nclusio n .........................................................................................
3 .6 -1 1SECTION 44.0 TIME-LIMITED AGING ANALYSES
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4-14.1 IDENTIFICATION AND EVALUATION OF TIME-LIMITED AGINGA N A L Y S E S ...................................................................................................
4 -14.1.1 Identification of LSCS Time-Limited Aging Analyses
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4-14.1.2 Evaluation of LSCS Time-Limited Aging Analyses
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4-34 .1.3 A cceptance C riteria .................................................................................
4-34 .1.4 S um m ary of R esults ................................................................................
4-44.1.5 Identification of Exemptions Pursuant to 10 CFR 50.12 .........................
4-44.2 REACTOR VESSEL AND INTERNALS NEUTRON EMBRITTLEMENT A N A L Y S E S ...................................................................................................
4 -74.2.1 Neutron Fluence Analyses
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4-94.2.2 Upper-Shelf Energy Analyses
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4-224.2.3 Adjusted Reference Temperature Analyses
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4-324.2.4 Pressure-Temperature Limits ................................................................
4-434.2.5 Axial Weld Failure Probability Assessment Analyses
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4-444.2.6 Circumferential Weld Failure Probability Assessment Analyses
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4-474.2.7 Reactor Pressure Vessel Reflood Thermal Shock Analysis
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4-514.2.8 RPV Core Plate Rim Hold-Down Bolt Loss of Preload Analysis
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4-57LaSalle County Station, Units 1 and 2License Renewal Application Page vii Table of Contents4.2.9 Jet Pump Riser Brace Clamp Loss of Preload Analysis
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4-584.2.10 Jet Pump Slip Joint Repair Clamp Loss of Preload Analysis
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4-594.3 M ETAL FATIG UE ANALYSES
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4-604.3.1 ASME Section III, Class I Fatigue Analyses
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4-604.3.2 ASME Section III, Class 2 and 3 and ANSI B31.1 Allowable StressA n a ly se s ...............................................................................................
4 -7 44.3.3 Environmental Fatigue Analyses for RPV and Class 1 Piping ..............
4-764.3.4 Reactor Vessel Internals Fatigue Analyses
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4-904.3.5 High-Energy Line Break (HELB) Analyses Based on Fatigue .............
4-924.3.6 Main Steam Relief Valve Discharge Piping Fatigue Analyses
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4-934.4 ENVIRONMENTAL QUALIFICATION (EQ) OF ELECTRICC O M P O N E N T S ..........................................................................................
4-954.4.1 Environmental Qualification (EQ) of Electric Components
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4-954.5 CONCRETE CONTAINMENT TENDON PRESTRESS ANALYSES
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4-984.5.1 Concrete Containment Tendon Prestress Analyses
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4-984.6 PRIMARY CONTAINMENT FATIGUE ANALYSES
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4-1044.6.1 Primary Containment Liner and Penetrations Fatigue Analyses
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4-1044.6.2 Primary Containment Refueling Bellows Fatigue Analysis
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4-1064.6.3 Primary Containment Downcomer Vents Fatigue Analysis
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4-1074.7 OTHER PLANT-SPECIFIC TIME-LIMITED AGING ANALYSES
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4-1094.7.1 Reactor Building Crane Cyclic Loading Analysis
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4-1094.7.2 Main Steam Line Flow Restrictors Erosion Analysis
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4-1114 .8 R E F E R E N C E S .........................................................................................
4-112List of Appendices APPENDIX A -FINAL SAFETY ANALYSIS REPORTAPPENDIX B -AGING MANAGEMENT PROGRAMSAPPENDIX C -RESPONSE TO BWRVIP LICENSE RENEWAL APPLICATION ACTION ITEMSAPPENDIX D -TECHNICAL SPECIFICATION CHANGES (Not Used)APPENDIX E -APPLICANT'S ENVIRONMENTAL REPORT -OPERATING LICENSERENEWAL STAGELaSalle County Station, Units 1 and 2License Renewal Application Page viii Table of ContentsList of TablesTable 2.1-1Table 2.2-1Table 2.3.1-1Table 2.3.1-2Table 2.3.1-3Table 2.3.2-1Table 2.3.2-2Table 2.3.2-3Table 2.3.2-4Table 2.3.2-5Table 2.3.3-1Table 2.3.3-2Table 2.3.3-3Table 2.3.3-4Table 2.3.3-5Table 2.3.3-6Table 2.3.3-7Table 2.3.3-8Table 2.3.3-9Table 2.3.3-10Table 2.3.3-11Table 2.3.3-12Table 2.3.3-13Table 2.3.3-14Table 2.3.3-150Passive Structure and Component Intended FunctionD e fi n itio n s ..........................................................................................
2 .1-3 2Plant Level Scoping Results ................................................................
2.2-2Components Subject to Aging Management Review -ReactorCoolant Pressure Boundary System ....................................................
2.3-6Components Subject to Aging Management Review -ReactorV e s s e l ................................................................................................
2 .3 -1 0Components Subject to Aging Management Review -ReactorV esse l Internals
.................................................................................
2 .3-15Components Subject to Aging Management Review -HighPressure Core Spray System ............................................................
2.3-19Components Subject to Aging Management Review -LowPressure Core Spray System ............................................................
2.3-24Components Subject to Aging Management Review -ReactorCore Isolation Cooling System ..........................................................
2.3-28Components Subject to Aging Management Review -ResidualHeat Rem oval System .......................................................................
2.3-33Components Subject to Aging Management Review -StandbyG as Treatm ent System ......................................................................
2.3-36Components Subject to Aging Management Review -ClosedCycle Cooling W ater System .............................................................
2.3-41Components Subject to Aging Management Review -Combustible G as C ontrol S ystem ..........................................................................
2.3-45Components Subject to Aging Management Review -Compressed A ir S yste m ..........................................................................................
2 .3 -4 7Components Subject to Aging Management Review -Control RodD rive S yste m ......................................................................................
2 .3-52Components Subject to Aging Management Review -ControlRoom Ventilation System ...................................................................
2.3-57Components Subject to Aging Management Review -Cranes,Hoists and Refueling Equipment System ..........................................
2.3-60Components Subject to Aging Management Review -Demineralized W ater M akeup System .....................................................................
2.3-63Components Subject to Aging Management Review -DieselGenerator and Auxiliaries System .....................................................
2.3-69Components Subject to Aging Management Review -DrywellP neum atic S ystem ...........................................................................
2.3-72Components Subject to Aging Management Review -Electrical Penetration Pressurization System .................................................
2.3-75Components Subject to Aging Management Review -Essential C ooling W ater System ......................................................................
2.3-79Components Subject to Aging Management Review -Fire Protection S y ste m ..............................................................................................
2 .3 -8 5Components Subject to Aging Management Review -Fuel PoolC ooling and Storage System .............................................................
2.3-89Components Subject to Aging Management Review -Nonessential C ooling W ater System ......................................................................
2.3-94Components Subject to Aging Management Review -Nonsafety-Related Ventilation System ..............................................
2.3-97LaSalle County Station, Units 1 and 2License Renewal Application Page ix Table of ContentsTable 2.3.3-16Table 2.3.3-17Table 2.3.3-18Table 2.3.3-19Table 2.3.3-20Table 2.3.3-21Table 2.3.3-22Table 2.3.3-23Table 2.3.3-24Table 2.3.3-25Table 2.3.4-1Table 2.3.4-2Table 2.3.4-3Table 2.3.4-4Table 2.3.4-5Table 2.4-1Table 2.4-2Table 2.4-3Table 2.4-4Table 2.4-5Table 2.4-6Table 2.4-7Table 2.4-8Table 2.4-9Table 2.4-10Components Subject to Aging Management Review -PlantD rainage S ystem ............................................................................
2.3-103Components Subject to Aging Management Review -PrimaryContainment Ventilation System ....................................................
2.3-107Components Subject to Aging Management Review -ProcessRadiation Monitoring System ...........................................................
2.3-113Components Subject to Aging Management Review -ProcessSampling and Post Accident Monitoring System ...........................
2.3-118Components Subject to Aging Management Review -RadwasteS y ste m ...........................................................................................
2 .3 -12 1Components Subject to Aging Management Review -ReactorWater Cleanup System ..................................................................
2.3-125Components Subject to Aging Management Review -Safety-Related Ventilation System .............................................................
2.3-130Components Subject to Aging Management Review -StandbyLiquid Control System ...................................................................
2.3-133Components Subject to Aging Management Review -Suppression Pool Cleanup System ...............................................
2.3-135Components Subject to Aging Management Review -Traversing Incore P robe S ystem .....................................................................
2.3-138Components Subject to Aging Management Review -Condensate System ........................................................................
2.3-143Components Subject to Aging Management Review -Condenser and Air Removal System .................................................................
2.3-144Components Subject to Aging Management Review -Feedwater S y ste m .............................................................................................
2 .3 -14 7Components Subject to Aging Management Review -MainS team S yste m ..................................................................................
2 .3-155Components Subject to Aging Management Review -Main Turbineand A uxiliaries S ystem .....................................................................
2.3-158Components Subject to Aging Management Review -Auxiliary B u ild in g ................................................................................................
2 .4 -5Components Subject to Aging Management Review -Component Supports Commodity Group ................................................................
2.4-9Components Subject to Aging Management Review -C o o ling La ke ......................................................................................
2 .4 -15Components Subject to Aging Management Review -DieselG e nerator B uilding .............................................................................
2 .4-18Components Subject to Aging Management Review -Lake ScreenH o u se .................................................................................................
2 .4 -2 3Components Subject to Aging Management Review -OffgasB u ild in g ..............................................................................................
2 .4 -2 7Components Subject to Aging Management Review -PrimaryC o nta inm e nt ......................................................................................
2 .4 -33Components Subject to Aging Management Review -RadwasteB u ild in g ..............................................................................................
2 .4 -3 9Components Subject to Aging Management Review -ReactorB u ild in g ..............................................................................................
2 .4 -4 5Components Subject to Aging Management Review -Structural C om m odity G roup .............................................................................
2 .4-5 1LaSalle County Station, Units 1 and 2License Renewal Application Page x Table of ContentsTable 2.4-11Table 2.4-12Table 2.4-13Table 2.4-14Table 2.5.2-1Table 3.0-1Table 3.1.1Table 3.1.2-1Table 3.1.2-2Table 3.1.2-3Table 3.2.1Table 3.2.2-1Table 3.2.2-2Table 3.2.2-3Table 3.2.2-4Table 3.2.2-5Table 3.3.1Table 3.3.2-1Table 3.3.2-2Table 3.3.2-3Table 3.3.2-4Table 3.3.2-5Table 3.3.2-6Table 3.3.2-7Table 3.3.2-8Table 3.3.2-9Table 3.3.2-10Components Subject to Aging Management Review -Switchyard S tru ctu re s ..........................................................................................
2 .4 -5 5Components Subject to Aging Management Review -TankFoundation and D ikes ........................................................................
2.4-58Components Subject to Aging Management Review -TurbineB u ild in g ..............................................................................................
2 .4 -6 1Components Subject to Aging Management Review -YardS tru ctu re s ..........................................................................................
2 .4 -6 7Electrical Commodities Subject to Aging Management Review ...........
2.5-7LaSalle Service Environm ents .............................................................
3.0-5Summary of Aging Management Evaluations for the ReactorVessel, Internals, and Reactor Coolant System .................................
3.1-16Reactor Coolant Pressure Boundary System Summary ofAging M anagem ent Evaluation
..........................................................
3.1-43Reactor Vessel Summary of Aging Management Evaluation
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3.1-56Reactor Vessel Internals Summary of Aging Management E v a lu a tio n ..........................................................................................
3 .1-8 2Summary of Aging Management Evaluations for the Engineered S afety Features
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3 .2-13High Pressure Core Spray System Summary of AgingM anagem ent Evaluation
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3.2-33Low Pressure Core Spray System Summary of AgingM anagem ent Evaluation
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3.2-39Reactor Core Isolation Cooling System Summary of AgingM anagem ent Evaluation
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3.2-4 5Residual Heat Removal System Summary of AgingM anagem ent Evaluation
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3.2-58Standby Gas Treatment System Summary of AgingM anagem ent Evaluation
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3.2-65Summary of Aging Management Evaluations for the Auxiliary S y ste m s .............................................................................................
3 .3 -3 6Closed Cycle Cooling Water System Summary of AgingManagement Evaluation
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3.3-92Combustible Gas Control System Summary of AgingM anagem ent Evaluation
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3.3-99Compressed Air System Summary of Aging Management E va luatio n ........................................................................................
3 .3-10 3Control Rod Drive System Summary of Aging Management E va lu atio n ........................................................................................
3 .3-10 6Control Room Ventilation System Summary of AgingM anagem ent Evaluation
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3.3-112Cranes, Hoists and Refueling Equipment System Summary ofAging M anagem ent Evaluation
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3.3-121Demineralized Water Makeup System Summary of AgingM anagem ent Evaluation
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3.3-124Diesel Generator and Auxiliaries System Summary of AgingM anagem ent Evaluation
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3.3-128Drywell Pneumatic System Summary of Aging Management E va lu atio n ........................................................................................
3 .3-14 2Electrical Penetration Pressurization System Summary ofAging Management Evaluation
........................................................
3.3-148LaSalle County Station, Units 1 and 2License Renewal Application Page xi Table of ContentsTable 3.3.2-11Table 3.3.2-12Table 3.3.2-13Table 3.3.2-14Table 3.3.2-15Table 3.3.2-16Table 3.3.2-17Table 3.3.2-18Table 3.3.2-19Table 3.3.2-20Table 3.3.2-21Table 3.3.2-22Table 3.3.2-23Table 3.3.2-24Table 3.3.2-25Table 3.4.1Table 3.4.2-1Table 3.4.2-2Table 3.4.2-3Table 3.4.2-4Table 3.4.2-5Table 3.5.1Table 3.5.2-1Table 3.5.2-2Table 3.5.2-3Table 3.5.2-4Table 3.5.2-5Table 3.5.2-6Table 3.5.2-7Table 3.5.2-8Table 3.5.2-9Essential Cooling Water System Summary of AgingM anagem ent Evaluation
..................................................................
3.3-150Fire Protection System Summary of Aging Management E v a lu a tio n ........................................................................................
3 .3 -16 2Fuel Pool Cooling and Storage System Summary of AgingM anagem ent Evaluation
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3.3-172Nonessential Cooling Water System Summary of AgingM anagem ent Evaluation
..................................................................
3.3-178Nonsafety-Related Ventilation System Summary of AgingM anagem ent Evaluation
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3.3-187Plant Drainage System Summary of Aging Management E va luatio n ........................................................................................
3 .3-19 2Primary Containment Ventilation System Summary of AgingM anagem ent Evaluation
..................................................................
3.3-198Process Radiation Monitoring System Summary of AgingM anagem ent Evaluation
..................................................................
3.3-204Process Sampling and Post Accident Monitoring SystemSummary of Aging Management Evaluation
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3.3-209Radwaste System Summary of Aging Management Evaluation
...... 3.3-216Reactor Water Cleanup System Summary of AgingM anagem ent Evaluation
..................................................................
3.3-219Safety-Related Ventilation System Summary of AgingM anagem ent Evaluation
..................................................................
3.3-226Standby Liquid Control System Summary of AgingM anagem ent Evaluation
..................................................................
3.3-230Suppression Pool Cleanup System Summary of AgingM anagem ent Evaluation
..................................................................
3.3-236Traversing Incore Probe System Summary of AgingM anagem ent Evaluation
..................................................................
3.3-239Summary of Aging Management Evaluations for the Steamand Power Conversion System ..........................................................
3.4.11Condensate System Summary of Aging Management Evaluation
.... 3.4-30Condenser and Air Removal System Summary of AgingM anagem ent Evaluation
....................................................................
3.4-35Feedwater System Summary of Aging Management Evaluation
...... 3.4-38Main Steam System Summary of Aging Management Evaluation
..... 3.4-42Main Turbine and Auxiliaries System Summary of AgingManagement Evaluation
...............................
3.4-46Summary of Aging Management Evaluations for the Structures and C om ponent Supports
..................................................................
3.5-32Auxiliary Building Summary of Aging Management Evaluation
.........
3.5-73Component Supports Commodity Group Summary of AgingM anagem ent Evaluation
....................................................................
3.5-89Cooling Lake Summary of Aging Management Evaluation
..............
3.5-103Diesel Generator Building Summary of Aging Management E v a lu a tio n ........................................................................................
3 .5 -10 9Lake Screen House Summary of Aging Management Evaluation
... 3.5-121Offgas Building Summary of Aging Management Evaluation
..........
3.5-137Primary Containment Summary of Aging Management Evaluation.
3.5-146Radwaste Building Summary of Aging Management Evaluation
..... 3.5-176Reactor Building Summary of Aging Management Evaluation
........
3.5-187LaSalle County Station, Units 1 and 2License Renewal Application Page xii Table of ContentsTable 3.5.2-10Table 3.5.2-11Table 3.5.2-12Table 3.5.2-13Table 3.5.2-14Table 3.6.1Table 3.6.2-1Table 4.1-1Table 4.1-2Table 4.2.1-1Table 4.2.1-2Table 4.2.1-3Table 4.2.1-4Table 4.2.1-5Table 4.2.1-6Table 4.2.2-1Table 4.2.2-2Table 4.2.3-1Table 4.2.3-2Table 4.2.3-3Table 4.2.3-4Table 4.2.5-1Table 4.2.5-2Table 4.2.6-1Table 4.2.6-2Structural Commodity Group Summary of Aging Management E va lu atio n ........................................................................................
3 .5 -2 0 5Switchyard Structures Summary of Aging Management E va lu atio n ........................................................................................
3 .5 -2 17Tank Foundations and Dikes Summary of Aging Management E va lu atio n ........................................................................................
3 .5 -2 24Turbine Building Summary of Aging Management Evaluation
.........
3.5-227Yard Structures Summary of Aging Management Evaluation
..........
3.5-237Summary of Aging Management Programs for the Electrical C o m po ne nts .......................................................................................
3 .6 -12Electrical Commodities Summary of Aging Management E v a lu a tio n ..........................................................................................
3 .6 -2 1Generic TLAA Applicability to LSCS .......................................................
4-5Summary of Results -LSCS Time-Limited Aging Analysis
....................
4-6LSCS Unit 1 -Maximum Neutron Fluence (>1.0 MeV) in RPVBeltline Shell Plates at 54 EFPY (n/cm2) ..............................................
4-16LSCS Unit 1 -Maximum Neutron Fluence (>1.0 MeV) in RPVBeltline W elds at 54 EFPY (n/cm 2) .......................................................
4-17LSCS Unit 1 -Maximum Neutron Fluence (>1.0 MeV) in RPVBeltline Nozzles at 54 EFPY (n/cm 2) ....................................................
4-18LSCS Unit 2 -Maximum Neutron Fluence (>1.0 MeV) in RPVBeltline S hell Plates (n/cm 2) .................................................................
4-19LSCS Unit 2 -Maximum Neutron Fluence (>1.0 MeV) in RPVBeltline W elds at 54 EFPY (n/cm 2) .......................................................
4-20LSCS Unit 2 -Maximum Neutron Fluence (>1.0 MeV) in RPVBeltline and Welds Nozzles at 54 EFPY(n/cm2)
..................................
4-21LSCS Unit 1 -54 EFPY (60-Year)
Upper Shelf Energy (USE) .............
4-25LSCS Unit 2 -54 EFPY (60-Year)
Upper Shelf Energy (USE) .............
4-29LSCS Unit 1 54 EFPY Adjusted Reference Temperature (ART)Values for Beltline Plates and W elds ....................................................
4-35LSCS Unit 1 54 EFPY Adjusted Reference Temperature (ART)Values for Beltline Nozzles and Welds and Integrated Surveillance Program W elds .................................................................
4-38LSCS Unit 2 54 EFPY Adjusted Reference Temperature (ART)Values for Beltline Plates and W elds ....................................................
4-40LSCS Unit 2 54 EFPY Adjusted Reference Temperature (ART)Values for Beltline Nozzles and Welds and Integrated Surveillance Program W elds .................................................................
4-4 1Comparison of NRC 64 EFPY Axial Weld Failure Probability Assessment for CE (CEOG) RPV to LSCS Unit 1 54 EFPYAxial Weld Failure Probability Assessment
..........................................
4-45Comparison of NRC 64 EFPY Axial Weld Failure Probability Assessment for CB&I RPV to LSCS Unit 2 54 EFPY Axial WeldFailure Probability Assessm ent ............................................................
4-46Comparison of NRC 64 EFPY Circumferential Weld FailureProbability Assessment for CE (CEOG) RPV to LSCS Unit 154 EFPY Circumferential Weld Failure Probability Assessment
...........
4-49Comparison of NRC 64 EFPY Circumferential Weld FailureProbability Assessment for CB&I RPV to LSCS Unit 254 EFPY Circumferential Weld Failure Probability Assessment
...........
4-50LaSalle County Station, Units 1 and 2License Renewal Application Page xiii Table of ContentsTable 4.2.7-1Table 4.2.7-2Table 4.3.1-1Table 4.3.1-2Table 4.3.1-3Table 4.3.2-1Table 4.3.3-1Table 4.3.3-2Table 4.3.3-3Table 4.3.3-4Table 4.3.4-1Table 4.7.1-1List of FiguresFigure 2.1-1Figure 2.1-2Figure 4.2.1-1Figure 4.2.1-2Figure 4.2.2-1Figure 4.2.2-2Figure 4.2.7-1Figure 4.2.7-2Figure 4.5.1-1Figure 4.5.1-2Figure 4.5.1-3Figure 4.5.1-4Crack Stability Analysis for Beltline Shells During Main SteamL in e B re a k .......................................................................................
4 -5 3Crack Stability Analysis for Beltline Shells During Recirculation L ine B re a k ..............................................................................
4 -54LSCS Unit 1 Year Transient Cycle Projections
..............................
4-63LSCS Unit 2 Year Transient Cycle Projections
..............................
4-68RPV Components Exempt Per ASME Section III, N-415.1 ...................
4-73Stress Range Reduction Factors for ASME Section III, Class 2and 3 and ANSI B31.1 Piping ...............................................................
4-74LSCS Unit 1 (CE) Reactor Pressure Vessel (RPV)Environmental Fatigue Analysis Results ...............................................
4-80LSCS Unit 2 (CB&I) Reactor Pressure Vessel (RPV)Environmental Fatigue Analysis Results ...............................................
4-83LSCS Unit 1 -Class 1 Piping System Environmental FatigueA nalysis R esults ......................................................................
4-87LSCS Unit 2 Class 1 Piping System Environmental FatigueA nalysis R esults ...................................................................................
4-88Reactor Vessel Internals Fatigue Analyses
..........................................
4-90LSCS Unit 1 and LSCS Unit 2 Reactor Building Crane Load Cycles..
4-110LaSalle County Station Scoping and Screening Flowchart
..................
2.1-3LaSalle SBO Recovery Boundary
......................................................
2.1-14LSCS Unit 1 Combustion Engineering Reactor VesselB eltline C om ponents ............................................................................
4-14LSCS Unit 2 Chicago Bridge and Iron Reactor VesselB e ltline C om ponents .............................................................................
4-15N12 Water Level Instrumentation Nozzle Extraction Path ....................
4-23N6 LPCI Nozzle-to-Shell Weld and Nozzle ForgingE xtractio n P aths ....................................................................................
4 -2 3K vs. a/T for Recirculation Line Break at t = 480 Seconds ....................
4-55K vs. a/T for Recirculation Line Break at t = 1,200 Seconds ................
4-55LSCS Unit 1 Vertical Containment Tendon Lift-off Forces .............
.4-100LSCS Unit 2 Vertical Containment Tendon Lift-off Forces .............
.4-101LSCS Unit 1 Horizontal (Hoop) Tendon Lift-off Forces ......................
4-102LSCS Unit 2 Horizontal (Hoop) Tendon Lift-off Forces ......................
4-103LaSalle County Station, Units 1 and 2License Renewal Application Page xiv This Page Intentionally Left Blank0 Section 1 -Administrative Information 1.0 ADMINISTRATIVE INFORMATION 1.1 GENERAL INFORMATION
-10 CFR 54.191.1.1 NAME OF APPLICANT Exelon Generation
- Company, LLC (Exelon),
hereby applies for renewedoperating licenses for LaSalle County Station, Units 1 and 2 (LSCS).1.1.2 ADDRESS OF APPLICANT Exelon Generation
- Company, LLC200 Exelon WayKennett Square, PA 193481.1.3 DESCRIPTIONS OF BUSINESS OR OCCUPATION OF APPLICANT Exelon Generation
- 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.
ExelonGeneration
- Company, LLC is the licensed operator of LaSalle County Station,Units 1 and 2, which is the subject of this application.
The current LaSalleCounty Station, Units 1 and 2 operating licenses will expire as follows:o At midnight on April 17, 2022 for Unit 1 (Facility Operating LicenseNo. NPF-11).o At midnight December 16, 2023 for Unit 2 (Facility Operating LicenseNo. NPF-18).Exelon Generation
- Company, LLC will continue as the licensed operator on therenewed operating licenses.
1.1.4 DESCRIPTIONS OF ORGANIZATION AND MANAGEMENT OF APPLICANT Exelon Corporation is a corporation organized under the laws of theCommonwealth of Pennsylvania with its headquarters and principal place ofbusiness in Chicago, Illinois.
Exelon Corporation is a publicly traded corporation whose shares are widely traded on the New York Stock Exchange.
ExelonGeneration
- Company, LLC, is organized under the laws of the Commonwealth ofPennsylvania.
Exelon Generation
- Company, LLC does not have a board ofDirectors.
All of the Principal Officers of Exelon Generation
- Company, LLC areU.S. citizens.
Exelon Generation
- Company, LLC is not owned, controlled, ordominated by an alien, a foreign corporation, or a foreign government.
TheLaSalle County Station, Units 1 and 2License Renewal Application Page 1-1 Section 1 -Administrative Information Principal Officers of Exelon Generation
- Company, LLC, and their addresses, arepresented below:Princip al Officers (Exelon Generation
- Company, LLC)Name Title AddressPresident and CEO Exelon 200 Exelon WayGeneration Kennett Square, PA 19348Senior Vice President ExelonMichael J. Pacilio Generation; President and Chief W infied RoadNuclear Officer, Exelon Nuclear Warrenville, IL 60555Exelon Nuclear Chief Operating 4300 Winfield RoadOfficer Warrenville, IL 60555Senior Vice President Exelon 300 Exelon WayRonald J. DeGregorio Generation; President, Exelon Kennett Square, PA 19348PowerJohn F. Barnes Chief Operating
- Officer, Exelon 300 Exelon WayPower Kennett Square, PA 19348EVP, Exelon and CEO 111 Market Place, Baltimore, MDJoseph Nigro Constellation 21202111 Market Place, Baltimore, MDMark P. Huston President, Retail, 21202111 Market Place, Baltimore, MDEdward J Quinn President, Wholesale 21202111 Market Place, Baltimore, MDBryan P. Wright Chief Financial Officer 120221202Paymon Aliabadi Chief Enterprise Risk Officer 10 S. Dearborn St, Chicago, IL606031.1.5 CLASS OF LICENSE, USE OF THE FACILITY, WHICH THE LICENSE IS SOUGHTAND PERIOD OF TIME FORExelon Generation
- Company, LLC requests renewal of the Class 103 operating licenses for LaSalle County Station, Units 1 and 2, for a period of 20 yearsbeyond the expiration of the current licenses to allow continued use of thefacilities 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 renewalof specific licenses under 10 CFR Parts 30, 40, and 70 that are subsumed in orcombined with the current operating licenses.
1.1.6 EARLIEST AND LATEST DATES FOR ALTERATIONS, IF PROPOSEDNo physical plant alterations or modifications have been identified as necessary in connection with this application.
LaSalle County Station, Units 1 and 2License Renewal Application Page 1-2 Section 1 -Administrative Information 1.1.7 RESTRICTED DATAWith regard to the requirements of 10 CFR 54.17(f),
this application does notcontain any "Restricted Data," as that term is defined in the Atomic Energy Actof 1954, as amended, or other defense information, and it is not expected thatany such information will be part of the licensed activities.
In accordance with the requirements of 10 CFR 54.17(g),
the applicant will notpermit any individual to have access to, or any facility to possess restricted dataor classified national security information until the individual and/or facility hasbeen approved for such access under the provisions of 10 CFR Parts 25 and/or95.1.1.8 REGULATORY AGENCIESExelon Generation
- Company, LLC recovers its share of the costs incurred fromoperating LaSalle County Station, Units 1 and 2, in its own wholesale rates.The rates charged and services provided by Exelon Generation
- Company, LLCare subject to regulation by the Federal Energy Regulatory Commission underthe Federal Power Act. Exelon Generation
- Company, LLC is also subject toregulation as a public utility company by the Securities and ExchangeCommission under the Public Utility Holding Company Act of 1935, asamended.Securities and Exchange Commission 450 Fifth Street, NWWashington, DC 20549Federal Energy Regulatory Commission 888 First St. N.E.Washington, DC 204261.1.9 LOCAL NEWS PUBLICATIONS News publications in circulation near LaSalle County Station, Units 1 and 2 thatare considered appropriate to give reasonable notice of the application are asfollows:The Times110 W. Jefferson St.Ottawa, IL 61350The News Tribune426 Second St.LaSalle, IL 61301The Morris Daily Herald1804 N. Division St.Morris, IL 60450LaSalle County Station, Units 1 and 2License 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, toaccount for the expiration term of the proposed renewed license."
The currentindemnity 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 isthe last to expire; provided that, except as may otherwise be provided inapplicable regulations or orders of the Commission, the term of this agreement shall not terminate until all the radioactive material has been removed from thelocation and transportation of the radioactive material from the location hasended as defined in subparagraph 5(b), Article f'. Item 3 of the Attachment tothe indemnity agreement includes license numbers NPF-1 1 and NPF-1 8.Applicant requests that any necessary conforming changes be made to ArticleVII and Item 3 of the Attachment, and any other sections of the indemnity agreement as appropriate to ensure that the indemnity agreement continues toapply during both the terms of the current licenses and the terms of therenewed 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 2License Renewal Application Page 1-4 Section 1 -Administrative Information 1.2 GENERAL LICENSE INFORMATION 1.2.1 APPLICATION
- UPDATES, RENEWED LICENSES, AND RENEWAL TERMOPERATION In accordance with 10 CFR 54.21(b),
during NRC review of this application, anannual update to the application to reflect any change to the current licensing basis that materially affects the contents of the license renewal application willbe provided.
In accordance with 10 CFR 54.21(d),
Exelon Generation
- Company, LLC willmaintain a summary list in the LSCS Updated Final Safety Analysis Report(UFSAR) of activities that are required to manage the effects of aging for thesystems, structures or components in the scope of license renewal during theperiod of extended operation and summaries of the time-limited aging analysesevaluations.
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 forinformation only.1.2.3 CONTACT INFORMATION Any notices, questions, or correspondence in connection with this filing shouldbe directed to:Michael P. Gallagher Vice President License Renewal ProjectsExelon Generation
- Company, LLC200 Exelon WayKennett Square, PA 19348with copies to:Albert A. FulvioManager License RenewalExelon Nuclear200 Exelon WayKennett Square, PA 19348Shannon Rafferty-Czincila License Renewal Project Technical LeadExelon Nuclear200 Exelon WayKennett Square, PA 19348LaSalle County Station, Units 1 and 2License Renewal Application Page 1-5 Section 1 -Administrative Information 1.3 PURPOSEThis document provides information required by 10 CFR 54 to support theapplication for renewed licenses for LaSalle County Station Units 1 and 2. Theapplication contains technical information required by 10 CFR 54.21 andenvironmental information required by 10 CFR 54.23. The information contained herein is intended to provide the NRC with an adequate basis tomake the findings required by 10 CFR 54.29.1.4 DESCRIPTION OF THE PLANTThe LaSalle County Station, Units 1 and 2 is a dual unit facility located in theagricultural area of Brookfield
- Township, LaSalle County, Illinois.
It isapproximately 55 direct-line miles southwest of Chicago.
The plant is on flatterrain about 220 feet above the Illinois River channel which traverses northcentral Illinois some 3.5 miles to the north of the site.The power generation complex includes several contiguous buildings, twoReactor buildings, an Auxiliary building (housing the control room), the Turbinebuilding, Diesel-Generator buildings, the Radwaste
- building, the Servicebuilding, and the Offgas building.
Other buildings such as the gatehouse, warehouses, etc., are also located in the general plant area. A lake screenhouse on the intake flume is located about 800 feet east of the main buildingcomplex.
A small river screen house, located on the Illinois River, providesmakeup water to the cooling lake for the LaSalle County Station.The nuclear reactor system for each LSCS unit includes a single-cycle, forcedcirculation, General Electric boiling-water reactor (GE BWR Type 5). Both unitswere approved for a 5% stretch power uprate on May 9 of 2000 followed by a1.65% Measurement Uncertainty Recapture (MUR) power uprate on September 16, 2010. Each LSCS unit reactor is currently licensed to a rated core thermalpower of 3546 MWt and is housed within GE Mark II (wet) containment.
Normalheat sink cooling for the station is provided from a perched cooling lake of 2058acres. The ultimate heat sink for emergency core cooling is a submerged pondand intake flume that underlies the cooling lake and the natural grade of thesite. The gross electric output of each unit is approximately 1207 MWe and thenet 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 NuclearPlant 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 2License Renewal Application Page 1-6 Section 1 -Administrative Information Aging Management Programs and activities are structured to address theguidance provided in NUREG-1 800, "Standard Review Plan for Review ofLicense 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 theadequacy of existing programs for purposes of managing aging and whichexisting programs should be augmented for license renewal.
The results of theaging management review, using NUREG-1801, have been documented andare 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 54.17and 10 CFR 54.19. It describes the plant and states the purpose for thisapplication.
Included in this section are the names, addresses, businessdescriptions, and organization and management descriptions of the applicant, as well as other administrative information.
This section also provides anoverview of the structure of the application, general references, and a listing ofacronyms used throughout the application.
Section 2 -Structures and Components Subject To Aging Management ReviewThis section describes and justifies the methods used in the integrated plantassessment to identify those structures and components subject to an agingmanagement review in accordance with the requirements of10 CFR 54.21 (a)(2). These methods consist of: 1) scoping, which identifies thesystems, structures, and components that are within the scope of10 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 functionwithout moving parts or a change in configuration or properties, and that are notsubject 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 andstructural components that require aging management review. Briefdescriptions of mechanical systems and structures within the scope of licenserenewal are provided as background information.
Mechanical system andstructure intended functions are provided for in scope systems andstructures.
For each in scope system and structure, components requiring anaging management review are identified, associated component intendedfunctions are identified, and appropriate reference to the Section 3 Tableproviding the aging management review results is made.Electrical components and selected structural components, such as electrical cables and component
- supports, respectively, were evaluated asLaSalle County Station, Units 1 and 2License 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 anaging 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 Results10 CFR 54.21 (a)(3) requires a demonstration that the effects of aging will beadequately managed so that the intended functions will be maintained consistent with the current licensing basis throughout the period of extendedoperation.
Section 3 presents the results of the aging management reviews.Section 3 is the link between the scoping and screening results provided inSection 2 and the aging management programs provided in Appendix B.Aging management review results are presented in tabular form, in a format inaccordance with NUREG-1 800, "Standard Review Plan for Review of LicenseRenewal Applications."
For mechanical
- systems, aging management reviewresults 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.
Agingmanagement review results for containments, structures, and component supports are provided in Section 3.5. Aging management review results forelectrical 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, andinformation regarding the degree to which the proposed aging management programs are consistent with those recommended in NUREG-1 801.Section 4 -Time-Limited Aging AnalysesTime-limited aging analyses (TLAAs),
as defined by 10 CFR 54.3 are listed inthis section.
This section includes each of the TLAAs identified in the NRCStandard Review Plan for License Renewal Applications and in LSCSplant-specific analyses.
This section includes a summary of the time-dependent aspects of the analyses.
A demonstration is provided to show that the analysesremain valid for the period of extended operation, the analyses have beenprojected to the end of the period of extended operation, or the effects of agingon the intended function(s) will be adequately managed for the period ofextended 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 managingthe effects of aging for the period of extended operation.
In addition, summarydescriptions of time-limited aging analyses evaluations are provided.
Table3.0-1, "FSAR Supplement for Aging Management of Applicable Systems,"
fromRevision 2 of NUREG-1 800 was used as guidance for the content of theapplicable aging management program summaries.
LaSalle County Station, Units 1 and 2License Renewal Application Page 1-8 Section 1 -Administrative Information Appendix B -Aging Management ProgramsAppendix B describes the programs and activities that are credited formanaging aging effects for components or structures during the period ofextended operation based upon the aging management review results providedin 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 XIand Section X, respectively, of NUREG-1801.
A description of the agingmanagement program is provided and a conclusion is drawn based upon theresults of an evaluation to each of the ten elements provided in NUREG-1801.
In some cases, exceptions and justifications for managing aging are providedfor specific NUREG-1 801 elements.
Additionally, operating experience relatedto the aging management program is provided.
Appendix C -Response to BWRVIP License Renewal Applicant ActionItemsThis Appendix provides the requested responses to applicant action itemscontained in the NRC safety evaluation reports associated with NRC approvedBoiling Water Reactor Vessel and Internals Program reports.Appendix D -Technical Specification ChangesThis Appendix satisfies the requirement in 10 CFR 54.22 to identify technical specification changes or additions necessary to manage the effects of agingduring the period of extended operation.
There were no Technical Specification Changes identified necessary to manage the effects of aging during the periodof extended operation.
Appendix E -Environmental Information
-LaSalle County Station Units 1and 2This Appendix satisfies the requirements of 10 CFR 54.23 to provide asupplement to the environmental report that complies with the requirements ofsubpart A of 10 CFR Part 51 for LaSalle County Station Units 1 and 2.LaSalle County Station, Units 1 and 2License Renewal Application Page 1-9 Section 1 -Administrative Information 1.6 ACRONYMSAcronym MeaningAC Alternating CurrentACI American Concrete Institute AMP Aging Management ProgramAMR Aging Management ReviewANL 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 scramBTP Branch Technical PositionBWR Boiling Water ReactorBWRVIP Boiling Water Reactor Vessels and Internals ProjectC (-C) Degrees CelsiusCASS Cast austenitic stainless steelCFR Code of Federal Regulations CLB Current licensing basisCUF Cumulative Usage FatigueCUFen Environmentally Adjusted Cumulative Usage FactorDBA Design basis accidentDBD Design basis documentDBE Design basis eventDC Direct CurrentDO Dissolved OxygenDORL Division of Operating Reactors Licensing DOT Department of Transportation EAF Environmentally-Assisted FatigueECCS Emergency Core Cooling SystemECT Eddy Current TestingEDG Emergency Diesel Generator EFPY Effective full-power yearsEPRI Electric Power Research Institute LaSalle County Station, Units 1 and 2License Renewal Application Page 1-10 Section 1 -Administrative Information Acronym MeaningEPA Environmental Protection AgencyEPU Extended Power UprateEQ Environmental Qualification ESF Engineered Safety FeaturesF (TF) Degrees Fahrenheit FAC Flow-accelerated corrosion Fen Environmentally Assisted Fatigue Correction FactorFHAR Fire Hazards Analysis ReportFHS Fuel Handling and Storage SystemFSAR Final Safety Analysis ReportFSSD Fire safe shutdownGALL Generic Aging Lessons Learned Report NUREG 1801GL Generic LetterGSI GSI Generic Safety IssueHELB High energy line breakHEPA High efficiency particulate airHVAC Heating, ventilation, and air conditioning HX Heat exchanger I & C Instrumentation and controlsIASCC Irradiation assisted stress corrosion crackingIEEE Institute of Electrical and Electronics Engineers IGA Intergranular AttackIGSCC Intergranular stress corrosion crackingIN Information NoticeINPO Institute of Nuclear Power Operations IPA Integrated plant assessment ISI Inservice inspection ISG Interim Staff GuidanceIST Inservice testingLBB Leak before breakLER Licensee event reportLSCS LaSalle County Station, Units 1 and 2LLRT Local leak rate testLOCA Loss-of-coolant accidentLRA License Renewal Application LaSalle County Station, Units 1 and 2License Renewal Application Page 1-11 Section 1 -Administrative Information Acronym MeaningLTOP Low Temperature Overpressure Protection MCC Motor control centerMEAP Material/Environment/Aging affect/Program assummarized on AMR line-items MG Motor generator MIC Microbiologically influenced corrosion MOV Motor-operated valveMSIV Main steam isolation valveMSIP Mechanical Stress Improvement ProcessMSV Main stop valveMSRV Main Steam Relief ValveMUR 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 SizeNRC Nuclear Regulatory Commission NRR Office of Nuclear Reactor Regulation NSR Nonsafety-Related OE Operating experience P&ID Piping and instrumentation diagramPM Preventive maintenance PTS Pressurized Thermal ShockP-T curves Pressure-temperature limit curvesPUA Plant-unique analysesPWR Pressurized Water ReactorRCPB Reactor coolant pressure boundaryRCS Reactor Coolant SystemRG Regulatory guideRPS Reactor protection systemRTNDT nil-ductility transition reference temperature RPV Reactor Pressure VesselRW Radwaste SystemsLaSalle County Station, Units 1 and 2License Renewal Application Page 1-12 Section 1 -Administrative Information AcronymSBOSCCSSCSRSRVSSCsSSETLAAsUFSARUHSUSEMeaningStation BlackoutStress corrosion crackingSystems Structures and Components Safety-Related Safety Related Ventilation SystemSystems, structures, and components Safe shutdown earthquake Time-limited aging analysesUpdated Final Safety Analysis ReportUltimate heat sinkUpper-shelf energyLaSalle County Station, Units 1 and 2License 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 NuclearPower Plants."1.7.2 NEI 95-10, "Industry Guidelines for Implementing the Requirements of 10 CFRPart 54 -The License Renewal Rule," Revision 6, June 2005.1.7.3 Regulatory Guide 1.188, "Standard Format and Content for Applications toRenew Nuclear Power Plant Operating Licenses,"
Revision 1.1.7.4 NUREG-1 800, "Standard Review Plan for Review of License RenewalApplications for Nuclear Power Plants" United States Nuclear Regulatory Commission, Revision 2.1.7.5 NUREG-1 801, "Generic Aging Lessons Learned (GALL) Report,"
United StatesNuclear 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 toSafety 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 Plantsand Fuel Reprocessing Plants."1.7.12 10 CFR 51, "Environmental Protection Regulations for Domestic Licensing andRelated 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 toEPRI 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 2License Renewal Application Page 1-14 Section 1 -Administrative Information 1.7.18 NEI 05-01, "Severe Accident Mitigation Alternatives (SAMA) Analysis GuidanceDocument, Revision A, November 2005.LaSalle County Station, Units 1 and 2License Renewal Application Page 1-15 This Page Intentionally Left Blank Section 2 -Scoping and Screening Methodology and Results2.0 SCOPING AND SCREENING METHODOLOGY FORIDENTIFYING STRUCTURES AND COMPONENTS SUBJECTTO AGING MANAGEMENT REVIEW, ANDIMPLEMENTATION RESULTSThis 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, andcomponents (SSCs) within the scope of license renewal, 10 CFR 54.21 (a)(1)requires the license renewal applicant to identify and list those structures andcomponents subject to Aging Management Review (AMR). 10 CFR 54.21(a)(2) further requires that the methods used to implement the requirements of10 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 ofidentifying the plant systems and structures that are to be included within thescope of license renewal in accordance with 10 CFR 54.4. The intendedfunctions that are the bases for including the systems and structures within thescope of license renewal are also identified during the scoping process.Screening is the process of determining which components associated with the inscope systems and structures are subject to an aging management review inaccordance with 10 CFR 54.21 (a)(1) requirements.
A detailed description of theLSCS 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 thescope of license renewal in Section 2.2. The screening results identifycomponents 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 2.0-1License Renewal Application This Page Intentionally Left Blank Section 2 -Scoping and Screening Methodology and Results2.1 SCOPING AND SCREENING METHODOLOGY 2.
1.1 INTRODUCTION
This introduction provides an overview of the scoping and screening processused at LSCS. Subsequent sections provide details of how the process wasimplemented.
The initial step in the scoping process was to define the entire plant in terms ofsystems 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 asafety-related
- function, or if the system or structure performs functions thatdemonstrate compliance with the requirement of one of the five license renewalregulated 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 anyportion 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 furtherevaluated to determine those system components that are required to perform orsupport the identified system intended function(s).
The in scope boundaries ofmechanical systems were identified and are described in Section 2.3. Theseboundaries 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. Inscope 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 licenserenewal regulated events are shown highlighted in green. Nonsafety-related mechanical components that are included within the scope of license renewalbecause they provide structural support to safety-related SSCs are shownhighlighted in red. Nonsafety-related mechanical components that are includedwithin the scope of license renewal because component failure could prevent theaccomplishment of a safety-related function due to potential spatial interaction with safety-related SSCs are shown highlighted in red. Additional details onscoping evaluations and boundary drawing development are provided in Section2.1.5.A structure was included within the scope of license renewal if any portion of thestructure met the scoping criteria of 10 CFR 54.4. Structures were then furtherevaluated to determine those structural components that are required to performor support the identified structure intended function(s).
The portions of eachstructure within the scope of license renewal that are required to perform orsupport the identified structure intended function(s) were identified and aredescribed in Section 2.4. The structures that are within the scope of licenseLaSalle County Station, Units 1 and 2 Page 2.1-1License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsrenewal are highlighted in green on the site plan. Additional details on scopingevaluations and boundary drawing development are provided in Section 2.1.5.Electrical and Instrumentation and Control (I&C) systems were scoped likemechanical 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 wereincluded within the scope of license renewal.
Consequently, further systemevaluations to determine which electrical components were required to performor support the system intended functions were not performed during the scopingprocess.
Additional details on electrical and I&C system scoping are provided inSection 2.1.5.After completion of the scoping and boundary evaluations, the screening processwas performed to evaluate the structures and components within the scope oflicense renewal to identify the long-lived and passive structures and components subject to an Aging Management Review (AMR). In addition, the passiveintended 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 werenot evaluated with the individual system or structure, but were evaluated collectively as a commodity group. Commodity groups are identified in Table2.2-1. Passive structural commodities are identified in Section 2.4, and passiveelectrical commodities are identified in Section 2.5. Commodity groups utilizedare consistent with NUREG-1 800, Table 2.1-5, and previous license renewalapplications accepted by the NRC.Figure 2.1-1 provides a flowchart of the general scoping and screening processfor mechanical
- systems, structures, and electrical systems.0LaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-2 Section 2 -Scoping and Screening Methodology and ResultsFigure 2.1-1LaSalle County Station Scoping and Screening Flowchart SCOPING:
Each system and structure is processed through both paths.LaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-3 Section 2 -Scoping and Screening Methodology and Results2.1.2 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 LSCSis consistent with the definition provided in 10 CFR 54.4. The significant sourcedocumentation is discussed below.These source documents are available in hard copy or electronic format.Document records such as licensing correspondence and NRC SafetyEvaluation 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 ReportThe LSCS UFSAR follows the established guidelines published in NUREG-0800, "Standard Review Plan for the Review of Safety Analysis Reports forNuclear Power Plants,"
dated July 1981. The LSCS UFSAR has since beenupdated 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 ReportThe Fire Protection Report (FPR) describes the fire protection configuration forthe confinement, detection, and suppression of fires, and demonstrates thecapability to achieve and maintain safe shutdown conditions in the event of afire, in support of the Fire Protection Program functions.
2.1.2.3 Environmental Qualification Master ListThe scope of the electrical equipment and components that must beenvironmentally qualified for use in a harsh environment at LSCS is identified in the Passport equipment database.
The Passport equipment database isdiscussed in Section 2.1.2.6.
The database includes a listing of equipment andcomponents, and includes fields that identify specific equipment information such as manufacturer, plant location, and qualification level. The Passportequipment database Environmental Qualification (EQ) data field is amandatory and design basis field, which means that the field must bepopulated and that the data is controlled and has been verified accurate.
2.1.2.4 Maintenance Rule DatabaseThe Maintenance Rule Database documents the results of Maintenance Rulescoping for LSCS systems and structures.
The Maintenance Rule Databaseprovided an additional source of information to identify system and structure functions.
LaSalle County Station, Units 1 and 2 Page 2.1-4License Renewal Application Section 2 -Scoping and Screening Methodology and Results2.1.2.5 Engineerina DrawingsEngineering drawings at LSCS provide system, structure, and component configuration details and safety classification information.
These drawingswere utilized to determine SSC functional requirements and materials ofconstruction in support of scoping and screening evaluations.
2.1.2.6 Controlled Plant Component DatabaseLSCS maintains a controlled plant component database that containscomponent 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 discretemaintenance or modification activities typically are performed.
The Passportequipment database provides a comprehensive listing of plant components and their quality classifications.
Unique equipment component tag numbersidentify 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 licenseecommitments.
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 renewalproject.
Engineers experienced in nuclear plant systems,
- programs, andoperations prepared the basis documents.
Basis documents contain technical evaluations and bases for decisions or positions associated with license renewalrequirements as described below. Basis documents are prepared,
- reviewed, andapproved in accordance with controlled project procedures, and are based on theCLB source documents described in Section 2.1.2.The following sections describe the technical basis documents associated withthe LSCS scoping and screening methodology.
2.1.3.1 License Renewal Systems and Structures ListOne of the first steps necessary to begin the license renewal scoping processwas to identify a comprehensive list of systems and structures to be evaluated for license renewal scoping.
While there exists a variety of document sourcesLaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-5 Section 2 -Scoping and Screening Methodology and Resultsthat identify and list systems and structures at LSCS, no single sourceprovided the comprehensive list in a format appropriate for 10 CFR 54.4license renewal system and structure scoping.
Therefore, a basis documentwas prepared to establish a comprehensive list of license renewal systems andstructures, and to document the basis for the list. Starting with the systemsand structures list contained in the Passport equipment
- database, the list wasevaluated 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 documentassures all plant structures and components included in the scoping review areassociated with a system, structure, or commodity group.The basis document grouped license renewal systems and structures into thefollowing categories:
- Reactor Vessel, Internals, and Reactor Coolant System* Engineered Safety Features* Auxiliary Systems* Steam and Power Conversion System* Electrical Components
- Structures and Component SupportsThis grouping of the LSCS license renewal systems and structures is based onthe LSCS UFSAR and the guidance of NUREG-1 801 "Generic Aging LessonsLearned (GALL) Report,"
Revision 2 (reference 1.7.5). The complete list ofsystems, structures, and commodity groups evaluated for license renewal isprovided in Section 2.2 of this application.
Certain structures and equipment were excluded at the outset because theyare not considered to be systems, structures, or components that are part ofthe CLB and do not have design or functional requirements related to the10 CFR 54.4(a)(1),
(a)(2), or (a)(3) scoping criteria.
These include:
driveways and parking lots, temporary equipment, health physics equipment, portablemeasuring 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 licenserenewal in accordance with 10 CFR 54.4(a)(1) scoping criterion.
LSCS plantsystems 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" scopingcriterion in 10 CFR 54.4(a)(1),
to confirm that LSCS safety-related classifications are consistent with license renewal requirements.
This review isincluded in a technical basis document.
The basis document also provides asummary list of the systems and structures that are safety-related at LSCS.LaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-6 Section 2 -Scoping and Screening Methodology and ResultsThese systems and structures are included within the scope of license renewalin 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 toassure:* The integrity of the reactor coolant pressure
- boundary,
- The capability to shut down the reactor and maintain it in a safeshutdown condition, or" The capability to prevent or mitigate the consequences ofaccidents which could result in potential offsite exposures inexcess of the guideline exposures of 10 CFR 100 or 10 CFR50.67 as applicable.
This definition is consistent with 10 CFR 54.4(a)(1) for the purposes of licenserenewal scoping.
The wording differences are addressed as follows:Design Basis EventsThe LSCS UFSAR definition of safety-related does not specifically refer todesign basis events, while 10 CFR 54.4(a)(1) refers to design basis events asdefined in 10 CFR 50.49(b)(1).
For LSCS license renewal, an additional technical basis document was prepared to confirm that all applicable designbasis events were considered.
The basis document includes a review of allsystems or structures that are relied upon to remain functional during andfollowing design-basis events as defined in 10 CFR 50.49 (b)(1). This includesconfirming that design basis internal and external events including DesignBasis Accidents (DBAs), Anticipated Operational Transients, AbnormalOperational Transients, and natural phenomena as described in the currentlicensing 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 with10 CFR 54.4(a)(1).
Nonsafety-related systems and structures required tosupport 10 CFR 54.4(a)(1) functions are included within the scope of licenserenewal in accordance with 10 CFR 54.4(a)(2).
Exposure LimitsThe license renewal rule refers to exposure limits as defined in10 CFR 50.34(a)(1),
or 10 CFR 100.11, as applicable.
These different exposure limit requirements appear in three different Codesections to address similar accident analyses performed by licensees fordifferent reasons.
The exposure limit requirements in 10 CFR 50.34(a)(1) areapplicable to facilities seeking a construction permit, and are, therefore, notapplicable to LSCS license renewal.
The exposure limit requirements in10 CFR 50.67(b)(2) are applicable to facilities seeking to revise the currentaccident source term used in their design basis radiological analyses.
LaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-7 Section 2 -Scoping and Screening Methodology and ResultsThe original UFSAR Chapter 15 Accident Analyses were performed to address10 CFR 100 guidelines.
In support of a full scope implementation ofAlternative Source Term (AST) methodology in accordance with Regulatory Guide 1.183, AST radiological consequence analyses were performed for thedesign basis accidents that result in offsite exposures.
The Loss-of-Coolant Accident and the Fuel Handling Accident were analyzed.
The doseconsequences for these limiting design basis accidents result in doses that arewithin 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 comprisethe design basis for the LaSalle design basis accidents.
When supplemented with the broad review of CLB design basis events, theLSCS UFSAR definition of "safety-related" is consistent with10 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 theapplication of the 10 CFR 54.4(a)(1) scoping criterion is provided in Section2.1.5.1.2.1.3.3 10 CFR 54.4(a)(2)
Scoping CriteriaAll nonsafety-related
- systems, structures, and components whose failure couldprevent satisfactory accomplishment of any of the functions identified in10 CFR 54.4(a)(1),
were included within the scope of license renewal inaccordance with 10 CFR 54.4(a)(2) requirements.
To assure complete andconsistent application of this scoping criterion, a technical basis document wasprepared.
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 supportfor a safety-related SSC.3. Nonsafety-related systems with a potential for spatial interaction withsafety-related SSCs.The first item is addressed during the scoping process, by identifying thenonsafety-related systems and structures required to functionally support theaccomplishment of a safety-related intended function under 10 CFR 54.4(a)(1),
and then including these supporting systems and structures in scope of licenserenewal 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, andcomponents.
Scoping of these systems is the subject of NEI 95-10,Appendix F. To assure complete and consistent application of10 CFR 54.4(a)(2) requirements and NEI 95-10, a technical basis documentLaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-8 Section 2 -Scoping and Screening Methodology and Resultswas 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 assurethat license renewal scoping for 10 CFR 54.4(a)(2) met the requirements of thelicense renewal rule and NEI 95-10. Additional detail on the application of the10 CFR 54.4(a)(2) scoping criterion is provided in Section 2.1.5.2.2.1.3.4 Scoping for Regulated EventsTechnical basis documents were prepared to address license renewal scopingof SSCs relied on in safety analyses or plant evaluations to perform a functionthat demonstrates compliance with the Commission's regulations for FireProtection, Environmental Qualification, Anticipated Transients Without Scram,and Station Blackout.
The Commission's regulations for pressurized thermalshock are not applicable to the LSCS boiling water reactor design. Thesebasis documents are summarized below:Fire Protection
- Systems, structures, and components relied on in safety analyses or plantevaluations to perform a function that demonstrates compliance with theCommission's regulations for fire protection (10 CFR 50.48) are included withinthe 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 tocomply with the requirements of 10 CFR 50.48 includes:
" Systems and structures required to demonstrate post-fire safe shutdowncapabilities
" 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 ofsafety-related equipment, and also includes fire protection
- systems, structures, and components needed to minimize the effects of a fire and to prevent therelease of radioactive material to the environment.
Fire protection system andstructure scoping for LSCS is performed consistent with this guidance, and isdocumented in the technical basis document.
The fire protection technical basis document summarizes results of a detailedreview of the plant's fire protection program documents that demonstrate compliance with the requirements of 10 CFR 50.48. The basis documentprovides a list of systems and structures credited in the plant's fire protection program documents.
For the listed systems and structures, the basisdocument also identifies appropriate CLB references.
The identified systemsLaSalle County Station, Units 1 and 2 Page 2.1-9License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsand 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 systemsthat protect a wide variety of plant equipment.
Not all portions of thesesystems are required to demonstrate compliance with 10 CFR 50.48. Someportions of the fire detection and suppression systems protect plant areas inwhich a fire would not impact any equipment important to safety or significantly increase the risk of radioactive releases to the environment.
Portions of thefire suppression and detection systems are not included within the scope oflicense renewal if (1) those portions of the system are provided to protect areasthat do not contain any SSCs within the scope of license renewal and (2) thoseportions of the system can be isolated from the in scope portions of thesystem. The portions of the fire suppression and detection systems that arenot included within the scope of license renewal are identified in the systemscoping document.
Those portions of fire detection and suppression systemsthat are not included in scope can be isolated from the remaining in scopesystem by closing the associated isolation valve. The isolation valve isincluded within the scope of license renewal.Environmental Qualification Criterion 10 CFR 54.4(a)(3) requires that all systems, structures, andcomponents relied on in safety analyses or plant evaluations to perform afunction that demonstrates compliance with the Commission's regulations forenvironmental qualification (10 CFR 50.49) be included within the scope oflicense renewal.The LSCS Environmental Qualification (EQ) program includes
- 1) safety-related electrical equipment,
- 2) nonsafety-related electrical equipment whose failureunder postulated environmental conditions could prevent the accomplishment of safety functions, and 3) certain post-accident monitoring equipment, asdefined in 10 CFR 50.49(b)(1),
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 areview of LSCS EQ program documents.
The EQ basis document provides alist of systems that include EQ components.
The EQ basis document alsoprovides a list of structures that provide the physical boundaries for thepostulated harsh environments, and contain environmentally qualified electrical equipment.
These systems and structures are included within the scope oflicense renewal in accordance with 10 CFR 54.4(a)(3) scoping criteria.
Anticipated Transients Without ScramCriterion 10 CFR 54.4(a)(3) requires that all systems, structures, andcomponents relied on in safety analyses or plant evaluations to perform afunction that demonstrates compliance with the Commission's regulations foranticipated transients without scram (10 CFR 50.62) be included within thescope of license renewal.LaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-10 Section 2 -Scoping and Screening Methodology and ResultsAn Anticipated Transient Without Scram (ATWS) is an anticipated operational occurrence that generates an automatic scram signal, accompanied by afailure of the reactor protection system to automatically shutdown the reactor.The ATWS rule (10 CFR 50.62) requires improvements in the design andoperation of light-water cooled water reactors to reduce the likelihood of failureto automatically shutdown the reactor, and to mitigate the consequences of anATWS event. LSCS Unit 1 and Unit 2 are boiling water reactors.
For boilingwater reactors (BWR), the following requirements apply:1. Each BWR must have an alternate rod injection (ARI) system withredundant scram air header exhaust valves. The ARI system must beindependent of the existing reactor trip system.2. Each BWR must have a standby liquid control system with definedboron injection capabilities.
Standby liquid control system automatic initiation is not required for plants issued a construction permit beforeJuly 26, 1984, unless already installed.
- 3. Each BWR must have equipment to trip the recirculation pumpsautomatically under conditions indicative of an ATWS.The ATWS basis document summarizes the results of a review of the LSCScurrent licensing basis with respect to ATWS. The LSCS design features tomeet the requirements of 10 CFR 50.62 for ATWS mitigation include:* Alternate Rod Insertion (ARI) system features to satisfy therequirements of 10 CFR 50.62 (c)(3). The ARI plant system isincluded in the License Renewal Reactivity Control system." Standby Liquid Control (SLC) system to meet the requirements of 10CFR 50.62 (c)(4)." ATWS Recirculation Pump Trip (RPT) system to satisfy therequirements of 10 CFR 50.62 (c)(5).The ATWS basis document provides a list of the systems required by10 CFR 50.62 to reduce the risk from ATWS events. The basis document alsoprovides a list of structures that provide physical support and protection for theATWS systems.
These systems and structures are included within the scopeof license renewal in accordance with 10 CFR 54.4(a)(3) scoping criteria.
Station BlackoutCriterion 10 CFR 54.4(a)(3) requires that all systems, structures, andcomponents relied upon in safety analyses or plant evaluations to perform afunction that demonstrates compliance with the Commission's regulations forstation blackout (10 CFR 50.63) be included within the scope of licenserenewal.LaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-11 Section 2 -Scoping and Screening Methodology and ResultsA station blackout (SBO) event is a complete loss of alternating current (AC)electric power to the essential and nonessential switchgear buses in a nuclearpower plant (i.e., loss of the offsite electric power system concurrent withgenerator trip and unavailability of the onsite emergency AC power sources).
SBO does not include the loss of available AC power to buses fed by stationbatteries through inverters or by alternate AC sources, nor does it assume aconcurrent 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 thatdemonstrate compliance with 10 CFR 50.63 are documented in the UFSARSection 15.9 and in NRC safety evaluation reports and correspondence relatedto the SBO rule.The NUREG-1 800 guidance on scoping of equipment relied on to meet therequirements of the SBO rule (10 CFR 50.63) for license renewal has beenincorporated into the LSCS scoping methodology.
In accordance with theNUREG-1 800 requirements, the SSCs required to recover from the SBO eventare included within the scope of license renewal.
Recovery is defined as therepowering of the plant AC distribution system from offsite sources or onsiteemergency AC sources.For LSCS, the boundary between the offsite transmission system and the plantelectrical distribution system has been defined at four 345 kV switchyard circuitbreakers:
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 licenserenewal, NUREG-1800, section 2.5.2.1.1 for the boundary for the StationBlackout recovery path. The NUREG states that the in scope plant systemportion of the offsite power system that is used to connect to the offsite powersource is the equipment out to the first circuit breaker with the offsitedistribution system. This typically includes equipment in the switchyard.
Thebreaker control circuits and the structures associated with these breakers andthe switchyard relay house are also in scope for license renewal.
See Figure2.1-2 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 thepreferred (and alternate for Division 1 and Division
- 2) power sources for LSCSsafety-related loads. Two physically independent circuits are provided for eachunit, one via the unit's assigned system auxiliary transformer, and the otherfrom 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 anexample, the 4160 V safety-related switchgear source power paths from thenormal offsite source from the 345 kV transmission system, and, from thealternate 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 2License 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 1System Auxiliary Transformer 142 and then through breaker 1422 toenergize the safety-related 4160 V 142Y (1A) switchgear.
-The alternate offsite source from the 345 kV system is through the Unit 2System Auxiliary Transformer 242 and then through breakers 2422, 2424and 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 LSCScurrent licensing basis with respect to station blackout.
The basis documentprovides 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 withinthe scope of license renewal in accordance with 10 CFR 54.4(a)(3) scopingcriteria.
LaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-13 Section 2 -Scoping and Screening Methodology and ResultsFigure 2.1-2LASALLE SBO RECOVERY BOUNDARYUNS01E LINE0X 010110-11 9-101-9(LINE LI0102 012-3 3-4)1-2NE03NOTINSCOPEItq. -,11-13 I1-13()1-6I4-INSCOPESA~T142 11413 2413141Y ) ) 241Y1412 ) ) )24121414 Lj24141422 142Y 242Y 4221423 ) 1424 2424 2423IJ'DG 1A DG2A14321)4143D1BDG1 BSAT 242)243224.33)DG2B3LEGENDJA11DIESELCIRCUIT BREAKER TRANSFORMER GENERATOR LaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-14 Section 2 -Scoping and Screening Methodology and Results2.1.4 INTERIM STAFF GUIDANCE DISCUSSION The NRC has encouraged applicants for license renewal to address Interim StaffGuidance (ISG) issues in license renewal applications.
The following is a listingof 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 1-01LR-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 AnalysesAging Management of Stainless Steel Structures andComponents in Treated Borated Water, Revision 1Aging Management Program for Steam Generators Generic Aging Lessons Learned (GALL) Report Revision 2AMP XI.M41, "Buried and Underground Piping and Tanks"Updated Aging Management Criteria for Reactor VesselInternal Components of Pressurized Water ReactorsOngoing 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 forInternal Service Level III (Augmented)
CoatingsThe following sections provide summaries of how each of the ISG issues isaddressed 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 inwhich the NRC endorses the guidance of NEI 05-01, "Severe AccidentMitigation Alternatives (SAMA) Analysis Guidance Document" (reference 1.7.18).
The LSCS severe accident mitigation alternatives analysis providedas a part of Appendix E to this application is consistent with the guidance ofNEI 05-01, as discussed in this LR-ISG.2.1.4.2 Aging Management of Stainless Steel Structures and Components inTreated Borated Water, Revision 1 (LR-ISG-201 1-01)This LR-ISG provides interim guidance to applicants for license renewal as toone acceptable approach to managing the aging effects of stainless steelstructures and components exposed to treated borated water. New guidancehas also been provided for BWR spent fuel storage racks for which there iscurrently no specific guidance in the GALL Report for the loss of material agingLaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-15 Section 2 -Scoping and Screening Methodology and Resultseffect. LSCS incorporates the guidance presented in this LR-ISG for BWRsand 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 rodblades, defective fuel, and spent fuel storage racks exposed to treated water inthe 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 Revision2 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 toone acceptable approach to managing the aging effects of buried andunderground 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 InternalComponents 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 renewalrevising NUREG-1 800 acceptance criteria and review procedures to betteraddress the ongoing review of operating experience with respect to licenserenewal aging management programs.
The LSCS license renewal application incorporates the guidance presented in this LR-ISG. Ongoing review ofoperating experience is addressed in Appendix A, Section A. 1.6 and AppendixB, 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 toone acceptable approach to managing the aging effect of wall thinning due tovarious erosion mechanisms in piping and components within the scope oflicense renewal.
LR-ISG-2012-01 revises the guidance provided in NUREG-1801, Revision 2, XI.M17, "Flow-Accelerated Corrosion" program.
The LSCSFlow-Accelerated Corrosion (B.2.1.10) program incorporates the guidancepresented in this LR-ISG.LaSalle County Station, Units 1 and 2 Page 2.1-16License Renewal Application Section 2 -Scoping and Screening Methodology and Results2.1.4.8 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 toone acceptable approach to managing the effects of aging. The ISGaddresses recurring internal corrosion, representative minimum sample size forinternal 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 InternalSurfaces 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 LevelIII (Augmented)
Coatinas (Draft LR-ISG-2013-01; ADAMS Accession No.ML13262A442)
This draft LR-ISG provides interim guidance to applicants for license renewalas to one acceptable approach to managing loss of coating integrity due toblistering,
- 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 draftLR-ISG.2.1.5 SCOPING PROCEDURE The scoping process is the systematic process used to identify the LSCSsystems, structures, and components within the scope of the license renewalrule. 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 areview of the source CLB documents.
In scope boundaries were established anddocumented in the scoping evaluations, based on the identified intendedfunctions.
The in scope boundaries form the basis for identification of the inscope components, which is the first step in the screening process described inSection 2.1.6. System and structure scoping evaluations are documented andhave 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 listof plant systems and structures, as described in Section 2.1.3.1.
The systemsand structures were grouped into one of the following categories:
LaSalle County Station, Units 1 and 2License 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 thecriteria 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, Section2.1.5.2, 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, andcomponents within the scope of license renewal include:Safety-related
- systems, structures, and components which are thoserelied 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 safeshutdown condition; or(iii) The capability to prevent or mitigate the consequences of accidents which could result in potential offsite exposures comparable to thosereferred to in 10 CFR 50.34(a)(1),
or10 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 databasewere populated using a controlled procedure, with classification criteriaconsistent with the above 10 CFR 54.4(a)(1) criteria.
The classification criteriadifferences have been evaluated in a license renewal basis document asdescribed in Section 2.1.3.2 and accounted for during the license renewalscoping process.LaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-18 Section 2 -Scoping and Screening Methodology and ResultsSafety-related classifications for systems and structures are based on systemand structure descriptions and analyses in the UFSAR, or on design basisdocuments such as engineering
- drawings, design specifications, evaluations, or calculations.
Safety-related structures are those structures listed in theUFSAR and classified as Seismic Category I. Systems and structures that areidentified as safety-related in the UFSAR or in design basis documents havebeen classified as satisfying the criteria of 10 CFR 54.4(a)(1) and have beenincluded within the scope of license renewal.
Safety-related components listedin the Passport equipment database were also reviewed and the system orstructure associated with the safety-related component was included within thescope of license renewal in accordance with 10 CFR 54.4(a)(1) criteria.
Thereview also confirmed that plant conditions, internal and external eventsincluding design basis accidents (DBAs), anticipated operational transients, abnormal operational transients, and natural phenomena as described in thecurrent 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, andcomponents within the scope of license renewal include:* All nonsafety-related
- systems, structures, and components whose failurecould 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 withrespect 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 SSCsEach 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 functionin support of a safety-related SSC intended function.
The functional requirement distinguishes this category from the other categories, where thenonsafety-related SSCs are required only to maintain adequate integrity topreclude structural failure or spatial interactions.
The nonsafety-related SSCsthat 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 identifynonsafety-related systems or structures required to support satisfactory accomplishment of a safety-related function.
Nonsafety-related systems orstructures credited in CLB documents to support a safety-related function havebeen included within the scope of license renewal.
LSCS classifies systemsLaSalle County Station, Units 1 and 2 Page 2.1-19License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsthat 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 SSCsthat are functionally relied upon to directly mitigate the consequences ofthe 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 MSIVleakage following a LOCA. Additionally, manual isolation of thenonsafety-related main condenser off-gas outlet valves and manualtripping of the nonsafety-related mechanical vacuum pump is creditedfollowing 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 meansfor handling loads above or near safety-related components.
- The Main Steam System includes nonsafety-related SSCs that containleakage 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 lowpressure turbine exhaust hoods which are credited for holdup andplateout of MSIV leakage following a LOCA.* The Plant Computer System includes nonsafety-related SSCs that arefunctionally relied upon to support operator actions that mitigate theconsequences of analyzed accidents as presented in the UFSARAccident
- Analyses, including abnormal operating transients.
- The Plant Drainage System includes nonsafety-related floor drains in theReactor Building that are credited for the mitigation of flooding as a resultof 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 chamberairspace prior to exiting the primary containment are in scope to ensuretheir 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 senseprocess conditions and generate signals to actuate control room alarmsto prompt operator actions in response to a radwaste gas leak abnormaloperational transient.
- The Reactivity Control System includes the nonsafety-related rod worthminimizer which is credited to prevent rod withdrawal error at low power.Additionally, the rod worth minimizer is credited for a control rod dropaccident.
LaSalle County Station, Units 1 and 2 Page 2.1-20License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsThe Safety-Related Ventilation System includes nonsafety-related SSCsthat provide a pathway to the station vent stack for the potential release offission 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 inaccordance with 10 CFR 54.4(a)(2).
As an additional confirmation of scoping to meet 10 CFR 54.4(a)(2)
- criteria, asupporting system review was completed as part of the scoping process.
Thescoping process was performed on a system and structure basis. For systemsincluded within the scope of license renewal in accordance with therequirements of 10 CFR 54.4(a)(1),
the scoping evaluation included theidentification of any additional
- systems, including nonsafety-related systems,that are required to support the safety-related system intended functions.
Itwas then confirmed that these identified supporting systems were alsoincluded in scope. Except as identified above, the LSCS systems required tosupport 10 CFR 54.4(a)(1) functions are classified safety-related, and as suchincluded within the scope of license renewal in accordance with10 CFR 54.4(a)(1).
The identification of supporting systems was not requiredfor 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 NEI95-10, Appendix F. The guidance requires that, when demonstrating thatfailures of nonsafety-related systems would not adversely impact the ability tomaintain intended functions, a distinction must be made between nonsafety-related systems that are directly connected to safety-related systems andthose that are not directly connected to safety-related systems.
For anonsafety-related piping system that is directly connected to and providesstructural 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 CLBinformation, 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 toperform its intended function under CLB design conditions.
The location of thepoint beyond which the failure of the nonsafety-related piping will not renderthe safety-related portion of the piping system unable to perform its intendedfunction under CLB design conditions is identified using the guidancepresented in NEI 95-10, Appendix F, Section 4.For nonsafety-related systems which are not connected to safety-related pipingor components, or are outside the structural support boundary for the attachedsafety-related piping system, but have a spatial relationship such that theirfailure could adversely impact the performance of a safety-related SSC'sintended
- function, there are two scoping options:
a mitigative option or apreventive option. When mitigative features (e.g., pipe whip restraints, jetimpingement
- shields, spray and drip shields, seismic supports, flood barriers, and physical barriers such as floors, walls, and doors) are provided to protectsafety-related SSCs from failures of nonsafety-related SSCs, thisLaSalle County Station, Units 1 and 2 Page 2.1-21License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsdemonstration should show that mitigating devices are adequate to protectsafety-related SSCs from failures of nonsafety-related SSCs regardless offailure location.
If this level of protection can be demonstrated, then only themitigative features need to be included within the scope of license renewal.However, if it cannot be demonstrated that the mitigative features are adequateto protect safety-related SSCs from the consequences of failures of nonsafety-related SSCs, then the preventive option is used, which requires that thenonsafety-related SSC be brought into the scope of license renewal.The methodology for identification of LSCS SSCs that satisfy the10 CFR 54.4(a)(2) scoping criterion was based on a review of applicable CLBdocuments, as well as plant-specific and industry operating experience.
Themitigative 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 SSCsFor nonsafety-related SSCs directly connected to safety-related SSCs thenonsafety-related piping and supports, up to and including the first seismic orequivalent anchor (such as a series of supports that have been evaluated as apart of a plant-specific piping design analysis to ensure that forces andmoments are restrained in three (3) orthogonal directions) beyond thesafety/nonsafety interface, are within the scope of license renewal per 10 CFR54.4(a)(2).
The "first seismic or equivalent anchor" is defined such that thefailure 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 performits intended function under CLB design conditions.
An alternative to specifically identifying a seismic anchor or equivalent anchorthat supports the safety-related/nonsafety-related piping interface is to includeenough of the nonsafety-related piping run to ensure these anchors areincluded and thereby ensure the piping and anchor intended functions aremaintained.
The intended function consists of two facets 1) providing structural support for the safety-related/nonsafety-related interface and 2) ensuringnonsafety-related piping loads are not transferred through the safety-related/nonsafety-related interface.
The following methods (a) thru (g) wereused to define end points for the portion of nonsafety-related piping attached tosafety-related piping to be included in the scope of license renewal.
In thesecases the nonsafety-related piping was included in scope for 10 CFR54.4(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.) thatis a rugged component and is designed not to impose loads onconnecting 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 endpoint when the flexible connection effectively decouples the pipingLaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-22 Section 2 -Scoping and Screening Methodology and Resultssystem (i.e. does not support loads or transfer loads across it toconnecting piping).d) A free end of nonsafety-related piping, such as a drain pipe that ends atan open floor drain.e) For nonsafety-related piping runs that are connected at both ends tosafety-related piping, the entire run of nonsafety-related piping is includedin scope.f) A point where buried piping exits the ground. The buried portion of thepiping should be included in the scope of license renewal.
Adetermination that the buried piping is well founded on compacted soilthat is not susceptible to liquefaction must be documented.
g) A smaller branch line where the moment of inertia ratio of the largerpiping to the smaller piping is equal to or greater than the acceptable ratio defined by the current licensing basis, because significantly smallerpiping does not impose loads on larger piping and does not supportlarger piping.These scoping boundaries are determined from review of the physicalinstallation
- 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. Theassociated piping and components included within the scope of licenserenewal 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 systemsare shown on the license renewal boundary drawings in blue. Note that if theconnected nonsafety-related piping system contains water, steam or oil, thenthe in scope boundary may extend beyond the locations described above dueto potential for spatial interaction with safety-related SSCs.Potential for Spatial Interactions with Safety-Related SSCsNonsafety-related systems that are not connected to safety-related piping orcomponents, or are outside the structural support boundary for the attachedsafety-related piping system, and have a spatial relationship such that theirfailure could adversely impact the performance of a safety-related SSCintended
- 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 protectsafety-related SSCs from failures of nonsafety-related SSCs. Examples ofplant 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 themitigating features are adequate to protect safety-related SSCs from failures ofLaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-23 Section 2 -Scoping and Screening Methodology and Resultsnonsafety-related SSCs regardless of failure location.
If this level of protection can be demonstrated, then only the mitigative features need be included withinthe scope of license renewal.
Mitigative plant design features are used in theTurbine Building and Offgas Building to exclude SSCs from the scope oflicense renewal at LSCS by defining the boundaries for areas where spatialinteraction is not a concern.The preventive option involves identifying the nonsafety-related SSCs thathave a spatial relationship such that failure could adversely impact theperformance of a safety-related SSC intended
- function, and including theidentified nonsafety-related SSC within the scope of license renewal withoutconsideration of plant mitigative features.
With the exception of the TurbineBuilding and Offgas Building, LSCS applied the preventive option for 10 CFR54.4(a)(2) scoping.The preventive option assumes potential spatial interaction in structures orportions 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 wereperformed as required to confirm that all structures containing safety-related SSCs were identified.
With the exception of the Turbine Building and OffgasBuilding, it was assumed that all nonsafety-related SSCs within thesestructures 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 otherareas. No credit was taken for separation by distance alone without amitigative feature capable of preventing the spatial interaction.
The mitigative features were included in the scope of license renewal.
This evaluation wasdocumented in a technical basis document.
Nonsafety-related piping and components that contain water, oil, or steam, andare located inside structures that contain safety-related SSCs, are included inscope for potential spatial interaction under criterion 10 CFR 54.4(a)(2),
unlesslocated in an area where there is no concern with spatial interaction.
High-energy lines with potential spatial interaction are included in the scope oflicense renewal under 10 CFR 54.4(a)(1) or (a)(2) depending on their safetyclassification.
Safety-related high-energy lines are in scope under 10 CFR54.4(a)(1),
and nonsafety-related high-energy lines are in scope under 10 CFR54.4(a)(2).
Potential spatial interaction due to leakage or spray is assumed forsystem 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 withsafety-related SSCs. SSCs containing air or gas cannot adversely affectsafety-related SSCs due to leakage or spray, since gas systems contain noliquids that could spray or leak onto safety-related systems to cause shorts orother malfunctions.
LSCS operating experience was reviewed and confirmed LaSalle County Station, Units 1 and 2 Page 2.1-24License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsthat there have been no failures due to aging in systems containing air or gasthat 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 impactfrom pipe whip or jet impingement from moderate energy systems do not occurand need not be considered.
Thus the nonsafety-related systems containing air or gas are not included in the scope of license renewal for spatialinteraction.
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 CFR54.4(a)(2) for potential spatial interaction with safety-related SSCs areidentified on the license renewal boundary drawings in red.Scoping of Abandoned Equipment Abandoned equipment is not included within the scope of license renewal if ithas been confirmed to be isolated, vented, and drained.
If this confirmation cannot be made, the system or portions
- thereof, are included within the scopeof license renewal for aging management.
Abandoned equipment is not reliedon to perform any function delineated in 10 CFR 54.4(a)(1) or (a)(3) as it isnonoperational.
- 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 forlicense renewal.
In addition, disconnection of wiring for power, control, orparameter indication and air supplies is not necessary to assure that theabandoned 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, andcomponents within the scope of license renewal include:All systems, structures and components relied on in safety analyses orplant evaluations to perform a function that demonstrates compliance withthe 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), andstation blackout (10 CFR 50.63).The regulation for pressurized thermal shock (10 CFR 50.61) is applicable topressurized water reactors only, and therefore not applicable to LSCS which isa boiling water reactor.
For each of the other four regulations, a technical basis document was prepared to provide input into the scoping process.
Eachof the regulated event basis documents (described in Section 2.1.3.4) identifythe systems and structures that are relied upon to demonstrate compliance with the applicable regulation.
The basis documents also identify the sourcedocumentation used to determine the scope of components within the systemLaSalle County Station, Units 1 and 2 Page 2.1-25License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsthat are credited to demonstrate compliance with each of the applicable regulated events. Guidance provided by the technical basis documents was 0incorporated into the system and structure scoping evaluations, to determine the SSCs credited for each of the regulated events. SSCs credited in theregulated events have been classified as satisfying criteria of10 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, theintended functions that are the bases for including them within the scope oflicense renewal are identified and documented in the scoping evaluation.
Thesystem or structure intended functions are based on the applicable CLBreference documents.
For systems, the system level intended functiondescriptions associated with 10 CFR 54.4(a)(1) were standardized based onnuclear safety criteria for boiling water reactors as documented in industrystandard ANSI/ANS-52.1-1983.
The use of standardized 10 CFR 54.4(a)(1) functions provided for consistent function application and appropriate level ofdetail for system level intended function descriptions.
The component levelintended functions are the passive component functions that are necessary tosupport the system or structure intended function(s).
The structure andcomponent 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 renewalare then further evaluated to determine the population of in scope structures and components.
This part of the scoping process is also a transition from thescoping 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 systemsare 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&Ccomponents of in scope electrical and in scope mechanical systems are placedinto commodity groups and are screened as commodities.
Scoping boundaries for mechanical
- systems, structures, and electrical systems are, therefore, described separately.
Mechanical SystemsFor mechanical
- systems, the mechanical components that support the systemintended functions are included within the scope of license renewal and aredepicted on the applicable system piping and instrumentation diagram.Mechanical system piping and instrumentation diagrams are marked up tocreate 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 renewalregulated events, are identified on the system piping and instrumentation diagrams by green highlighting.
Nonsafety-related components that areconnected to safety-related components and are required to provide structural LaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-26 Section 2 -Scoping and Screening Methodology and Resultssupport at the safety/nonsafety interface, or components whose failure couldprevent satisfactory accomplishment of a safety-related function due to spatialinteraction with safety-related SSCs, are identified by red highlighting.
Acomputer sort and download of associated system components from thePassport equipment database confirms the scope of components in thesystem. 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 areidentified from a review of applicable plant design drawings of the structure, applicable UFSAR sections, and design basis documentation.
Plantwalkdowns were performed when required for additional confirmation.
Structural bolting required to support the structure proper is evaluated with thestructure.
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 ismarked up to create a license renewal boundary drawing showing thestructures within the scope of license renewal.Electrical SystemsElectrical and I&C systems, and electrical components within mechanical
- systems, did not require further system evaluations to determine whichcomponents were required to perform or support the identified intendedfunctions.
A bounding scoping approach is used for electrical equipment.
Allelectrical components within in scope systems were included within the scopeof license renewal.
In scope electrical components were placed intocommodity 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, thenext step is to determine which structures and components are subject to anaging management review.2.1.6.1 Identification of Structures and Components Subject to AMRThe requirement to identify structures and components subject to an agingmanagement 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 ofthis 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 2License Renewal Application Page 2.1-27 Section 2 -Scoping and Screening Methodology and ResultsStructures 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 orproperties.
These structures and components
- include, but arenot limited to, the reactor vessel, the reactor coolant systempressure
- 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 andconnections, cable trays, and electrical
- cabinets, excluding, butnot limited to, pumps (except casing),
valves (except body),motors, diesel generators, air compressors,
- snubbers, thecontrol rod drive, ventilation
- dampers, pressure transmitters, pressure indicators, water level indicators, switchgears, coolingfans, transistors, batteries,
- breakers, relays, switches, powerinverters, circuit boards, battery chargers, and power supplies; and(ii) That are not subject to replacement based on a qualified life orspecified time period.Structures and components that perform an intended function without movingparts or without a change in configuration or properties are defined as passivefor license renewal.
Passive structures and components that are not subject toreplacement based on a qualified life or specified time period are defined aslong-lived for license renewal.
The screening procedure is the process used toidentify the passive, long-lived structures and components within the scope oflicense renewal that are subject to aging management review.NUREG-1 800, "Standard Review Plan for Review of License RenewalApplications for Nuclear Power Plants" and NEI 95-10, Appendix B, were usedas the basis for the identification of passive structures and components.
Mostpassive structures and components are long-lived.
In the few cases where apassive component is determined not to be long-lived, such determination isdocumented in the screening evaluation and, if applicable, on the associated license renewal boundary drawing.The LSCS structures and components subject to aging management reviewhave been identified in accordance with the requirements of10 CFR 54.21 (a)(1) described above. The process implemented to meet theserequirements for mechanical
- systems, structures, and electrical commodities isdescribed as follows:Mechanical SystemsThe mechanical system screening process began with the results from thescoping process.
For in scope mechanical
- systems, the completed scopingpackages include written descriptions and marked up system piping andLaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-28 Section 2 -Scoping and Screening Methodology and Resultsinstrumentation diagrams that clearly identify the in scope system boundary forlicense renewal.
The marked up system piping and instrumentation diagramsare called license renewal boundary drawings.
These system boundarydrawings were reviewed to identify the passive, long-lived components, andthe identified components were then entered into the license renewaldatabase.
Component listings from the Passport equipment database werealso reviewed to confirm that all system components were considered.
Incases where the system piping and instrumentation diagram did not providesufficient 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 wereperformed when required for confirmation.
Some mechanical components, when combined, are considered a complexassembly.
A complex assembly is a predominantly active assembly where theperformance of its components is closely linked to that of the intended functionof the entire assembly, such that testing and monitoring of the assembly issufficient to identify degradation of these components.
Examples of complexassemblies 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 beadequately tested or monitored as part of the complex assembly, thosecomponents are identified and subject to aging management review. Thisfollows the screening methodology for complex assemblies as described inTable 2.1-2 of NUREG-1800, "Standard Review Plan for Review of LicenseRenewal Applications for Nuclear Power Plants,"
Revision 2 (reference 1.7.4).Mechanical components are screened with the system in which they werescoped. For heat exchangers, the process side of the heat exchanger isevaluated with the process side system for aging management review.Likewise, the cooling water side of the heat exchanger is evaluated with thecooling water side system for aging management review.Structures The structure screening process also began with the results from the scopingprocess.
For in scope structures, the completed scoping packages includewritten 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 wereperformed 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 NEI95-10. Electrical and I&C components for the in scope systems were assignedto commodity groups. The commodities subject to an aging management LaSalle County Station, Units 1 and 2 Page 2.1-29License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsreview are identified by applying the criteria of 10 CFR 54.21 (a)(1). Thismethod 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 electricheaters primarily serve an electrical function;
- however, they can also serve amechanical pressure boundary function.
According to Appendix B of NEI 95-10, the electrical portions of these components are active per 10 CFR54.21 (a)(1)(i) and are therefore not subject to aging management review. Onlythe pressure boundary of such an in scope component is subject to agingmanagement 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 thescope of license renewal at LSCS were identified and listed. The listingprovided by NEI 95-10, Appendix B, is the basis for this list. Electrical andI&C components and commodities were organized into groups such ascircuit breakers,
- switches, and cables. Individual specific components were not identified.
The electrical commodities were identified from areview 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 of10 CFR 54.21(a)(1)(i) was applied to identify commodities that performtheir functions without moving parts or without a change in configuration orproperties (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 todetermine if they perform a license renewal intended function during thescoping 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 thosecommodities that are subject to replacement based on a qualified life orspecific time period from the requirements of an aging management review. The 10 CFR 54.21(a)(1)(ii) screening criterion was applied tothose commodities that were not previously eliminated by the application ofthe 10 CFR 54.21(a)(1)(i) screening criterion.
Components andcommodities included in the plant environmental qualification (EQ) programare 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 theLaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-30 Section 2 -Scoping and Screening Methodology and Resultsregulatory definition and are, therefore, not subject to an agingmanagement 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 theseparate electrical commodities that are not part of a larger active component.
The passive commodities that are not subject to replacement based on aqualified life or specified time period are subject to an aging management review. For LSCS, the electrical commodities that require an agingmanagement review are identified in Section 2.5.2.1.6.2 Intended Function Definitions The intended functions that the components and structures must fulfill arethose functions that are the bases for including them within the scope oflicense renewal.
A component intended function is defined as a passivecomponent function that must be performed in order for the system or structure to be able to perform the system or structure intended function(s).
Forexample, pressure boundary failure of a component would cause loss ofinventory from the system, and the system would subsequently be unable toperform its intended function(s).
Structures and components may havemultiple intended functions.
LSCS has considered multiple intended functions where applicable, consistent with the staff guidance provided in Table 2.1-3 ofNUREG-1 800, "Standard Review Plan for Review of License RenewalApplications for Nuclear Power Plants" (reference 1.7.4).Table 2.1-1 provides expanded definitions of structure and component passiveintended functions identified in this application.
LaSalle County Station, Units 1 and 2 Page 2.1-31License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 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 (forContainment, Holdup and radioactive decay) of iodine and non-condensable gases beforerelease.Direct Flow Provide spray shield or curbs for directing flow. Also applies to diffusercredited 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 orfrom 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), andprotective 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 ofLeakage Boundary safety-related SSCs. This function includes the required structural integrity when the nonsafety-related leakage boundary piping is alsoattached 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 2License Renewal Application Page 2.1-32 Section 2 -Scoping and Screening Methodology and ResultsTable 2.1-1 Passive Structure and Component Intended Function Definitions Intended Function Definition Provide pressure-retaining boundary so that sufficient flow at adequatepressure is delivered, or provide fission product barrier for containment Pressure Boundary pressure
- boundary, or provide containment isolation for fission productretention, or provide the containment, holdup and plateout function (forMain 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 protectBarrier public health and safety in the event of any postulated design basisevents.Provide structural support for structures and components within theStructural Support scope for 10 CFR 54.4(a)(1),
(a)(2), or (a)(3) or provide structural integrity to preclude nonsafety-related component interactions thatcould prevent satisfactory accomplishment of a safety-related function.
Structural Support to Provide structural support of fuel assemblies, control rods, and incoremaintain core instrumentation, to maintain core configuration and flow distribution.
configuration and flowdistribution 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 2License Renewal Application Page 2.1-33 Section 2 -Scoping and Screening Methodology and Results2.1.6.3 Stored Equipment For several fire zones, credit is taken for making repairs to equipment in orderto perform safe shutdown functions.
In all cases, such credit is taken only toaccomplish a function required for cold shutdown.
Equipment that is stored onsite for installation or use in achieving cold shutdown is considered to be withinthe scope of license renewal.
Specific repairs credited for individual fire zonesare discussed in the LSCS Fire Protection Report (FPR) subsection H.4.5. Foreach 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 bythe analysis and the procedure are reserved onsite. Periodic surveillances areperformed to inventory and check the availability of equipment necessary tosupport the repairs.
Tools and supplies used to place the stored equipment inservice are not within the scope of license renewal.2.1.6.4 Consumables The evaluation process for consumables is consistent with the guidanceprovided in NUREG-1800, Table 2.1-3. Consumables have been divided intothe 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, andair 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 notpressure-retaining parts. Therefore, these subcomponents are not reliedon to form a pressure-retaining function and are not subject to an AMR.* Group (b) structural sealants:
AMRs were required for structural sealantsin structures within the scope of license renewal.
A summary of the AMRresults is presented in Section 3.5.* Group (c) subcomponents (oil, grease, and component filters):
Thesesubcomponents are short-lived and are periodically replaced.
Variousplant procedures are used in the replacement of oil, grease, and filters incomponents that are in scope for license renewal.
Therefore, thesesubcomponents are not subject to an AMR." Group (d) consumables (system filters, fire extinguishers, fire hoses, andair packs): System ventilation filters are replaced in accordance with plantprocedures based on vendor manufacturers' requirements and systemtesting.
Fire extinguishers, self-contained breathing air packs and firehoses are within the scope of license renewal, but are not subject toaging management because they are replaced based on condition.
These components are periodically inspected in accordance with NFPA10 for portable fire extinguishers, 29 CFR 1910.134 for self-contained breathing air packs, and NFPA 1962 for fire hoses (with exceptions toNFPA standards as identified in the LSCS FPR). These requirereplacement of equipment based on their condition or performance duringLaSalle County Station, Units 1 and 2License Renewal Application Page 2.1-34 Section 2 -Scoping and Screening Methodology and Resultstesting and inspection.
The periodic inspections are implemented bycontrolled LSCS procedures.
These components are subject toreplacement based on requirements implemented by controlled procedures, and are therefore not long-lived and not subject to an agingmanagement review.2.1.7 GENERIC SAFETY ISSUESIn accordance with the guidance in NEI 95-10 and Appendix A.3 of NUREG-1800, "Standard Review Plan for Review of License Renewal Applications forNuclear Power Plants,"
review of NRC generic safety issues (GSIs) as part of thelicense renewal process is required to satisfy 10 CFR 54.29. This guidancesuggests that GSIs involving issues related to license renewal agingmanagement reviews or TLAAs should be addressed in the license renewalapplication.
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 areaddressed for LSCS license renewal:* GSI 186, Potential Risk and Consequences of Heavy Load Drops in NuclearPower Plants -This GSI addresses heavy load issues related to cranedesign and operation.
Aging effects are not central to these issues. Theissue 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 theNRC. 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 oflicense renewal.
Accordingly, the issue of environmental effects oncomponent fatigue life is addressed in Section 4.3.* GSI-1 93, BWR ECCS Suction Concerns
-This GSI addresses the possiblefailure of low pressure emergency core cooling systems due to unanticipated, large quantities of entrained gas in the suction piping from the pressuresuppression chamber (torus) in BWR Mark I containments.
This issue is notapplicable to LSCS which is Mark II containment.
NUREG-0933 was reviewed and there are no new generic issues that involveissues related to license renewal aging management reviews or TLAAs.2.
1.8 CONCLUSION
The scoping and screening methodology described above was used for theLSCS IPA to identify the systems, structures, and components that are within thescope of license renewal and that are subject to an aging management review.The methodology is consistent with and satisfies the requirements of10 CFR 54.4 and 10 CFR 54.21(a)(1).
LaSalle County Station, Units 1 and 2 Page 2.1-35License Renewal Application This Page Intentionally Left Blank Section 2 -Scoping and Screening Methodology and Results2.2 PLANT LEVEL SCOPING RESULTSTable 2.2-1 lists the LaSalle County Station systems, structures and commodity groupsthat were evaluated to determine if they were within the scope of license renewal, usingthe 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 2License Renewal Application Page 2.2-1 Section 2 -Scoping and Screening Methodology and ResultsTable 2.2-1 Plant Level Scoping ResultsIn ScopeforSystem, Structure or Commodity Group License Reference Renewal?Reactor Vessel, Internals, and Reactor Coolant SystemReactor Coolant Pressure Boundary System Yes 2.3.1.1Reactor Vessel Yes 2.3.1.2Reactor Vessel Internals Yes 2.3.1.3Engineered Safety FeaturesHigh Pressure Core Spray System Yes 2.3.2.1Low Pressure Core Spray System Yes 2.3.2.2Reactor Core Isolation Cooling System Yes 2.3.2.3Residual Heat Removal System Yes 2.3.2.4Standby Gas Treatment System Yes 2.3.2.5Auxiliary Systems,AuxiiarySý*
te*ISytm No, ,, UFClosed Cycle Cooling Water System Yes 2.3.3.1Combustible Gas Control System Yes 2.3.3.2Compressed Air System Yes 2.3.3.3Control Rod Drive System Yes 2.3.3.4Control Room Ventilation System Yes 2.3.3.5Cranes, Hoists, and Refueling Equipment System Yes 2.3.3.6Demineralized Water Makeup System Yes 2.3.3.7Diesel Generator and Auxiliaries System Yes 2.3.3.8Drywell Pneumatic System Yes 2.3.3.9Electrical Penetration Pressurization System Yes 2.3.3.10LaSalle County Station, Units 1 and 2 Page 2.2-2LaSalle County Station, Units 1 and 2License Renewal Application Page 2.2-2 Section 2 -Scoping and Screening Methodology and ResultsTable 2.2-1 Plant Level Scoping ResultsIn ScopeforSystem, Structure or Commodity Group License Reference Renewal?Essential Cooling Water System Yes 2.3.3.11Fire Protection System Yes 2.3.3.12Fuel Pool Cooling and Storage System Yes 2.3.3.13Nonessential Cooling Water System Yes 2.3.3.14Nonsafety-Related Ventilation System Yes 2.3.3.15Plant Drainage System Yes 2.3.3.16Primary Containment Ventilation System Yes 2.3.3.17Process Radiation Monitoring System Yes 2.3.3.18Process Sampling and Post Accident Monitoring System Yes 2.3.3.19Radwaste System Yes 2.3.3.20Reactor Water Cleanup System Yes 2.3.3.21Safety-Related Ventilation System Yes 2.3.3.22Standby Liquid Control System Yes 2.3.3.23Suppression Pool Cleanup System Yes 2.3.3.24Traversing Incore Probe System Yes 2.3.3.25Steam and Power Conversion SystemCondensate SystemCondenser and Air Removal SystemtracionSteaSystem
.Feedwater System..
...,. ... 3 ,,. ;; ...... .....: ~ !% :............=7:I' Main Sratorland ASuxlary Systemj:tem Main Steam System2.3.4.12.3.4.2,UJFSAR 10.4.82.3.4.33UFSAR10 10,22.3.4.4LaSalle County Station, Units 1 and 2License Renewal Application Page 2.2-3 Section 2 -Scoping and Screening Methodology and ResultsTable 2.2-1 Plant Level Scoping ResultsIn ScopeforSystem, Structure or Commodity Group License Reference Renewal?Main Turbine and Auxiliaries System _Yes 2.3.4.5Structures and Component SupportsAuxiliary Building Yes 2.4.1Component Supports Commodity Group Yes 2.4.2Cooling Lake Yes 2.4.3Diesel Generator Building Yes 2.4.4Lake Screen House Yes 2.4.5see aneus ot n epeStrutures NOffgas Building Yes 2.4.6Primary Containment Yes 2.4.7Radwaste Building Yes 2.4.8Reactor Building Yes 2.4.9Service Building.
No Comment.2 Structural Commodity Group Yes 2.4.10Switchyard Structures Yes 2.4.11Tank Foundation and Dikes Yes 2.4.12Turbine Building Yes 2.4.13Yard Structures Yes 2.4.14Electrical Components Area Radiation Monitoring System Yes UFSAR 7.7.9Automatic Depressurization System Yes UFSAR 7.3.1.2.2 Auxiliary Power System Yes UFSAR 8.3.1LaSalle County Station, Units 1 and 2License Renewal Application Page 2.2-4 Section 2 -Scoping and Screening Methodology and ResultsTable 2.2-1 Plant Level Scoping ResultsIn ScopeforSystem, Structure or Commodity Group License Reference Renewal?C~athodiic Prot~etonrSystern.
No IPS-AR Table 3.21Communication System Yes UFSAR 9.5.2DC Power System Yes UFSAR 8.3.2Electrical Commodities Yes 2.5.2.5Heat Trace System Yes UFSAR 7.5.2.2, 7.4.2Leak Detection System Yes UFSAR 7.6.2.2, 7.7.15MIt s~eilarneous Instr~umentationSystemn
-, No :l :2o3.3, 3.7.4,77,7.8 Neutron Monitoring System Yes UFSAR 7.6.3, 7.7.6Offsite Power System Yes UFSAR 8.2Plant Computer System Yes UFSAR 7.7.7Plant Lighting System Yes UFSAR 9.5.3.Plant'Sectfrit Syte .No-- I1J~S~iPrimary Containment Isolation System Yes UFSAR 7.3.2Reactivity Control System Yes UFSAR 7.6.5, 7.7.2Reactor Protection System Yes UFSAR 7.2Reactor Vessel Instrumentation, Controls and Display Yes UFSAR 7.5, 7.7.1, 7.7.4SystemRemote Shutdown System Yes UFSAR 7.4.4Comments:
- 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 licenserenewal.
These nonsafety-related structures are also separated from safety-related
- systems, structures, and components such that the structures' failure would not impact asafety-related function.
Therefore, the following structures are not within the scope ofLaSalle County Station, Units 1 and 2License Renewal Application Page 2.2-5 Section 2 -Scoping and Screening Methodology and Resultslicense renewal:
Administration Building (also known as the South Service Building or NewService Building),
Building
- 30 (Records Storage Vault or Records Storage Building),
IDNS(Illinois Department of Nuclear Safety) Building, Project Management Field Office, TrainingBuilding, Maintenance Shop, Building
- 1 (contractor fab shop, radiological outage, equipstorage),
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 (TSCand 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 OutfallStructure, Transporter
- Building, Hazardous/Mixed Waste Storage Facility (Building
- 20),Radwaste
- Storage, Building
- 33, Filling Station, Station Heat Chiller Pad, and FishHatchery.
- 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 ServiceBuilding is to provide structural
- support, shelter, and protection for machine and electricshops, storage, and administrative and maintenance personnel office areas. The ServiceBuilding reinforced concrete substructure is supported by a reinforced concrete matfoundation on soil. The service building roof is galvanized metal decking and built-uproofing.
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 ServiceBuilding, 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 functiondelineated in 10 CFR 54.4 (a) and is not in scope for license renewal.LaSalle County Station, Units 1 and 2License Renewal Application Page 2.2-6 Section 2 -Scoping and Screening Methodology and Results2.32.3.1SCOPING AND SCREENING RESULTS:
MECHANICAL REACTOR VESSEL, INTERNALS, AND REACTOR COOLANT SYSTEMThe 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 2License Renewal Application 2.3-1 Section 2 -Scoping and Screening Methodology and Results2.3.1.1 Reactor Coolant Pressure Boundary System 0Description The Reactor Coolant Pressure Boundary System (RCPB) is a normally operating systemdesigned to provide the source of forced circulation of reactor coolant through the reactor coreto remove the heat generated by fission.
The RCPB also provides a flowpath to the reactorvessel for feedwater, high pressure core spray (HPCS), low pressure core spray (LPCS),standby liquid control (SLC), shutdown
- cooling, low pressure coolant injection, and reactorcore isolation cooling (RCIC). The RCPB also includes piping within the flowpath for steamfrom the reactor to the main turbine, RCIC turbine, supply and return reactor coolant for theshutdown cooling and reactor water cleanup system (RWCU) functions, and provides pressurerelief 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 reactorrecirculation system or are connected to the reactor recirculation system, up to and including the outermost containment isolation valve in system piping which penetrates primary reactorcontainment, 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 lowpressure coolant injection),
RCIC, RWCU, feedwater, main steam, and nuclear boilerinstrumentation.
The RCPB also includes the ASME Section Xl Class 2 portions of the nuclear boilerinstrumentation 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 andmakeup 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 pumpdischarge flow control valves, the piping and instrumentation that supports the pump motorwinding and bearing coolers, and oil reservoirs.
For more detailed information see UFSAR Chapter 5.0 and Appendix G.BoundaryThe RCPB license renewal scoping boundary begins at the piping attached to the reactorpressure vessel (RPV) nozzle safe end to piping welds. The RPV nozzles, safe-ends, andwelds are included with the license renewal Reactor Vessel system. The RCPB boundaryincludes the piping connected to the 10 recirculation inlet nozzles, two recirculation outletnozzles, four main steam nozzles, six feedwater
- nozzles, three low pressure coolant injection
- nozzles, 10 instrumentation
- nozzles, two jet pump instrument
- nozzles, one high pressure corespray nozzle, one low pressure core spray nozzle, one standby liquid control nozzle, onebottom 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 mainreactor recirculation
- flowpath, which begins at the pump suction piping attached to the reactorvessel nozzles, continues through the suction piping, suction valves, recirculation pumpcasings, discharge valves and discharge piping back to the RPV nozzles.
Also included is theLaSalle County Station, Units 1 and 2 2.3-2License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsprocess sample line from the "B" recirculation pump discharge header to the sample coolerinlet valve, and the purge supply to the reactor recirculation pump seals from the CRD Systemfrom the outboard containment isolation check valves to the pump seals. Also included is thehydraulic control oil system and piping components from the hydraulic control power units inthe Reactor Building to the hydraulic actuators on the recirculation pump discharge flowcontrol valves. Also included are piping and instrumentation associated with lubrication andcooling of the recirculation pumps and motors. The scoping boundary to the Closed CoolingWater System is at the flanges that connect the plant reactor building closed cooling watersystem 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) shutdowncooling suction containment isolation valve. The boundary includes the 12-inch RHRshutdown cooling return piping from the outermost containment valves to the branchconnections off the 24-inch recirculation pump "A" and "B" discharge piping. The RCPB alsoincludes 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 outboardcontainment isolation valve.The RCPB includes the RHR piping that provides low pressure coolant injection and the LPCSand 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 flowcheck valves outside of containment and to pressure-retaining instrumentation, and from theSLC 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 steamline drains, to the outboard containment isolation valves. Also included is the inlet piping tothe main steam relief valves and the main steam relief valve bodies. The main steam reliefdischarge piping is included with the license renewal Main Steam System. The RCPBincludes the 10-inch branch connection off the "B" main steam line to the 4-inch RCIC Systemturbine steam supply piping up to the outboard containment isolation valve and the 10-inchblank flange connection to the RHR System. The RCPB also includes Feedwater Systempiping and components from the RPV nozzles to the outboard containment isolation checkvalves.The RCPB includes the RCIC System pump discharge piping from the 6-inch flanged nozzleon the RPV head to outboard containment isolation valves and extends to the branchconnection to RHR System piping to the outboard containment isolation valve. The RCPBincludes the vent piping from the flanged 4-inch nozzle on the RPV head to the 2-inch branchconnection off of the "A" main steam line, ending at the second isolation valve to the glandseal 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 theRPV 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 aboveare included in the license renewal RCPB System. Included is instrumentation piping andcomponents attached to the RCPB piping sections from the branch connections off the pipingto pressure-retaining instrumentation.
Instrumentation downstream of the excess flow checkvalves is included as shown on License Renewal Boundary Drawings.
LaSalle County Station, Units 1 and 2 2.3-3License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsAlso 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe nonsafety-related portions of the system located in the Reactor Building and PrimaryContainment.
Included in this boundary are pressure-retaining components relied upon topreserve the leakage boundary intended function of this portion of the system. For moreinformation, 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 theEHC system reservoirs associated with the reactor recirculation pump discharge flow controlvalves, 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 asafety-related system that is relied upon to remain functional during and following design basisevents. The Reactor Coolant Pressure Boundary System meets 10 CFR 54.4(a)(2) becausefailure 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 BoundarySystem also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses or plantevaluations 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 BoundarySystem forms a barrier to minimize the release of reactor coolant and radioactive material tothe Reactor Buildings.
The Reactor Coolant Pressure Boundary System, in conjunction withthe Reactor Protection System, provides overpressure protection for the reactor coolantpressure boundary.
- 2. Provide primary containment boundary.
The Reactor Coolant Pressure Boundary Systemincludes containment isolation valves. 10 CFR 54.4(a)(1)
- 3. Sense process conditions and generate signals for reactor trip or engineered safetyfeatures actuations.
The Reactor Coolant Pressure Boundary System includesinstrumentation and process controls that provide input signals to the Primary Containment Isolation System, Reactor Protection System, and ECCS systems.
- 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The Reactor Coolant Pressure Boundary System includes nonsafety-related fluid filled lines within the Reactor Building and Primary Containment which have thepotential 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). TheReactor Coolant Pressure Boundary System provides the flow path for reactor coolant make-LaSalle County Station, Units 1 and 2 2.3-4License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsup and decay heat removal, and maintains the reactor coolant pressure boundary in support ofreactor safe shutdown.
- 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 locatedwithin areas of the plant that may have harsh environments, and therefore have environmental qualifications.
- 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 (10CFR 50.62). Reactor Coolant Pressure Boundary System components receive therecirculation pump trip signal from the Reactor Protection System and provides the flow pathand maintains the pressure boundary for standby liquid control injection.
- 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). TheReactor 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 ofreactor safe shutdown.
UFSAR References 1.2.2.3.3 Table 3.2-15.07.7.3Appendix GLicense Renewal Boundary Drawinqgs LR-LAS-M-93, Sheets 1, 2, 3, 4, 5, 6, 7, 8LR-LAS-M-2095, Sheet 1LR-LAS-M-2097, Sheet 1LR-LAS-M-2100, Sheet 2LR-LAS-M-55, Sheets 1, 2, 7LR-LAS-M-57, Sheet 1LR-LAS-M-90, Sheet 2LR-LAS-M-91, Sheet 4LR-LAS-M-94, Sheet 1LR-LAS-M-95, Sheet 1LR-LAS-M-96, Sheets 1, 2, 3LR-LAS-M-97, Sheet 1LR-LAS-M-99, Sheet 1LR-LAS-M-100, Sheet 5LR-LAS-M-101, Sheets 1, 2LR-LAS-M-115, Sheets 1, 12LR-LAS-M-139, Sheets 1,2, 3, 4, 5, 8, 9LR-LAS-M-2146, Sheet 2LR-LAS-M-2141, Sheet 1LR-LAS-M-2143, Sheet 1LaSalle County Station, Units 1 and 2License Renewal Application 2.3-5 Section 2 -Scoping and Screening Methodology and ResultsLR-LAS-M-116, Sheets 1, 2, 7LR-LAS-M-118, Sheet 1LR-LAS-M-1 36, Sheet 2LR-LAS-M-1 37, Sheet 4LR-LAS-M-140, Sheet 1LR-LAS-M-141, Sheet 1LR-LAS-M-142, Sheets 1, 2, 3LR-LAS-M-143, Sheet 1LR-LAS-M-145, Sheet 1LR-LAS-M-146, Sheet 6LR-LAS-M-147, Sheets 1, 2LR-LAS-M-159, Sheet 1Table 2.3.1-1Reactor Coolant Pressure Boundary SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionAccumulator Leakage BoundaryBolting Mechanical ClosureClass 1 Piping, Fittings and Branch Pressure BoundaryConnections
< NPS 4"Flow Device (Instrumentation Orifices)
Pressure BoundaryThrottleFlow Device (Main Steam Line Flow ThrottleRestrictors)
Heat Exchanger
-(EHC Fluid) Tube Side Leakage BoundaryComponents Heat Exchanger
-(Motor Oil Coolers)
Leakage BoundaryShell Side Components Heat Exchanger
-(Motor Winding Leakage BoundaryCoolers)
Tube Side Components Heat Exchanger
-(Motor Winding Leakage BoundaryCoolers)
TubesHoses Leakage BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (EHC Skid) Leakage BoundaryPump Casing (RRP) Pressure BoundaryRPV Flange Leak Detection Line Pressure BoundaryTanks (EHC Reservoir)
Leakage BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.1.2-1Reactor Coolant Pressure Boundary SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-6 Section 2 -Scoping and Screening Methodology and Results2.3.1.2 Reactor VesselDescription The Reactor Vessel system is a normally operating system designed to contain pressure andheat in the core and transfer this heat to the reactor coolant.
The Reactor Vessel consists ofthe cylindrical vessel shell, lower vessel head, vessel support skirt, closure head, nozzles andsafe 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 systemsand components that are not within the license renewal boundary of the Reactor Vessel butare evaluated separately.
These include the Control Rod Drive System, Neutron Monitoring System, Primary Containment, Reactor Coolant Pressure Boundary System, Reactor VesselInternals, 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 ReactorVessel Internals, provide a floodable volume. The Reactor Vessel provides a boundary toseparate 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.BoundaryThe components within the Reactor Vessel license renewal scoping boundary are those thatcomprise 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 headvent nozzle, one head spray / reactor core isolation cooling nozzle, one spare nozzle and fourlifting lugs. The cylindrical portion of the vessel includes one flange seal leak detection linenozzle, four steam outlet nozzles, six feedwater inlet nozzles, one high pressure core spraynozzle, one low pressure core spray nozzle, one control rod drive hydraulic system returnnozzle, 10 water level instrumentation
- nozzles, three residual heat removal / low pressurecoolant injection
- nozzles, 10 recirculation inlet nozzles, two recirculation outlet nozzles, andtwo 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 licenserenewal systems, as described below. The boundary between the Reactor Vessel and theReactor Coolant Pressure Boundary System is at the weld between each reactor vesselnozzle safe-end and the attached piping and components.
The boundary between theReactor Vessel and the Control Rod Drive (CRD) System is at the flange attached to the CRDhousing.
The boundary between the Reactor Vessel and the Neutron Monitoring System is atthe flange attached to the in-core monitor housing.
The boundary between the Reactor Vesseland the Reactor Vessel Internals is at the CRD housing-to-guide tube weld and at the in-coremonitor housing-to-guide tube weld.There are multiple attachments to the reactor vessel for supporting various internalcomponents.
These internal attachments include guide rod brackets, steam dryer supportLaSalle County Station, Units 1 and 2 2.3-7License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsbrackets, dryer hold-down
- brackets, feedwater sparger brackets, jet pump riser support pads,core spray brackets, and surveillance specimen holder brackets.
The boundary between theReactor Vessel and the Reactor Vessel Internals is between the brackets and the attachedcomponents.
The brackets are included within the Reactor Vessel scoping boundary and theattached components are included within the Reactor Vessel Internals scoping boundary.
There are also external attachments to the reactor vessel within the scope of the ReactorVessel. The Unit 1 reactor vessel skirt is connected to a ring girder adapter via 60 bolts, allwithin the Reactor Vessel scoping boundary.
The ring girder adapter is connected to thereactor 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 thereactor 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 Vesselscoping boundary.
The refueling bellows and stabilizer bracket assembly are within thePrimary Containment.
The reactor vessel top head lifting lugs are within the scope of theReactor Vessel.Reason for Scope Determination The Reactor Vessel meets 10 CFR 54.4(a)(1) because it is a safety-related system that isrelied upon to remain functional during and following design basis events. The Reactor Vesselis not in scope under 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of thesystem would not prevent satisfactory accomplishment of function(s) identified for 10 CFR54.4(a)(1).
The Reactor Vessel also meets 10 CFR 54.4(a)(3) because it is relied upon in thesafety analyses and plant evaluations to perform a function that demonstrates compliance withthe 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 isnot relied upon in any safety analyses or plant evaluations to perform a function thatdemonstrates 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 therelease of reactor coolant and radioactive material to the Reactor Building.
- 2. Maintain reactor core assembly geometry.
The Reactor Vessel provides support to theReactor Vessel Internals.
The Reactor Vessel, along with the Reactor Vessel Internals, maintains a floodable volume within the reactor.
- 3. Provides structural support or restraint to SSCs in the scope of license renewal.
Thereactor pressure vessel support skirt and stabilizer brackets provide structural support for thereactor vessel. The refueling bellows bracket provides support for the refueling bellows.
- 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). TheReactor Vessel provides the flow path and maintains the pressure boundary for reactor safeshutdown.
LaSalle County Station, Units 1 and 2 2.3-8License Renewal Application Section 2 -Scoping and Screening Methodology and Results5. 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 (10CFR 50.62). The Reactor Vessel provides the flow path and maintains the pressure boundaryfor standby liquid control injection.
- 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). TheReactor Vessel provides the flow path and maintains the pressure boundary for reactor safeshutdown.
UFSAR References 3.9.55.15.3License Renewal Boundary DrawingsNone.LaSalle County Station, Units 1 and 2 2.3-9License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.1-2Reactor VesselComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting (Closure Studs -RPV) Mechanical ClosureBolting (Head Spray, CRD Housing, Head Mechanical ClosureVent, Spare Nozzle)N-1 Nozzle (Recirculation Outlet) Pressure BoundaryN-1 Nozzle Safe Ends and Welds Pressure BoundaryN-2 Nozzle (Recirculation Inlet) Pressure BoundaryN-2 Nozzle Safe Ends and Welds Pressure BoundaryN-2 Nozzle Thermal Sleeve Direct FlowN-3 Nozzle (Steam Outlet) Pressure BoundaryN-3 Nozzle Safe Ends and Welds Pressure BoundaryN-4 Nozzle (Feedwater)
Pressure BoundaryN-4 Nozzle Safe Ends and Welds Pressure BoundaryN-4 Nozzle Thermal Sleeve Direct FlowN-5 Nozzle (Low Pressure Core Spray) Pressure BoundaryN-5 Nozzle Safe End Extension Pressure BoundaryN-5 Nozzle Safe Ends and Welds Pressure BoundaryN-5 Nozzle Thermal Sleeve Direct FlowN-5 Thermal Sleeve Extension Direct FlowN-6 Nozzle (RHR / LPCI) Pressure BoundaryN-6 Nozzle Safe End Extensions Pressure BoundaryN-6 Nozzle Safe Ends and Welds Pressure BoundaryN-6 Nozzle Thermal Sleeve Extension Pressure Boundary(Unit 2 Only)N-6 Thermal Sleeve Direct FlowN-7 Nozzle (Top Head Spray / RCIC -Pressure BoundaryFlanged)N-7 Nozzle Flange Pressure BoundaryN-7 Nozzle Welds Pressure BoundaryN-8 Nozzle (Top Head Vent -Flanged)
Pressure BoundaryN-8 Nozzle Flange Pressure BoundaryN-8 Nozzle Welds Pressure BoundaryN-9 Nozzle (Jet Pump Instrumentation)
Pressure BoundaryN-9 Nozzle Safe End and Welds Pressure BoundaryN10 Nozzle (CRD Hydraulic System Pressure BoundaryReturn Line -Capped)N10 Nozzle Cap and Welds Pressure BoundaryN 11 Nozzle (Core Differential Pressure Pressure Boundaryand Liquid Control)N1i1 Nozzle Welds Pressure BoundaryN12 Nozzle (Water Level Instrumentation Pressure Boundary-366" Elevation)
N12 Nozzle Extension and Welds Pressure BoundaryN13 Nozzle (Water Level Instrumentation Pressure Boundary-517" Elevation)
N13 Nozzle Extension Pressure BoundaryLaSalle County Station, Units 1 and 2License Renewal Application 2.3-10 Section 2 -Scoping and Screening Methodology and ResultsComponent Type Intended FunctionN13 Nozzle Welds Pressure BoundaryN14 Nozzle (Water Level Instrumentation Pressure Boundary-599" Elevation)
N14 Nozzle Extension Pressure BoundaryN14 Nozzle Extension Welds Pressure BoundaryN15 Nozzle (Bottom Head Drain) Pressure BoundaryN16 Nozzle (High Pressure Core Spray) Pressure BoundaryN16 Nozzle Safe End Extensions Pressure BoundaryN16 Nozzle Safe Ends and Welds Pressure BoundaryN16 Thermal Sleeve Direct FlowN16 Thermal Sleeve Extension (Unit 2 Direct FlowOnly)N17 Nozzle (Seal Leak Detection)
Pressure BoundaryN18 (Top Head Spare -Flanged)
Pressure BoundaryN18 Nozzle Flange Pressure BoundaryN19 CRD Nozzle (Housing and Flange) Pressure BoundaryN19 CRD Nozzle (Welds) Pressure BoundaryN19 CRD Nozzles (Stub Tubes) Pressure BoundaryN20 Incore Monitor Nozzles (Housing and Pressure BoundaryFlange)Reactor Vessel (Bottom Head and Welds) Pressure BoundaryReactor Vessel (Shell, Lower Flange, and Pressure BoundaryWelds)Reactor Vessel (Top Head, Upper Pressure BoundaryFlange, and Welds)Reactor Vessel External Attachments Pressure Boundary(Refueling Bellows Support)
Structural SupportReactor Vessel External Attachments Structural Support(Support Skirt and Stabilizer Bracket)Reactor Vessel Internal Attachments Structural Support to maintain coreI_ configuration and flow distribution The aging management review results for these components are provided in:Table 3.1.2-2Reactor VesselSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-11 Section 2 -Scoping and Screening Methodology and Results2.3.1.3 Reactor Vessel Internals Description The Reactor Vessel Internals is a normally operating system within the Reactor Vessel that isdesigned to control the generation of heat in the reactor core, to transfer this heat to thereactor coolant, and to supply dry steam to the Main Steam System. The Reactor VesselInternals include fuel assemblies that generate the heat in the core, control rods and controlrod drive (CRD) assemblies that control reactivity in the core, and neutron flux detectorassemblies that monitor core reactivity.
The Reactor Vessel Internals also includes the coreshroud, shroud support and access hole covers, shroud head and steam separator, core plateand holddown bolts, top guide, fuel supports, core spray piping and spargers, low pressurecoolant injection (LPCI) couplings, jet pump assemblies, feedwater
- spargers, control rod guidetubes, incore instrumentation guide tubes and dry tubes, core plate differential pressure andstandby 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, toachieve and maintain the reactor core subcritical for any mode of normal operation or event, tocontrol 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 tothe 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 coreto control reactivity.
The core shroud, shroud support, core plate, top guide, fuel supports, andcontrol 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 pumpassemblies directs coolant flow through the core and maintains a floodable volume of coolantaround 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 andstandby liquid control injection line provides a flowpath for injecting a neutron absorber into thereactor core when the normal method of controlling core reactivity with control rods isunavailable.
The steam dryer assembly removes moisture from the wet steam leaving thesteam separators.
The Reactor Vessel Internals system is required for plant start-up, normalplant operations, normal shutdown, transient, and accident conditions.
For more detailed information see UFSAR Sections 3.9.5 and 4.1.2.BoundaryThe Reactor Vessel Internals license renewal scoping boundary includes components that areinside the Reactor Vessel. The following Reactor Vessel Internals components perform asafety-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, coreplate 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 incoreinstrumentation guide tubes and dry tubes. Also within the scope of license renewal is allrepair hardware installed on reactor internal components.
The steam dryer does not perform asafety-related function;
- however, it is included in the license renewal scope because failure ofsteam dryer components could result in loose parts that could potentially prevent satisfactory accomplishment of safety-related functions.
LaSalle County Station, Units 1 and 2 2.3-12License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsThe fuel assemblies, control rods, and neutron flux detection assemblies are in scope forlicense renewal; however they are short-lived components and are therefore not subject toaging management review. The CRD assemblies are also in scope; however they are activeassemblies and are therefore not subject to aging management review. The following ReactorVessel Internals components are not safety-related and are not required to support intendedfunctions; 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 guidepins, incore guide tube stabilizers, jet pump differential pressure sensing lines, and thesurveillance sample holders.
A safety assessment for these components is documented inBWRVIP-06 Revision 1-A. The evaluation concluded that these components do not perform asafety-related function.
This report also concluded that failure of these components does notresult in consequential failure of safety-related components.
The reactor vessel nozzles and penetrations, including associated housings and stub tubes forthe CRD assemblies, incore instrumentation, and core plate differential pressure and standbyliquid control injection line penetrations are evaluated with the license renewal Reactor Vesselsystem.Reason for Scope Determination The Reactor Vessel Internals meets 10 CFR 54.4(a)(1) because it is a safety-related systemthat is relied upon to remain functional during and following design basis events. The ReactorVessel Internals meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of thesystem could prevent satisfactory accomplishment of function(s) identified for 10 CFR54.4(a)(1).
The Reactor Vessel Internals also meets 10 CFR 54.4(a)(3) because it is reliedupon 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 ReactorVessel Internals is not relied upon in any safety analyses or plant evaluations to perform afunction 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 fuelconfiguration and clearances to ensure core reactivity control and core cooling capability during normal and accident conditions.
- 2. Introduce negative reactivity to achieve and maintain subcritical reactor condition.
Thecontrol rods and CRD assemblies adjust the concentration of the neutron absorber in the coreduring normal operations and shutdown conditions.
- 3. Introduce emergency negative reactivity to make the reactor subcritical.
When a ReactorProtection System scram signal is received, high pressure water is applied to the CRDassemblies to rapidly insert each control rod into the core. The core plate differential pressureand standby liquid control line provides a flowpath for injecting a neutron absorber into thereactor core when control rods are unavailable.
- 4. Sense process conditions and generate signals for reactor trip or engineered safetyfeatures actuation.
Neutron flux detectors within the reactor core initiate a Reactor Protection LaSalle County Station, Units 1 and 2License Renewal Application 2.3-13 Section 2 -Scoping and Screening Methodology and ResultsSystem scram signal to shutdown the reactor upon a high flux condition.
- 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 asafety-related function.
The nonsafety-related steam dryer could interact with safety-related components.
- 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 (10CFR 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). TheReactor Vessel Internals system includes CRD assemblies and control rod blades that arerequired to achieve and maintain safe shutdown of the reactor.
- 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). TheReactor Vessel Internals system includes CRD assemblies and control rod blades that arerequired to achieve and maintain safe shutdown of the reactor.
UFSAR References 1.2.2.3.2 Table 3.2-13.9.54.1.25.2.2License Renewal Boundary DrawingsNone.LaSalle County Station, Units 1 and 2 2.3-14License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.1-3Reactor Vessel Internals Components Subject to Aging Management ReviewComponent Type Intended FunctionCore Shroud (Including Repairs) and Structural Support to maintain coreCore Plate: Core Shroud (Upper, Central, configuration and flow distribution Lower)Core Shroud (Including Repairs) and Structural Support to maintain coreCore Plate: Shroud Support Structure configuration and flow distribution (Shroud Support Cylinder, ShroudSupport Plate, Shroud Support Legs andGussets)Core Shroud and Core Plate: Access Direct FlowHole Cover (Welded Covers)Core Shroud and Core Plate: Core Plate, Structural Support to maintain coreCore Plate Bolts configuration and flow distribution Core Shroud and Core Plate: LPCI Direct FlowCouplingCore Spray Lines and Spargers:
Core Direct FlowSpray Lines (Headers),
Spray Rings,Spray NozzlesFuel Supports and Control Rod Drive Structural Support to maintain coreAssemblies:
Orificed Fuel Support configuration and flow distribution ThrottleInstrumentation:
Intermediate Range Structural Support to maintain coreMonitor (IRM) Dry Tubes, Source Range configuration and flow distribution Monitor (SRM) Dry Tubes, Incore NeutronFlux Monitor Guide TubesJet Pump Assemblies:
Castings Direct FlowJet Pump Assemblies:
Inlet Riser and Direct FlowBrace, Holddown Beam, Diffuser,
- Tailpipe, Wedges, and RepairComponents Reactor Vessel Internals Components:
Structural Support to maintain coreControl Rod Drive Guide Tube configuration and flow distribution Reactor Vessel Internals Components:
Direct FlowCore Plate DP/SLC LineSteam Dryers Structural Integrity Top Guide Structural Support to maintain coreconfiguration and flow distribution The aging management review results for these components are provided in:Table 3.1.2-3Reactor Vessel Internals Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-15 Section 2 -Scoping and Screening Methodology and Results2.3.2 ENGINEERED SAFETY FEATURES SYSTEMSThe 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 2.3-16License Renewal Application Section 2 -Scoping and Screening Methodology and Results2.3.2.1 High Pressure Core Spray SystemDescription The High Pressure Core Spray (HPCS) System is a standby high pressure emergency corecooling 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 HPCSsystem provides and maintains an adequate coolant inventory inside the reactor vessel tomaintain fuel cladding temperatures below fragmentation temperature in the event of breaks inthe reactor coolant pressure boundary.
For small breaks that do not result in rapid reactordepressurization, the HPCS system spray maintains reactor water level and depressurizes thevessel. For large breaks, the HPCS system sprays the top surface of the core to cool the coreuntil 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 theprimary 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 HPCSSystem. After entering the vessel, HPCS flow divides and enters the shroud at two pointsnear the top of the shroud. A semicircular sparger is attached to each outlet. Nozzles arespaced around the spargers to spray the water radially over the core and into the fuelassemblies.
The HPCS System injection piping is provided with an isolation valve on eachside 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 primarycontainment (drywell) high pressure signal, or can be initiated manually.
The HPCS System isindependent 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 froma 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.
BoundaryThe HPCS scoping boundary begins at the HPCS suction strainer in the suppression pool andcontinues through suction piping and a primary containment isolation valve, through the HPCSpump, and terminates at the upstream side of the HPCS discharge outboard primarycontainment 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 atthe discharge of the HPCS pump and continues through primary containment isolation valvesprior 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 thedischarge piping of the HPCS pump.All associated piping, components and instrumentation contained within the boundarydescribed above are also included in the HPCS scoping boundary.
LaSalle County Station, Units 1 and 2 2.3-17License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsAlso 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe nonsafety-related portions of the system located within the Reactor Building.
Included inthis boundary are pressure-retaining components relied upon to preserve the leakageboundary intended function of this portion of the system. For more information, refer to theLicense 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 outboardprimary 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 andaround the core periphery.
This is evaluated with the Reactor Vessel Internals license renewalsystem.Not included in the HPCS System scoping boundary are the HPCS Diesel Generators.
TheHPCS Diesel Generators are evaluated with the Diesel Generator and Auxiliaries licenserenewal system.Not included in the scope of license renewal are the nonsafety-related portions of the HPCSsupply and return pipes from the cycled condensate storage tank to the Reactor Building asthese 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. TheHigh 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 CFR54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform afunction 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 CFR50.63). The High Pressure Core Spray System is not relied upon in any safety analyses orplant 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 primarycontainment isolation valves on the HPCS suction from the suppression pool, HPCS reliefvalve discharge piping, and the HPCS full flow test and minimum flow lines. 10 CFR54.4(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 pressureboundary by delivering water from the suppression pool through nozzles in a circular spargerLaSalle County Station, Units 1 and 2 2.3-18License Renewal Application Section 2 -Scoping and Screening Methodology and Resultslocated above and around the core periphery.
- 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The HPCS System contains nonsafety-related water filled lines in theReactor 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 HPCSSystem is credited for Fire Safe Shutdown by supporting the basic safe-shutdown methodsystem. 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.
- 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). TheHPCS System is credited for reactor cooling and make-up for Station Blackout coping. 10CFR 54.4(a)(3)
UFSAR References 1.2.2.5.1 Table 3.2-1Table 6.1-1Table 6.2-21Table 6.2-286.3.2.2.1 7.3.1.2.1 License Renewal Boundary Drawingqs LR-LAS-M-95, Sheet 1LR-LAS-M-141, Sheet 1LR-LAS-M-91, Sheet 5LR-LAS-M-1 37, Sheet 5LR-LAS-M-2095, Sheet 1LR-LAS-M-2141, Sheet 1LaSalle County Station, Units 1 and 2 2.3-19License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.2-1High Pressure Core Spray SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureFlow Device Pressure BoundaryThrottlePiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (HPCS Pump) Pressure BoundaryPump Casing (Water Leg Pump) Pressure BoundaryStrainer Element FilterPressure BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.2.2-1High Pressure Core Spray SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-20 Section 2 -Scoping and Screening Methodology and Results2.3.2.2 Low Pressure Core Spray SystemDescription The Low Pressure Core Spray System (LPCS) is a standby system designed to provide corecooling following a break in the reactor coolant pressure boundary which would rapidlydepressurize 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 corespray 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 coolantpressure 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.
TheLPCS also includes a water leg pump which functions to keep the ECCS discharge lines filledto avoid hydrodynamic effects on ECCS pump initiation.
The LPCS water leg pump servicesthe 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 bymeans of pressure switches located in the pump discharge piping upstream of the pumpdischarge 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 primarycontainment do not operate any LPCS valves which could affect flow to the reactor pressurevessel. The LPCS also includes relief valves for overpressure protection of the LPCS pumpsuction and discharge piping. These relief valves discharge into the suppression pool and arealso primary containment isolation valves.The LPCS contains components that are environmentally qualified.
The LPCS primarycontainment isolation valves are credited for Station Blackout coping. The LPCS water legpump is credited for Fire Safe Shutdown by supporting the "A" loop of RHR which is a basicmethod system.For more detailed information see UFSAR Section 6.3.2.2.3.
BoundaryThe LPCS scoping boundary begins at the LPCS suction strainer in the suppression pool andcontinues through suction piping and a primary containment isolation valve, through the LPCSpump, and terminates at the upstream side of the LPCS discharge outboard primarycontainment 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 atthe discharge of the LPCS pump and continue through primary containment isolation valvesprior 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 theLaSalle County Station, Units 1 and 2 2.3-21License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsdischarge piping of the LPCS pump and discharge piping of the "A" RHR pump.All associated piping, components and instrumentation contained within the boundarydescribed 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe nonsafety-related portions of the system located within the Reactor Building.
Included inthis boundary are pressure-retaining components relied upon to preserve the leakageboundary intended function of this portion of the system. For more information, refer to theLicense 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 thereactor vessel. These components are evaluated with the Reactor Coolant PressureBoundary license renewal system.Not included in the LPCS scoping boundary is the circular sparger located above and aroundthe core periphery.
This is evaluated with the Reactor Vessel Internals license renewalsystem.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. TheLow 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 CFR54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform afunction 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 CFR50.63). The Low Pressure Core Spray System is not relied upon in any safety analyses orplant 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 primarycontainment isolation valves on the LPCS suction from the suppression pool, LPCS reliefvalve 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 bydelivering water from the suppression pool through nozzles in a circular sparger located aboveand around the core periphery.
- 3. Sense process conditions and generate signals for reactor trip or engineered safetyfeatures 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 2.3-22License Renewal Application Section 2 -Scoping and Screening Methodology and Results4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The LPCS contains nonsafety-related water filled lines in the ReactorBuilding 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 LPCSwater leg pump is credited for Fire Safe Shutdown by supporting the "A" loop of RHR which isa 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.
- 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). TheLPCS primary containment isolation valves are credited for Station Blackout coping. 10 CFR54.4(a)(3)
UFSAR References 1.2.2.5.3 Table 3.2-1Table 6.1-1Table 6.2-21Table 6.2-286.3.2.2.3 7.3.1.2.2 7.3.1.2.3 Chapter 15Table 15.9-4License Renewal Boundary DrawingsLR-LAS-M-94, Sheet 1LR-LAS-M-140, Sheet 1LR-LAS-M-91, Sheet 5LR-LAS-M-96, Sheet 1LR-LAS-M-1 37, Sheet 5LR-LAS-M-142, Sheet 1LaSalle County Station, Units 1 and 2 2.3-23License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.2-2Low Pressure Core Spray SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureFlow Device Pressure BoundaryThrottlePiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (LPCS Pump) Pressure BoundaryPump Casing (Water Leg Pump) Pressure BoundaryStrainer Element FilterPressure BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.2.2-2Low Pressure Core Spray SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-24 Section 2 -Scoping and Screening Methodology and Results2.3.2.3 Reactor Core Isolation Cooling SystemDescription The Reactor Core Isolation Cooling (RCIC) System is a standby system designed to ensurethat sufficient reactor water inventory is maintained in the reactor pressure vessel (RPV) toallow 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 arenot in scope.Although not a safety system, the purpose of the RCIC System is to provide makeup water tothe RPV when the vessel is isolated.
The RCIC System accomplishes this by pumping waterfrom the cycled condensate storage tank or directly from the suppression pool or from thesuppression pool via the RHR heat exchangers, depending on reactor conditions, anddischarges it through the head spray nozzle of the RPV to maintain reactor water level. Thiscapability prevents reactor fuel from overheating when (1) the reactor vessel is isolated andmaintained in the hot standby condition, (2) the reactor vessel is isolated and accompanied byloss of the coolant flow from the reactor feedwater system, or (3) the reactor vessel isshutdown under condition of loss of the normal feedwater system and prior to operation of theshutdown cooling system.The RCIC System utilizes a steam-driven turbine-pump unit which operates automatically tomaintain adequate water level in the RPV. The RCIC System steam supply is from the RPVupstream of the main steam isolation valves. The RCIC System supports RPVdepressurization to a shutdown condition with the reactor coolant pressure boundary isolatedby maintaining sufficient RPV water inventory.
The RCIC System continues to operate untilthe RPV is depressurized to the point at which low pressure coolant injection and low pressurecore spray system operation can maintain core cooling.The RCIC System operation is initiated automatically by reactor vessel low water level or canbe initiated manually.
The RCIC System can be operated on DC emergency power withoutthe need for AC emergency power.For more detailed information, see UFSAR Sections 5.4.6 and 7.4.1.BoundaryThe RCIC System license renewal scoping boundary for water injection begins at the RCICpump suction piping from the cycled condensate storage tank at the flange directly upstreamof 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. Thedischarge flow path continues through the discharge of the RCIC pump, and terminates at theRCIC injection valve outside of primary containment.
The discharge path also includes aminimum 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 theoutboard RCIC containment isolation valve and continues through the RCIC turbine, and theRCIC turbine exhaust to the suppression pool. Auxiliary systems include gland seal, drainpots, and turbine lubricating and control oil.LaSalle County Station, Units 1 and 2 2.3-25License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsAll associated piping, components and instrumentation, contained within flow paths andsubsystems 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe nonsafety-related portions of the system located within the Reactor Building.
Included inthis boundary are pressure-retaining components relied upon to preserve the leakageboundary intended function of this portion of the system. For more information, refer to theLicense 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 ofcontainment to the reactor vessel. These components are evaluated with the Reactor CoolantPressure 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 RCICsteam isolation valve. These components are evaluated with the Reactor Coolant PressureBoundary license renewal system.Not included in the scope of license renewal are the abandoned RCIC System lines located inthe Off Gas Filter Building.
These lines are verified to be isolated,
- drained, and vented andtherefore do not present a spatial interaction hazard to safety-related equipment.
Also notincluded in the scope of license renewal are the RCIC System water return lines to the cycledcondensate storage tanks. These lines are nonsafety-related and are not located in areaswhere there are potential spatial interactions with components performing safety-related functions, and therefore are not relied upon to perform or support any system intendedfunction.
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 steamisolation valve. These components are evaluated with the Reactor Coolant PressureBoundary 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 basisevents. The Reactor Core Isolation Cooling System meets 10 CFR 54.4(a)(2) because failureof nonsafety-related portions of the system could prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
The Reactor Core Isolation Cooling System alsomeets 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 FireProtection (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 safetyanalyses or plant evaluations to perform a function that demonstrates compliance with theCommission's regulations for Anticipated Transient Without Scram (10 CFR 50.62).LaSalle County Station, Units 1 and 2 2.3-26License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsIntended Functions
- 1. Remove residual heat from the reactor coolant system. The RCIC System is capable ofmaintaining sufficient coolant inventory in the reactor vessel in case of an isolation with a lossof main feedwater flow. 10 CFR 54.4(a)(1)
- 2. Provide primary containment boundary.
The RCIC System includes safety-related primarycontainment isolation valves on the RCIC suction from the suppression pool, HPCS reliefvalve 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 asafety-related function.
The RCIC System includes nonsafety-related water filled lines in theReactor Buildings that have the potential for spatial interactions (spray or leakage) orstructurally 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 RCICSystem supports Safe Shutdown.
- 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.
- 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 RCICSystem can be operated without AC power during a station blackout event to provide coolantto the reactor vessel. 10 CFR 54.4(a)(3)
UFSAR References 1.2.2.35.4.67.4.1License Renewal Boundary DrawingsLR-LAS-M-74, Sheet 1LR-LAS-M-91, Sheet 5LR-LAS-M-94, Sheet 1LR-LAS-M-96, Sheet 4LR-LAS-M-101, Sheets 1, 2LR-LAS-M-127, Sheet 1LR-LAS-M-137, Sheet 5LR-LAS-M-140, Sheet 1LR-LAS-M-142, Sheet 4LR-LAS-M-147, Sheets 1, 2LaSalle County Station, Units 1 and 2 2.3-27License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.2-3Reactor Core Isolation Cooling SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureFlow Device Pressure BoundaryThrottleHeat Exchanger
-(Lube Oil Cooler) Shell Pressure BoundarySide Components Heat Exchanger
-(Lube Oil Cooler) Tube Pressure BoundarySheetHeat Exchanger
-(Lube Oil Cooler) Heat TransferTubes Pressure BoundaryHoses Leakage BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (Condenser Condensate Leakage BoundaryPump)Pump Casing (Condenser Vacuum Leakage BoundaryPump)Pump Casing (RCIC Pump) Pressure BoundaryPump Casing (Turbine Main Oil Pump) Pressure BoundaryPump Casing (Water Leg Pump) Pressure BoundaryRupture Disks Pressure BoundaryStrainer Element FilterPressure BoundaryTanks (Turbine Lube Oil Reservoirs)
Pressure BoundaryTanks (Vacuum Tank) Leakage BoundaryTurbine Casings (RCIC Turbine)
Pressure BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.2.2-3Reactor Core Isolation Cooling SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-28 Section 2 -Scoping and Screening Methodology and Results2.3.2.4 Residual Heat Removal SystemDescription The Residual Heat Removal (RHR) System is a standby heat removal system that alsoprovides a low pressure emergency core cooling system (ECCS) function to supply coolingwater 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 coolantinjection (LPCI) function of the RHR System is designed to provide cooling to the reactor corewhen 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) andHigh Pressure Core Spray System (HPCS), the effective core cooling capability of LPCI isextended to small breaks. The RHR System has multiple
- purposes, listed below. Itaccomplishes 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 coolingsystem. The function of LPCI is to cool the reactor core by flooding the reactor pressurevessel (RPV) following a loss of coolant accident (LOCA). LPCI is automatically actuated bylow reactor water level or high drywell pressure.
LPCI takes water from the suppression pooland injects water directly into the core shroud. Reactor pressure must be reduced belownormal 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 rapidlydepressurizes.
It also provides protection during a small break after ADS has reducedpressure 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 eventwill not render all of the loops inoperable.
The suppression pool cooling mode is used to cool the suppression pool during normal andemergency situations.
The purpose of this mode is to remove the heat that gets transferred tothe 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 bythe Essential Cooling Water System.The shutdown cooling and RPV head spray mode maintains the reactor core in a coldshutdown condition and meets the requirements for long-term heat removal.
This mode isused to remove decay heat, prevent thermal stratification, and cool the reactor formaintenance and refueling.
It also provides a flowpath for core cooling during emergency situations when the normal injection flow path is unavailable.
Shutdown cooling takes waterfrom the RPV, cools it in a heat exchanger cooled by the Essential Cooling Water System andthen returns the water to the RPV where it is forced through the reactor core. Head spray isused to condense steam and cool the RPV head during RPV flooding operations and toprevent thermal stratification during shutdown cooling.
Head spray diverts some of theshutdown 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 modeof heat removal is unavailable.
The full flow test mode allows testing of certain RHR System components for systemoperability during all modes of reactor operation without having to inject water directly into theLaSalle County Station, Units 1 and 2 2.3-29License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsRPV. The difference between the suppression pool cooling and full flow test modes is that inthe test mode the heat exchanger bypass valve remains open.The suppression chamber/drywell spray mode is used to condense any steam that may nothave completely condensed in the suppression pool and drywell following a LOCA. It alsoprovides an additional method of containment cooling that can be used in an emergency.
Thesuppression pool is sprayed from a spray header installed in the inner circumference of theupper air space of the chamber and fed from either RHR A or B loops. The drywell is sprayedfrom either of two ring spray headers inside the drywell.
One drywell spray header is suppliedby 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 thefuel 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 thatspool 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 locatedin 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 beused to remove water from the reactor while in shutdown cooling.
Instead of returning all thewater 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 leveland to drain water from the suppression pool during maintenance.
The RHR 'B' loop can takewater 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.BoundaryThe RHR System license renewal scoping boundary begins with the strainers in thesuppression 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 throughdischarge piping and valves to the reactor containment where it interfaces with the LPCIportion of the Reactor Coolant Pressure Boundary (RCPB) System at the outboardcontainment isolation valve for each LPCI injection line. The boundary also includes the pipingand valves in the suction flowpath from the reactor recirculation suction line, which begins atthe outboard containment isolation valve (part of the RCPB System) and continues to the RHRSystem pump suction headers.
Also included are the RHR heat exchangers (RHR flowpath isthrough the shell side), including piping and valves in the lines to the heat exchangers andfrom them to the shutdown cooling injection outboard isolation valves (part of the RCPBSystem),
and to the drywell spray, head spray and suppression pool spray and returnflowpaths described below. The Essential Cooling Water System provides cooling water to theRHR heat exchanger tube side components.
The RHR pump discharge flowpath includes thepiping and valves to the containment spray piping (drywell and suppression pool), terminating at the spray rings and nozzles inside containment.
The system scoping boundary alsoincludes piping and valves in the full-flow test lines and minimum flow recirculation lines fromthe pump discharge to the suppression pool. The water leg fill portion of the RHR Systembegins at the suction of the RHR pump and continues through the water leg pump suctionpiping, through the water leg pump, and terminates at the discharge piping of the RHR pump.LaSalle County Station, Units 1 and 2License Renewal Application 2.3-30 Section 2 -Scoping and Screening Methodology and ResultsAll associated piping, components and instrumentation contained within the boundarydescribed 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe nonsafety-related portions of the system located within the Reactor Building.
Included inthis boundary are pressure-retaining components relied upon to preserve the leakageboundary intended function of this portion of the system. For more information, refer to theLicense 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 ReactorCoolant 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. TheResidual 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 for10 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 thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48), 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 plantevaluations 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 primarycontainment isolation capability on containment spray discharge, suppression pool suction,and test return lines penetrating the primary containment.
- 2. Remove residual heat from the reactor coolant system. The RHR System removes decayand 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 coreregion 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 forspraying the drywell and suppression pool vapor spaces to maintain internal pressure belowdesign limits. 10 CFR 54.4(a)(1)
- 5. Sense process conditions and generate signals for reactor trip or engineered safetyLaSalle County Station, Units 1 and 2 2.3-31License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsfeatures actuation.
The RHR System provides for associated actuation and system protection logic for engineered safety features operation.
- 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 asafety-related function.
The RHR System contains nonsafety-related fluid filled lines within theReactor Buildings which have the potential for spatial interaction with safety-related SSCs. 10CFR 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 RHRSystem is credited for reactor makeup and heat removal for Fire Safe Shutdown.
- 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. Relied upon in safety analyses or plant evaluations to perform a function thatdemonstrates compliance with the Commission's regulations for Station Blackout (10 CFR50.63). The primary containment isolation and decay heat removal functions of the RHRSystem are credited for Station Blackout coping. 10 CFR 54.4(a)(3)
UFSAR References 5.4.76.2.1.16.2.26.3.16.3.27.4.3License Renewal Boundary DrawingsLR-LAS-M-96, Sheets 1, 2, 3, 4, 5LR-LAS-M-142, Sheets 1, 2, 3, 4, 5LR-LAS-M-91, Sheet 5LR-LAS-M-94, Sheet 1LR-LAS-M-95, Sheet 1LR-LAS-M-101, Sheet 1LR-LAS-M-115, Sheets 1, 12LR-LAS-M-1 37, Sheet 5LR-LAS-M-140, Sheet 1LR-LAS-M-141, Sheet 1LR-LAS-M-147, Sheet 1LR-LAS-M-159, Sheet 1LaSalle County Station, Units 1 and 2 2.3-32License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.2-4Residual Heat Removal SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureFlow Device Pressure BoundaryThrottleHeat Exchanger
-(RHR Heat Exchanger)
Pressure BoundaryShell Side Components Heat Exchanger
-(RHR Heat Exchanger)
Pressure BoundaryTube SheetHeat Exchanger
-(RHR Heat Exchanger)
Heat TransferTubes Pressure BoundaryHoses Pressure BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (RHR Pump) Pressure BoundaryPump Casing (Water Leg Pump) Pressure BoundarySpray Nozzles SprayStrainer Element FilterPressure BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.2.2-4Residual Heat Removal SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-33 Section 2 -Scoping and Screening Methodology and Results2.3.2.5 Standby Gas Treatment SystemDescription The Standby Gas Treatment (SGT) System is a standby system designed to reduce halogenand particulate concentrations in gases leaking from the Primary Containment and which arepotentially present in the secondary containment following an accident.
The system alsoprovides an alternate means of purging the Primary Containment.
The SGT System is inscope for license renewal.The SGT System is part of secondary containment.
When initiated, the system takes suctionon the secondary containment, treats the air flowing through the system, and then releasesthat air to the environment via an elevated release point. The SGT System maintains a slightlynegative internal secondary containment pressure to prevent any untreated air leakage frombeing released to the environment.
The SGT System is designed to function during a designbasis 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 normallyin standby, and automatically starts and operates during design basis accidents.
The SGT System is a safety-related system. SGT System equipment is powered from theessential 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.BoundaryThe SGT System consists of two independent subsystems that are shared between Unit 1 andUnit 2, each with its own set of ductwork,
- dampers, charcoal filter train, and isolation andcontrol dampers, interconnecting pipes, and associated instrumentation.
Each charcoal filtertrain 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 exhauststack 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 boundarydescribed 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe nonsafety-related portions of the system located within the Reactor Building.
Included inthis boundary are pressure-retaining components relied upon to preserve the leakageboundary intended function of this portion of the system, specifically the filter plenum moisturecollection and drain pans. Also included in the license renewal scoping boundary of the SGTSystem are those portions of nonsafety-related piping components relied upon to preserve thestructural integrity intended function of this portion of the system. For more information, referto 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 delugespray piping, headers, valves, and temperature detectors.
These components perform a fireLaSalle County Station, Units 1 and 2 2.3-34License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsprotection
- 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. TheStandby 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 for10 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 thatdemonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49). The Standby Gas Treatment System is not relied upon in any safetyanalyses or plant evaluations to perform a function that demonstrates compliance with theCommission's regulations for Fire Protection (10 CFR 50.48), Anticipated Transient WithoutScram (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 SGTSystem maintains a negative pressure within secondary containment, and reduces halogenand particulate concentrations in gases potentially present in the secondary containment following an accident prior to release to the environment.
- 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The SGT System includes nonsafety-related piping that structurally interacts with safety-related SSCs, and water filled components that have the potential forspatial 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.
UFSAR References 6.5.17.3.8License Renewal Boundary Drawinqis LR-LAS-M-89, Sheet 1LR-LAS-M-92, Sheet 1LR-LAS-M-105, Sheet 1LR-LAS-M-138, Sheet 1LR-LAS-M-153, Sheet 1LaSalle County Station, Units 1 and 2 2.3-35License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.2-5Standby Gas Treatment SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureDucting and Components Leakage BoundaryPressure BoundaryFlexible Connection Pressure BoundaryPiping, piping components, and piping Pressure Boundaryelements Structural Integrity Valve Body Pressure BoundaryThe aging management review results for these components are provided in:Table 3.2.2-5Standby Gas Treatment SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 23-36 Section 2 -Scoping and Screening Methodology and Results2.3.3 AUXILIARY SYSTEMSThe 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 2.3-37License Renewal Application Section 2 -Scoping and Screening Methodology and Results2.3.3.1 Closed Cycle Cooling Water SystemDescription The Closed Cycle Cooling Water System (CCW) is a normally operating closed cooling watersystem designed to provide cooling water to various plant components.
The CCW consists of the reactor building closed cooling water system and turbine buildingclosed cooling water system. The CCW is in scope for license renewal.
- However, portions ofthe 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 providecooling 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 servicewater system through the reactor building closed cooling water heat exchangers.
The reactorbuilding 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 primarycontainment and are provided with safety-related and environmentally qualified motoroperated primary containment isolation valves. The primary containment isolation boundaryalso includes pressure relief valves to protect the containment penetration piping fromoverpressurization when it is isolated during a LOCA. The pressure relief valves also functionas primary containment isolation valves.The purpose of the turbine building closed cooling water system portion of the CCW is toprovide cooling water to various components in the Turbine Building.
The systemaccomplishes this by circulating demineralized and chemically treated cooling water throughthese components and transferring the heat to the plants service water system through theturbine building closed cooling water heat exchangers.
The turbine building closed coolingwater system portion of the CCW does not perform an intended function and is not in scope forlicense renewal.For more detailed information see UFSAR Sections 9.2.3 and 9.2.8.BoundaryThe reactor building closed cooling water portion of the CCW license renewal scopingboundary begins at the reactor building closed cooling water pumps and continues through thefollowing 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 airconditioning unit, drywell pneumatic system compressors and aftercoolers, drywell equipment drain sump heat exchanger, and drywell sump sample pump. The boundary continues fromthese heat loads through the reactor building closed cooling water heat exchangers prior toreturning to the reactor building closed cooling water system pumps. The boundary includesthe reactor building closed cooling water expansion tank and reactor building closed coolingwater chemical feeder.The reactor building closed cooling water portion of the CCW license renewal scopingLaSalle County Station, Units 1 and 2 2.3-38License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsboundary also includes the following primary containment heat loads: reactor recirculation system pump motor coolers, pump seals, and pump bearings (evaluated with the ReactorCoolant Pressure Boundary),
and drywell penetration cooling coils. Each primary containment influent and effluent line includes two motor operated containment isolation valves and apressure relief valve for overpressure protection.
All associated piping, components and instrumentation contained within the boundarydescribed above are also included in the CCW scoping boundary.
Also included in the reactor building closed cooling water portion of the CCW System scopingboundary are those portions of nonsafety-related piping and equipment that extend beyond thesafety-related/nonsafety-related interface up to the location of the first seismic anchor, or to apoint where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of thesystem located within the Reactor Building, Primary Containment, and Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve theleakage boundary intended function of this portion of the system. For more information, referto 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 waterportion of the CCW System since the turbine building closed cooling water system does notperform or support system intended functions.
The turbine building closed cooling watersystem portion of the CCW does not include pressure-retaining components located in areaswhere there are potential spatial interactions with components performing safety-related functions, and is not required to maintain leakage boundary integrity to preclude systeminteraction.
Therefore, the turbine building closed cooling water system portion of the CCW isnot 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 basisevents. The Closed Cycle Cooling Water System meets 10 CFR 54.4(a)(2) because failure ofnonsafety-related portions of the system could prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
The Closed Cycle Cooling Water System alsomeets 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 forEnvironmental Qualification (10 CFR 50.49). The Closed Cycle Cooling Water System is notrelied 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 primarycontainment isolation valves. 10 CFR 54.4(a)(1)
- 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The CCW contains nonsafety-related water filled lines in the ReactorBuilding, Primary Containment, and Auxiliary Building which provide structural support or havepotential spatial interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
LaSalle County Station, Units 1 and 2 2.3-39License Renewal Application Section 2 -Scoping and Screening Methodology and Results3. 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.
UFSAR References 1.2.2.6.1 Table 3.2-16.2.4.2.2 Table 6.2-21Table 6.2-289.2.39.2.811.5.2.3.5 License Renewal Boundary DrawingsLR-LAS-M-90, Sheets 1, 2, 3LR-LAS-M-136, Sheets 1,2, 3LR-LAS-M-66, Sheets 5, 9, 10, 11LR-LAS-M-91, Sheets 2, 3, 4, 5LR-LAS-M-104, Sheet 1LR-LAS-M-1 15, Sheets 1, 2LR-LAS-M-1 37, Sheets 2, 3, 4, 5LR-LAS-M-149, Sheet 1LR-LAS-M-1 53, Sheets 4, 6LR-LAS-M-159, Sheets 1, 2LaSalle County Station, Units 1 and 2 2.3-40License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.3-1Closed Cycle Coolinq Water SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureHeat Exchanger
-(CRD Feed Pump Leakage BoundaryBearing and Gear Oil Coolers)
Tube SideComponents Heat Exchanger
-(Clean-up Non- Leakage BoundaryRegenerative Heat Exchanger)
Shell SideComponents Heat Exchanger
-(Drywell Equipment Leakage.Boundary Drain Sump Heat Exchanger)
Shell SideComponents Heat Exchanger
-(Drywell Penetration Leakage BoundaryCooling Coils) Tube Side Components Heat Exchanger
-(Nitrogen Compressor Leakage BoundaryAftercooler)
Shell Side Components Heat Exchanger
-(Nitrogen Compressor Leakage BoundaryInter-Cooler)
Tube Side Components Heat Exchanger
-(RWCU Pump Heat Leakage BoundaryExchanger)
Tube Side Components Heat Exchanger
-(Reactor Building Leakage BoundaryClosed Cooling Water Heat Exchanger)
Shell Side Components Heat Exchanger
-(Reactor Building Leakage BoundaryEquipment Drain Tank Heat Exchanger)
Shell Side Components Heat Exchanger
-(Reactor Building Leakage BoundaryVentilation Instrument Room A/C Unit)Tube Side Components Hoses Leakage BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (Reactor Building Closed Leakage BoundaryCooling Water Pump)Tanks (Reactor Building Closed Cooling Leakage BoundaryWater Chemical Feeder)Tanks (Reactor Building Closed Cooling Leakage BoundaryWater Expansion Tank)Valve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-1Closed Cycle Cooling Water SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-41 Section 2 -Scoping and Screening Methodology and Results2.3.3.2 Combustible Gas Control SystemDescription The Combustible Gas Control (CGC) System is a standby system designed to ensure thatprimary 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 notincluded in the scope of license renewal.
The purpose of the CGC System includes:
inertingprimary containment with nitrogen, purging containment with air to permit maintenance, controlling containment
- pressure, and controlling combustible gas concentrations after aLOCA. The CGC System includes a nitrogen supply system, containment vent and purgesystem, 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 inlow flow mode for normal makeup, to maintain an inert atmosphere at a slight positivepressure.
The nitrogen supply system is nonsafety-related and is not in scope for licenserenewal since it does not support any intended functions.
The containment vent and purge system can be aligned to supply nitrogen from the nitrogensupply 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 ventand purge system is manually operated to supply makeup nitrogen to maintain a low oxygenconcentration inside primary containment.
The containment atmosphere is contained byprimary containment isolation valves, and is circulated and cooled by the Primary Containment Ventilation System. During post-accident conditions, the containment vent and purge systemcan be used to vent containment by manually over-riding isolation signals and aligning thevent 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 includeremotely operated valves that are automatically closed by the Primary Containment Isolation System upon indications of high drywell pressure, low-low reactor water level, or reactorbuilding or spent fuel pool ventilation exhaust high radiation signals.
The portions of thecontainment vent and purge system that maintain the primary or secondary containment boundary are safety-related, designed to seismic Category I requirements, and are in scopefor 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 thesuppression chamber air space. This operation provides mixing that prevents combustible concentrations of hydrogen from accumulating in low flow areas within the drywell.
Thehydrogen recombining function of the hydrogen recombiners is abandoned in place and notcredited for reducing hydrogen concentration inside containment.
The hydrogen recombiner system includes piping that is part of the primary containment boundary and valves thatautomatically close upon receipt of signals from the primary containment isolation system.During normal plant operation, the hydrogen recombiners are isolated from containment.
Thehydrogen recombiner system is safety-related, designed to seismic Category I requirements, LaSalle County Station, Units 1 and 2 2.3-42License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsand 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.BoundaryThe CGC System license renewal scoping boundary begins at the liquid nitrogen storagetanks and includes an electric water bath vaporizer, ambient air vaporizer, high flow and lowflow pressure/temperature control stations, and associated piping instrumentation and controlsthat are located outdoors.
The CGC System boundary continues to piping that passes throughthe 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 thedrywell air space to the pressure controller used for nitrogen makeup. The portion of thenitrogen supply system that is outside of the primary containment isolation valves does notsupport intended functions and is not in scope for license renewal.The CGC System boundary also includes the drywell and suppression chamber purge airsupply piping that is open to the Reactor Building air space, continuing through the primarycontainment isolation valves to the drywell and suppression chamber air space. Also includedis 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 theCGC System downstream of the secondary containment isolation valves, including the purgeair 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 hydrogenrecombiner packages and back to the suppression chamber air space. Also included is thepiping from the Residual Heat Removal System to the hydrogen recombiner packages andloop seals on the discharge of the hydrogen recombiners, including fill connections from theCondensate System and drain connections to the Plant Drainage System.All associated piping, components and instrumentation contained within the boundarydescribed 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe nonsafety-related portions of the system located within the Reactor Building.
Included inthis boundary are pressure-retaining components relied upon to preserve the leakageboundary intended function of this portion of the system. For more information, refer to theLicense Renewal Boundary Drawing for identification of this boundary, shown in red.Not included in the CGC System scoping boundary are the primary containment hydrogen andoxygen analyzers and pressure monitoring instrumentation, including piping connected toCGC System piping, which are evaluated with the Process Sampling and Post AccidentMonitoring System. The fire suppression deluge valves for the charcoal filters in the purge airfilter train are evaluated with the Fire Protection System. The four vacuum relief valves andassociated piping that connects the drywell and suppression chamber air space and all drywelland suppression chamber penetrations with connections to CGC System piping andcomponents are evaluated with the Primary Containment structure.
LaSalle County Station, Units 1 and 2 2.3-43License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsReason 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. TheCombustible 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 CFR54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform afunction that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49) and Station Blackout (10 CFR 50.63). The Combustible GasControl System is not relied upon in any safety analyses or plant evaluations to perform afunction 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 includespiping and isolation valves that form the primary containment boundary.
- 2. Provide secondary containment boundary.
The Combustible Gas Control System includespiping and isolation valves in the primary containment vent and purge flowpaths that form thesecondary containment boundary.
- 3. Provide emergency heat removal from primary containment and provide containment pressure control.
The Combustible Gas Control System includes flow paths from primarycontainment that are used to vent primary containment for pressure control.
1)4. Control combustible gas mixtures in the primary containment atmosphere.
TheCombustible Gas Control System is credited with establishing, and maintaining an inertatmosphere within primary containment during power operation.
The Combustible GasControl System also includes equipment that provides mixing of the containment atmosphere to prevent combustible mixtures of hydrogen and oxygen from forming following an accident.
- 5. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
Some portions of nonsafety-related piping are relied upon to preservethe structural support intended function of the safety-related piping used for purging, inertingand containment isolation.
Some portions of the discharge and drain piping from the hydrogenrecombiners may be liquid filled and have a potential for spatial interaction with safety-related equipment within the Reactor Building.
- 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 toremain functional during post-accident conditions.
- 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). TheCombustible Gas Control System includes primary containment isolation valves that areLaSalle County Station, Units 1 and 2 2.3-44License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsrequired to close to mitigate a Station Blackout event. 10 CFR 54.4(a)(3)
UFSAR References 6.2.57.3.59.4.109.5.9License Renewal Boundary DrawingsLR-LAS-M-92, Sheets 1, 2LR-LAS-M-1 30, Sheets 1, 2LR-LAS-M-138, Sheets 1, 2LR-LAS-M-96, Sheets 1, 2LR-LAS-M-142, Sheets 1, 2Table 2.3.3-2Combustible Gas Control SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBlower Housing Pressure BoundaryBolting Mechanical ClosureHoses Pressure BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryStructural Integrity Recombiners Pressure BoundaryValve Body Leakage BoundaryPressure BoundaryStructural Integrity The aging management review results for these components are provided in:Table 3.3.2-2Combustible Gas Control SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-45 Section 2 -Scoping and Screening Methodology and Results2.3.3.3 Compressed Air SystemDescription The Compressed Air System (CAS) is a normally operating system designed to providecompressed air for station use. The CAS is in scope for license renewal.
- However, portionsof 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 airplant system. The service air subsystem supplies compressed air for operating pneumatic equipment, air operated
- controls, maintenance
- services, and interruptible equipment such astank mixing air spargers.
The instrument air subsystem supplies compressed air for airoperated control devices and instruments outside the drywell.A portion of the CAS system performs a safety-related function.
The portion of the service airpiping 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.BoundaryThe CAS boundary begins at the intake outside the Turbine Building, proceeds through threecompressor trains which include intake filters and coolers, and discharges to a commonheader which supplies the station air receivers.
Compressed air from the receivers is directedto one of three filter and dryer trains, and is then discharged to the instrument air and serviceair 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 boundarydescribed 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 tothe location of the first seismic anchor. Included in this boundary are those portions ofnonsafety-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 LicenseRenewal Boundary Drawing for identification of this boundary, shown in red.Not included in the CAS System scoping boundary are the containment penetrations which areevaluated 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 anysystem intended function.
LaSalle County Station, Units 1 and 2 2.3-46License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsReason for Scope Determination The Compressed Air System meets 10 CFR 54.4(a)(1) because it is a safety-related systemthat is relied upon to remain functional during and following design basis events. TheCompressed 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 for10 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 thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10CFR 50.62), and Station Blackout (10 CFR 50.63).Intended Functions
- 1. Provide primary containment boundary.
The CAS contains safety-related primarycontainment isolation valves and piping which penetrates the primary containment.
- 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The CAS includes nonsafety-related piping and components that havethe potential for structural interactions with safety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References 9.3.1.2.1 License Renewal Boundary DrawingsLR-LAS-M-82, Sheets 3, 5Table 2.3.3-3Compressed Air SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosurePiping, piping components, and piping Pressure Boundaryelements Structural Integrity Valve Body Pressure BoundaryStructural Integrity The aging management review results for these components are provided in:Table 3.3.2-3Compressed Air SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 23-47 Section 2 -Scoping and Screening Methodology and Results2.3.3.4 Control Rod Drive SystemDescription The Control Rod Drive (CRD) System is a normally operating, high pressure hydraulic systemdesigned 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) systemwhich is included with the license renewal Reactivity Control System. The CRD System alsoincrementally positions control rods in response to signals from the plant rod controlmanagement 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 notrequired to perform intended functions and are not in scope.The primary safety-related purpose of the CRD System is to support rapid insertion of negativereactivity 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 corereactivity and control reactor power during normal reactor operation by inserting orwithdrawing control rods at a controlled rate, one rod at a time. The CRD Systemaccomplishes these functions by providing water at the required operating pressures to thecontrol rod drive mechanisms in response to inputs from the Reactor Protection System, andthe license renewal Reactivity Control System. The CRD System also supplies makeup to thereactor 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 watercleanup 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 cleanhigh pressure water to a flow control station, to the HCUs via the charging water header, thedrive water header, and the cooling water header, each at a different pressure.
The controlrod drive hydraulic system is arranged so that the equipment supporting each control rod drivemechanism is packaged into modular HCUs, one for each control rod drive mechanism.
TheHCUs receive electrical control signals from the Reactivity Control System or ReactorProtection System and direct water to and from the control rod drive mechanisms to move thecontrol 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. Storedenergy available from the nitrogen charged accumulators and from reactor pressure providehydraulic energy for rapid simultaneous insertion of control rods. The drive water headerprovides the control rod drive mechanisms with motive force for positioning the control rodsindividually to manage core reactivity.
The cooling water header provides a constant flow ofwater to cool the control rod drive mechanisms to maximize the life of internal seals andmaintain acceptable scram insertion times. An exhaust water header interconnects the HCUsto 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 drivemechanisms.
The scram air header provides a filtered pneumatic supply to scram inlet and outlet valveactuators via the scram solenoid pilot valves and the scram discharge volume vent and drainvalve actuators.
The scram air header is supplied with instrument air from the Compressed AirLaSalle County Station, Units 1 and 2 2.3-48License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsSystem. During a scram, scram solenoid pilot valves de-energize to open scram inlet andoutlet 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 thecontrol rods to rapidly insert. Also, solenoid valves on the scram air header energize to isolateit from the instrument air supply system and vent it to atmosphere upon receipt of a scramsignal 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 thescram outlet valves into the scram discharge volume. The scram discharge volume consistsof a header that drains to an instrument volume consisting of a vertical pipe with water levelinstrumentation.
The scram discharge volume vent and drain valves automatically isolateduring a scram to contain potentially contaminated water from the reactor vessel and tomaintain vessel inventory.
The scram discharge volume is maintained vented and drainedduring normal plant operation and following reset of the scram signal.For more detailed information, see UFSAR Section 4.6.BoundaryThe CRD System scoping boundary includes piping to and from the control rod drivemechanism flanges at the reactor vessel penetrations to the HCUs and back through thescram outlet valves to the scram discharge volume, including the scram instrument volume,level instruments and vent and drain valves. The CRD System scoping boundary alsoincludes the scram air header beginning at the air supply filter and continuing to the back-upscram solenoid valves, solenoid valves actuated by the ARI system, scram solenoid pilotvalves 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 routespressurized 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 volumevent and drain valves and vent the scram air header upon actuation from the ReactorProtection System or the plant ARI system have an active safety-related function and arewithin 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 agingmanagement review.All associated piping, components, and instrumentation contained within the boundarydescribed 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe 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 preservethe 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 inred.Not included in the CRD System scoping boundary are the control rod drive housings and stubtubes that are evaluated with the Reactor Vessel System, and the control rod driveLaSalle County Station, Units 1 and 2 2.3-49License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsmechanisms 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 oflicense 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 notperform 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 systemthat is relied upon to remain functional during and following design basis events. The ControlRod Drive System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions ofthe system could prevent satisfactory accomplishment of function(s) identified for 10 CFR54.4(a)(1).
The Control Rod Drive System also meets 10 CFR 54.4(a)(3) because it is reliedupon 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 CFR50.62), and Station Blackout (10 CFR 50.63).Intended Functions
- 1. Introduce negative reactivity to achieve or maintain subcritical reactor condition.
The HCUsprovide the motive force to the control rod drive mechanisms to rapidly insert control rodsduring a scram event. The scram discharge volume provides a low pressure sink for waterdischarged 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 HCUsprovide containment isolation function from the CRD insert and withdrawal lines. 10 CFR54.4(a)(1)
- 3. Sense process conditions and generate signals for reactor trip or engineered safetyfeatures actuation.
The scram discharge volume includes level instrumentation that causesactuation of the Reactor Protection System upon a high water level condition.
Pressureswitches on the charging water header cause actuation of the Reactor Protection System upona low pressure signal when reactor pressure is low and control rods are withdrawn.
- 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The CRD System includes nonsafety-related water filled, pressure-retaining piping and equipment within the Reactor Building and Auxiliary Building that have thepotential for spatial and structural interaction with safety-related equipment.
- 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 CRDSystem includes equipment that is credited by Fire Safe Shutdown analysis to shutdown thereactor via the scram function.
LaSalle County Station, Units 1 and 2 2.3-50License Renewal Application Section 2 -Scoping and Screening Methodology and Results6. 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 beenvironmentally qualified.
- 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 (10CFR 50.62). The CRD System includes solenoid valves that receive signals from the plantARI 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). Thestation blackout analysis credits the CRD System with successfully inserting all control rodsupon receipt of scram initiation signals from the Reactor Protection System. 10 CFR54.4(a)(3)
UFSAR References Table 3.2-13.9.44.6.14.6.2Table .6.2-217.7.2.2License Renewal Boundary DrawingsLR-LAS-M-90, Sheet 3LR-LAS-M-91, Sheets 5, 6LR-LAS-M-93, Sheets 1, 2LR-LAS-M-1 00, Sheets 1, 2, 3, 4, 5LR-LAS-M-104, Sheet 1LR-LAS-M-136, Sheet 3LR-LAS-M-137, Sheets 5, 6LR-LAS-M-139, Sheets 1, 2LR-LAS-M-146, Sheets 1, 2, 3, 4, 6LR-LAS-M-149, Sheet 1LR-LAS-M-2100, Sheet 2LR-LAS-M-2146, Sheet 2LaSalle County Station, Units 1 and 2 2.3-51License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.3-4Control Rod Drive SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionAccumulator Pressure BoundaryBolting Mechanical ClosureDrip Pan Leakage BoundaryGearbox (CRD Pump) Leakage BoundaryHeat Exchanger
-(CRD Feed Pump Leakage BoundaryBearing and Gear Oil Cooler) Shell SideComponents Piping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (CRD Pump) Leakage BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-4Control Rod Drive SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-52 Section 2 -Scoping and Screening Methodology and Results2.3.3.5 Control Room Ventilation SystemDescription The Control Room Ventilation (CRV) system is a normally operating system designed toensure habitability inside the control rooms and auxiliary electrical equipment rooms during allnormal and abnormal station operating conditions.
The CRV ensures that the control roomoperators 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 controlsand equipment during all station operating conditions.
The CRV license renewal systemconsists of the control room area ventilation plant system, the auxiliary electric equipment room ventilation plant system, the refrigeration plant system, and the breathing air plantsystem. 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 controlroom, main security control center, control room east area and control room toilet under allstation normal and abnormal operating conditions.
These abnormal conditions are ammoniaand high radiation detection at outside air intakes, and smoke detection in return air ducts andoutside air intake. The system accomplishes this using emergency makeup air filter units andrecirculating air filter units, which provide and recirculate clean filtered makeup air in caseswhere the outside air is contaminated.
The system is designed to Seismic Category I requirements with the exception of heatingequipment which is not Seismic Category I, but is seismically supported.
The heatingequipment 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, ata quantity sufficient to maintain positive pressure compared to surrounding areas at all timesexcept 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 providehabitability in the auxiliary electric equipment rooms during both normal and abnormal stationconditions.
The system accomplishes this by aligning to the same emergency makeup filterunits utilized by the control room area ventilation plant system, to provide and recirculate cleanfiltered makeup air in cases where outside air is contaminated.
The auxiliary electricequipment room ventilation subsystem contains its own recirculating filter units.The system is designed to Seismic Category I requirements with the exception of heatingequipment which is not Seismic Category I, but is seismically supported.
The heatingequipment 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 filteredLaSalle County Station, Units 1 and 2 2.3-53License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsoutdoor 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 plantsubsystems is to provide cooling for each of the control room area and auxiliary electricequipment room ventilation air handling systems.
The systems accomplish this through theuse of cooling coils mounted in an air handling unit, a compressor unit, an air cooledcondenser, 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 controlroom personnel.
The system accomplishes this through cylinders with appropriate pressureregulators, 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.BoundaryThe CRV license renewal system boundary begins at the outside air intakes, proceeds throughthe 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.
Thesystem includes the emergency makeup fan and filter train, the refrigeration systemcomponents, and associated
- ductwork, instrumentation and controls.
All associated piping, components, and instrumentation contained within the boundarydescribed 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe nonsafety-related portions of the system located within the Auxiliary Building.
Included inthis boundary are pressure-retaining components relied upon to preserve the leakageboundary intended function of this portion of the system. For more information, refer to theLicense 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 renewalsystem. Additionally, the fire protection function of fire dampers is evaluated with the FireProtection 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 2.3-54License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsReason 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. TheControl Room Ventilation System is not in scope under 10 CFR 54.4(a)(2) because failure ofnonsafety-related portions of the system would not prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
The Control Room Ventilation System also meets10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations toperform a function that demonstrates compliance with the Commission's regulations for FireProtection (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 safetyanalyses or plant evaluations to perform a function that demonstrates compliance with theCommission'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 ensurethe safety and comfort of operating personnel in the control room. The system also monitorsfor the presence of ammonia, radioactive contamination, and smoke; and provides a filteredfresh air supply as necessary in response to these conditions.
- 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 CFR54.4(a)(1)
- 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The Control Room Ventilation System contains nonsafety-related liquid-filled components, specifically the cooling coil drip pans, which have the potential forspatial 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 CRVsystem 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 SafeShutdown 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.
- 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 CRVsystem 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 SBOrecovery.
LaSalle County Station, Units 1 and 2 2.3-55License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsUFSAR References 1.2.3.6.6 6.46.5.19.4.1.19.4.1.27.3.46.4.1 .cLicense Renewal Boundary Drawiniqs LR-LAS-M-1443, Sheets 1, 2, 3, 4LR-LAS-M-1455, Sheet 1LR-LAS-M-1468, Sheets 3, 4, 5, 6LR-LAS-M-1470, Sheet 1LR-LAS-M-129, Sheets 2, 3LR-LAS-M-1 51, Sheet 4LaSalle County Station, Units 1 and 2License Renewal Application 2.3-56 Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.3-5Control Room Ventilation SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureDucting and Components Leakage BoundaryPressure BoundaryFlexible Connection Pressure BoundaryHeat Exchanger
-(Control Room and Aux Heat TransferElec Equip Room HVAC Air-Cooled Condenser)
FinsHeat Exchanger
-(Control Room and Aux Pressure BoundaryElec Equip Room HVAC Air-Cooled Condenser)
Shell Side Components Heat Exchanger
-(Control Room and Aux Heat TransferElec Equip Room HVAC Air-Cooled Pressure BoundaryCondenser)
TubesHeat Exchanger
-(Control Room and Aux Heat TransferElec Equip Room HVAC Supply Coolers)FinsHeat Exchanger
-(Control Room and Aux Pressure BoundaryElec Equip Room HVAC Supply Coolers)Shell Side Components Heat Exchanger
-(Control Room and Aux Heat TransferElec Equip Room HVAC Supply Coolers)
Pressure BoundaryTubesHeat Exchanger
-(Control Room and Aux Pressure BoundaryEquip Room HVAC Refrigerant Compressor Oil Cooler) Shell SideComponents Heat Exchanger
-(Control Room and Aux Heat TransferEquip Room HVAC Refrigerant Pressure BoundaryCompressor Oil Cooler) TubesPiping, piping components, and piping Pressure BoundaryelementsTanks (Control Room and Aux Elec Equip Pressure BoundaryRoom HVAC Refrigerant Receiver)
Valve Body Pressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-5Control Room Ventilation SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-57 Section 2 -Scoping and Screening Methodology and Results2.3.3.6 Cranes, Hoists and Refueling Equipment SystemDescription The Cranes, Hoists and Refueling Equipment System is a standby system comprised of loadhandling bridge cranes, jib cranes, lifting devices, monorails, and hoists provided throughout the facility designed to support operation and maintenance activities.
Also included areequipment 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 andRefueling Equipment System are not required to perform intended functions and are not inscope.The purpose of the Cranes, Hoists and Refueling Equipment System is to safely movematerial and equipment to support operations and maintenance activities.
The Cranes, Hoistsand Refueling Equipment System accomplishes this through compliance with NUREG-0612 and administrative controls such that damage from a postulated heavy load drop does notprevent safe shutdown of the reactor.The reactor building crane services the common refueling floor for both units, and is used to liftheavy loads including the drywell head, the reactor vessel head, vessel internals, and spentfuel casks. The reactor building crane is safety-related, designed to be single failure proof inconformance 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 systemsthroughout the facility.
Cranes and hoists that handle loads over safety-related systems,structures and components are in scope for license renewal.
Postulated failure of thesecranes and hoists could impact a safety-related function.
As a result, the reactor buildingcrane, approximately 60 cranes and hoists, and numerous rigging beams are in scope forlicense renewal.The refueling platform for each unit; including the fuel grapple hoist, frame mounted hoist, andtrolley mounted hoist that are mounted on each refueling platform which are used to handlefuel 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 alsoused to support refueling operations, handle light loads over the reactor cavity, and istherefore 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 machinesare 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.BoundaryThe Cranes, Hoists and Refueling Equipment System scoping boundary includes all thecranes, 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 thathave the potential to handle loads above safety-related components or fuel, as described inthe system description, are within the scope of license renewal.The concrete and steel structures that provide structural support for crane and hoistLaSalle County Station, Units 1 and 2 2.3-58License Renewal Application Section 2 -Scoping and Screening Methodology and Resultscomponents 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 loadbearing structural components such as the bridge, trolley, rail system (rails and rail fasteners),
structural bolts, monorail beams, and jib crane structural members.
Cranes, hoists, andrefueling 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 toservice 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 asafety-related system that is relied upon to remain functional during and following design basisevents. 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 andRefueling Equipment System is not in scope under 10 CFR 54.4(a)(3) because it is not reliedupon 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 CFR50.62), and Station Blackout (10 CFR 50.63).Intended Functions
- 1. Provides physical
- support, shelter and protection for safety-related
- systems, structures, andcomponents.
The reactor building crane is safety-related, seismically qualified, and is used totransport heavy loads over irradiated fuel and above or near safety-related components.
- 2. Provides a safe means for handling safety-related components and loads above or nearsafety-related components.
The Cranes, Hoists and Refueling Equipment Systemcomponents within the scope of license renewal handle equipment or fuel above or nearsafety-related components or spent fuel. 10 CFR 54.4(a)(2)
- 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The nonsafety-related cranes, hoists and refueling equipment that arein scope provide a safe means for handling loads above or near safety-related components.
UFSAR References 9.1.4Appendix 0Table 3.2-1License Renewal Boundary DrawingsNone.LaSalle County Station, Units 1 and 2 2.3-59License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.3-6Cranes, Hoists and Refueling Equipment SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting 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 3.3.2-6Cranes, Hoists and Refueling Equipment SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-60 Section 2 -Scoping and Screening Methodology and Results2.3.3.7 Demineralized Water Makeup SystemDescription The intended function of the Demineralized Water Makeup System for license renewal is tomaintain leakage boundary integrity to preclude system interactions.
For this reason, thissystem's pressure-retaining components located in areas where there is potential spatialinteraction with components performing safety-related functions have been included in thescope of license renewal.
This system is not required to operate to support license renewalintended functions, and is in scope only for potential spatial interaction.
The Demineralized Water Makeup System is a normally operating system designed to providewater from on-site wells, purify the stored well water, and provide it for various usesthroughout the plant, including potable and domestic use and high purity reactor grade waterfor makeup to the clean and cycled condensate storage tanks and various plant systems.
TheDemineralized Water Makeup System consists of the following plant systems:
domestic water,makeup demineralizer, and well water. The Demineralized Water Makeup System is in scopefor license renewal.
- However, portions of the Demineralized Water Makeup system are notrequired to perform or support intended functions and are not included in the scope of licenserenewal.Well Water SystemThe purpose of the well water system is to provide a source of ground water to supply plantneeds. The well water system accomplishes this by pumping water from two on-site deepwells, filtering the water through trailer mounted sand filters to remove iron, manganese, andsuspended matter, for storage in the 350,000 gallon well water storage tank.Makeup Demineralizer SystemThe purpose of the makeup demineralizer system is to purify the water stored in the well waterstorage 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 mounteddemineralizers and filters to purify water to meet reactor grade water quality requirements.
Aportion of the original demineralized water makeup system is abandoned in place and theregeneration capability of the makeup demineralizers has been removed.Domestic Water SystemThe purpose of the domestic water system is to provide potable water for domestic use onsite. The domestic water system accomplishes this by processing water from the well waterstorage tank. Water for domestic consumption is chlorinated and filtered to meet drinkingwater 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.BoundaryThe license renewal scoping boundary of the Demineralized Water Makeup Systemencompasses the liquid filled portions of nonsafety-related piping and equipment located inareas where there is potential spatial interaction with safety-related equipment.
This includesLaSalle County Station, Units 1 and 2 2.3-61License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsthe nonsafety-related portions of the system located within the Reactor Buildings and theAuxiliary Building.
Included in this boundary are pressure-retaining components relied upon topreserve the leakage boundary intended function of this system. This includes thedemineralized water supply line to the Nonessential Cooling Water System clean gland waterstorage tank and HVAC evaporative coolers and humidifiers in the Auxiliary Building and thedomestic water distribution piping in the Reactor Buildings and Auxiliary Building.
For moreinformation, 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 renewalsystem. The inactive portions of the system that do not perform or support an intendedfunction and are not located in areas where there are potential spatial interactions withcomponents performing safety-related functions, are not included in the scope of licenserenewal.Reason for Scope Determination The Demineralized Water Makeup System is not in scope under 10 CFR 54.4(a)(1) becauseno portions of the system are safety-related or relied upon to remain functional during andfollowing design basis events. The Demineralized Water Makeup System meets 10 CFR54.4(a)(2) because failure of nonsafety-related portions of the system could preventsatisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
TheDemineralized Water Makeup System is not in scope under 10 CFR 54.4(a)(3) because it isnot 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 CFR50.62), or Station Blackout (10 CFR 50.63).Intended Functions
- 1. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The Demineralized Water Makeup System contains nonsafety-related liquid-filled lines in the Reactor Building and Auxiliary Building which have potential spatialinteractions with safety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References 1.2.3.6.4 2.4.13.1.3 9.2.49.2.59.4.3.4.2 9.4.4.210.4.7.2LaSalle County Station, Units 1 and 2 2.3-62License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsLicense Renewal Boundary DrawinasLR-LAS-M-76, Sheet 4LR-LAS-M-77, Sheet 1LR-LAS-A-615, Sheet 1LR-LAS-A-616, Sheet 1LR-LAS-A-617, Sheet 1LR-LAS-A-595, Sheet 1LR-LAS-M-1455, Sheet 1LR-LAS-M-1456, Sheet 1LR-LAS-M-1459, Sheet 1LR-LAS-M-1460, Sheet 1Table 2.3.3-7Demineralized Water Makeup SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureHeat Exchanger
-(Electric Hot Water) Leakage BoundaryShell Side Components Heat Exchanger-(Steam Generator)
Shell Leakage BoundarySide Components Piping, piping components, and piping Leakage BoundaryelementsPump Casing (Evaporative Cooler) Leakage BoundaryValve Body Leakage BoundaryThe aging management review results for these components are provided in:Table 3.3.2-7Demineralized Water Makeup SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-63 Section 2 -Scoping and Screening Methodology and Results2.3.3.8 Diesel Generator and Auxiliaries SystemDescription The Diesel Generator and Auxiliaries System is a standby system designed to providesufficient electrical power to important plant equipment when normal offsite power sources arenot available.
The Diesel Generator and Auxiliaries System consists of the following plantsystems:
diesel generator system, diesel oil transfer system, fire seals and fuel storage, andthe technical support center diesel. The Diesel Generator and Auxiliaries System alsoincludes the security diesel. The Diesel Generator and Auxiliaries System is in scope forlicense renewal.
- However, portions of the Diesel Generator and Auxiliaries System are notrequired 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 shutdownof both units, coincident with a loss-of-coolant accident on one unit. The Diesel Generator andAuxiliaries System is designed for physical separation and redundancy such that no singleactive failure can prevent the system from performing its safety-related
- function, and to remainfunctional during and following a SSE seismic event. The Diesel Generator and Auxiliaries System utilizes five diesel engines to power electric generators.
The system includes twodiesel generators for each LaSalle unit, and a diesel generator that can be aligned to bussesthat supply power to loads on both units. One of the diesel generators for each unit has theprimary purpose to supply emergency power to the high pressure core spray (HPCS) pumpmotor.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 roomto assure reliable operation of the diesel generator and associated equipment.
The ventilation system is evaluated for license renewal under the Safety-Related Ventilation System. Thedesign of the rooms prevents the possibility of a missile or explosion, or a fire affecting onediesel generator, from affecting another diesel generator.
Each diesel generator includes self-contained auxiliary support systems that include starting air, closed cooling water, enginelubricating 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 supplypressurized air to pneumatic starting motors that roll the engine until it starts. The safetyfunction of the starting air auxiliary system is to provide for reliable starting of the dieselgenerators.
The combustion air intake system provides combustion air that is adequately filtered and at the proper temperature and pressure.
The exhaust system discharges exhaustgases outside of the diesel room to support continuous engine operation at full load. Theauxiliary 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.
Heatis rejected from the closed cooling water system by the diesel generator cooling water pumpsthat 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 enginecomponents at a controlled pressure and temperature to support all engine functions.
Thelube 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 systemsupplies pressurized oil to various moving parts within the engine, including the turbocharger.
LaSalle County Station, Units 1 and 2 2.3-64License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsThe scavenging oil system provides cooled and filtered oil to the main lube oil and pistoncooling systems.
The piston cooling system supplies pressurized oil to the piston pin bearingsand cylinders.
The oil circulating and soak-back system supplies warm oil during standbyconditions 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, highquality fuel to support seven days of continuous operation following all design basesaccidents.
The fuel oil system also includes the fuel storage, transfer and delivery system forthe two diesel-driven fire pumps that is interconnected to the HPCS diesel storage tanks. Thefuel 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 securitydiesel generator and Technical Support Center diesel generator.
These fuel oil systems areindependent 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.BoundaryThe 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: startingair, combustion air intake and exhaust, cooling water, engine lubricating oil, and diesel fuel oilstorage and transfer.
There are two redundant starting air systems for each diesel engine. Each redundant startingair system scoping boundary begins at the air compressor and continues through the moistureseparator, air dryer and check valve to two air receiver tanks. The air compressors, moistureseparators and air dryers are nonsafety-related.
The check valve and flow path through the airreceivers to the engine are safety-related.
The scoping boundary continues from the airreceivers through a pressure regulator valve, strainer, air start solenoid valve, to twopneumatic starting motors. The pneumatic starting motors are part of the complex activediesel engine assembly, and are therefore not subject to aging management review. Allassociated piping, components, and instrumentation contained within the described flow pathare included in the system evaluation boundary.
The combustion air intake system scoping boundary begins at the air intake filter locateddownstream of the inlet louver bank associated with the diesel room ventilation system. Thescoping boundary continues to a flexible hose to the diesel engine. The diesel exhaust systemscoping 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 heatexchanger and continues through the lube oil cooler through the engine-driven cooling waterpumps to the engine water inlet manifolds and turbocharger aftercoolers.
The scopingboundary continues from the engine to a temperature regulating valve back to the enginecooling water heat exchanger.
An expansion tank, immersion heater, and all associated piping, components, and instrumentation contained within the described flow path are includedLaSalle County Station, Units 1 and 2 2.3-65License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsin the system evaluation boundary.
The engine-driven cooling water pumps, engine waterinlet manifolds, and aftercoolers are part of the complex active diesel engine assembly, andare 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 oillubrication system scoping boundary begins at the lube oil strainer tank and continues througha strainer, to the engine-driven main oil pump to the main lube oil manifold and through theturbocharger filter assembly to the turbocharger, and to the engine sump. The scavenging oilsystem scoping boundary begins at the engine sump and continues through a strainer to theengine-driven scavenging oil pump, through a filter, the lube oil cooler and to the lube oilstrainer tank. The piston cooling system scoping boundary begins at the suction piping to themain 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 andcontinues 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 thecirculating oil pump to the discharge of the scavenging oil pump filter, and to a commonheader 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 activediesel engine assembly, and are therefore not subject to aging management review. Allassociated piping, components, and instrumentation contained within the described flow pathare included in the system evaluation boundary.
The diesel fuel oil storage and transfer system scoping boundary begins at the fill line to thediesel fuel storage tank for each engine and continues through a strainer to the fuel oil storagetank. The scoping boundary continues from the fuel oil storage tank through a strainer to afuel transfer pump to the diesel generator day tank. The scoping boundary continues from daytank 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 aretherefore not subject to aging management review. All associated piping, components, andinstrumentation 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 firepumps begins at the HPCS diesel fuel storage tank and continues through a strainer to a fueltransfer pump to the diesel fire pump day tank. The scoping boundary continues from daytank 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 andTechnical Support Center diesel begins at the common fuel storage tank fill connection andcontinues to the fuel storage tank, security diesel day tank, Technical Support Center dieselday tank, and to the security diesel engine and the Technical Support Center diesel engine.All associated piping, components, and instrumentation contained within the described flowpath are included in the system evaluation boundary.
Also included in the Diesel Generator and Auxiliaries System license renewal scopingboundary are those portions of nonsafety-related piping and equipment that extend beyond thesafety-related to nonsafety-related interface up to the location of the first seismic anchor. ThisLaSalle County Station, Units 1 and 2 2.3-66License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsincludes the nonsafety-related portions of the system located in the diesel rooms. Alsoincluded in this boundary are pressure-retaining components relied upon to preserve theleakage boundary intended function of this portion of the system. For more information, referto 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 dieselroom ventilation system which is evaluated with the Safety-Related Ventilation System.Not included in the Diesel Generator and Auxiliaries System scoping boundary are the dieselgenerator 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 whichare evaluated with the Fire Protection System.Not included in the scope of license renewal are the components associated with the securityand Technical Support Center diesels and fuel oil systems since they do not perform orsupport an (a)(1) or (a)(3) intended
- function, and are not connected to or located in areaswhere 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 basisevents. The Diesel Generator and Auxiliaries System meets 10 CFR 54.4(a)(2) becausefailure 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 Systemalso meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plantevaluations 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 notrelied 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 (10CFR 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 powersources are not available.
- 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-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 withsafety-related SSCs. The starting air system includes nonsafety-related piping that is in scopeto provide a seismic anchor credited for structural support of safety-related piping. 10 CFR54.4(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). TheLaSalle County Station, Units 1 and 2 2.3-67License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsDiesel Generator and Auxiliaries System provides an alternate power source required to copewith a station blackout event to support safe shutdown and decay heat removal for the blackedout unit for the required coping duration.
- 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 DieselGenerator and Auxiliaries System provides power to safe shutdown equipment in the event ofa loss of offsite power coincident with the postulated fire for several analyzed Fire SafeShutdown methods.
The Diesel Generator and Auxiliaries System also provides the fuel oilsupply to the diesel-driven fire water pumps that support the distribution of water used for firesuppression.
- 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 locatedwithin areas of the plant that may have harsh environments, and therefore have environmental qualifications.
UFSAR References Table 3.2-17.3.68.3.19.5.4 through 9.5.8License Renewal Boundary DrawingsLR-LAS-M-83, Sheets 1, 2, 3, 4LR-LAS-M-85, Sheet 1LR-LAS-M-132, Sheet 1LR-LAS-M-1 05, Sheet 3LR-LAS-M-1 50, Sheet 2LR-LAS-M-EDGECW, Sheet 1LaSalle County Station, Units 1 and 2 2.3-68License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.3-8Diesel Generator and Auxiliaries SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionAir Dryer (Housing)
Structural Integrity Bird Screen FilterBolting Mechanical ClosureElectric Heaters (Housing)
Pressure BoundaryExpansion Joints Pressure BoundaryFlame Arrestor Pressure BoundaryFlow Device Pressure BoundaryThrottleHeat Exchanger
-(DIG Cooler) Shell Side Pressure BoundaryComponents Heat Exchanger
-(D/G Cooler) Tube Pressure BoundarySheetHeat Exchanger
-(D/G Cooler) Tubes Heat TransferPressure BoundaryHeat Exchanger
-(Lube Oil Cooler) Shell Pressure BoundarySide Components Heat Exchanger
-(Lube Oil Cooler) Tube Pressure BoundarySheetHeat Exchanger
-(Lube Oil Cooler) Tube Pressure BoundarySide Components Heat Exchanger
-(Lube Oil Cooler) Heat TransferTubes Pressure BoundaryHoses Pressure BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryStructural Integrity Pump Casing (Fuel Oil Transfer)
Pressure BoundaryPump Casing (Lube Oil) Pressure BoundarySilencer/Muffler Pressure BoundaryStrainer Element FilterTanks (Air Receivers)
Pressure BoundaryTanks (Closed Cooling Water Expansion Pressure BoundaryTanks)Tanks (Fuel Oil Storage and Day Tanks) Pressure BoundaryTanks (Lube Oil Strainer Tank) Pressure BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-8Diesel Generator and Auxiliaries SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-69 Section 2 -Scoping and Screening Methodology and Results2.3.3.9 Drywell Pneumatic SystemDescription The Drywell Pneumatic System (DPS) is a normally operating system designed to provide asafety-related supply of gas to pneumatic devices that are essential for safe plant shutdownfollowing 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 forpurging of the traversing incore probe (TIP) indexing mechanisms located inside the primarycontainment 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 licenserenewal.The purpose of the DPS is to provide a supply of gas for operation of pneumatic devices andfor purging of the TIP indexing mechanisms located inside the primary containment.
The DPSaccomplishes this by drawing gas from inside the primary containment and processing itthrough filters, compressors,
- coolers, separators, dryers, and receivers prior to distributing thegas 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 normalnonsafety-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 andan emergency pressurization station which provide a long term pneumatic supply to the ADSvalves 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.BoundaryThe DPS license renewal scoping boundary begins at the gas intake inside primarycontainment 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 steamsafety/relief valve accumulators, ADS valve accumulators, sample valves and pump seal watervalves 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 backupcompressed gas supply. This boundary begins at the bottle banks and gas manifolds andcontinues through primary containment isolation valves to the ADS accumulators.
One bottlebank supplies four of the seven ADS accumulators while the other serves the remaining threeADS accumulators.
Each bottle bank includes a reserve bottle which is placed in serviceLaSalle County Station, Units 1 and 2 2.3-70License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsduring bottle replacement and an emergency pressurization station so that each ADS gas linecan be recharged indefinitely via nitrogen bottles brought to that point.All associated piping, components and instrumentation contained within the boundarydescribed above are also included in the DPS scoping boundary.
Also included in the DPS scoping boundary are those portions of nonsafety-related piping andequipment that extend beyond the safety-related/nonsafety-related interface up to the locationof the first seismic anchor, or to a point where there is no longer the potential for spatialinteraction with safety-related equipment, whichever extends furthest.
This includes thenonsafety-related portions of the system located within the Reactor Buildings.
Included in thisboundary are pressure-retaining components relied upon to preserve the leakage boundaryintended function of this portion of the system. Also included in the DPS scoping boundary arethose gas filled portions of nonsafety-related piping and equipment that extend beyond thesafety-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 supportintended function of this portion of the system. For more information, refer to the LicenseRenewal Boundary Drawing for identification of this boundary, shown in red.Not included in the DPS scoping boundary are the TIP indexing mechanisms which areevaluated with the Traversing Incore Probe System.Not included in the scope of license renewal are non-liquid filled portions of the DPS. Thisincludes portions of the system that have been abandoned in place and verified to not presenta 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 systemthat is relied upon to remain functional during and following design basis events. The DrywellPneumatic System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions ofthe system could prevent satisfactory accomplishment of function(s) identified for 10 CFR54.4(a)(1).
The Drywell Pneumatic System also meets 10 CFR 54.4(a)(3) because it is reliedupon 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). TheDrywell Pneumatic System is not relied upon in any safety analyses or plant evaluations toperform a function that demonstrates compliance with the Commission's regulations forAnticipated 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 foroperation of the main steam isolation valves, main steam safety/relief valves, and Automatic Depressurization System (ADS) valves following a design basis accident.
- 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The DPS contains nonsafety-related water filled lines in the ReactorLaSalle County Station, Units 1 and 2 2.3-71License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsBuilding which have potential spatial interactions with safety-related SSCs. The DPS alsocontains nonsafety-related gas filled lines relied upon to preserve the structural supportintended 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). Thefunction of providing gas for ADS valve operation is credited for Fire Safe Shutdown.
- 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.
- 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). Thefunction of providing gas for ADS valve operation is credited for Station Blackout coping. 10CFR 54.4(a)(3)
UFSAR References Table 3.2-15.2.2.4.2.1.2 Table 6.2-21Figure 6.2-31Table 6.2-28Table 7.5-17.7.6.49.3.1License Renewal Boundary DrawinasLR-LAS-M-66, Sheets 1, 2, 3, 4, 5, 7, 8, 9, 10, 11Table 2.3.3-9Drywell Pneumatic SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionAccumulator Pressure BoundaryBolting Mechanical ClosureCompressor Housing Leakage BoundaryHoses Leakage BoundaryPressure BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryStructural Integrity Strainer Element FilterValve Body Leakage BoundaryPressure BoundaryStructural Integrity LaSalle County Station, Units 1 and 2License Renewal Application 2.3-72 Section 2 -Scoping and Screening Methodology and ResultsThe aging management review results for these components are provided in:Table 3.3.2-9 Drywell Pneumatic SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 2.3-73License Renewal Application Section 2 -Scoping and Screening Methodology and Results2.3.3.10 Electrical Penetration Pressurization SystemDescription The Electrical Penetration Pressurization (EPP) System is a standby system designed toprovide 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 theEPP System are not required to perform intended functions and are not included in the scopeof license renewal.The electrical penetration assemblies provide continuity of electric circuits through thecontainment building wall, while maintaining containment integrity.
The assemblies arepressurized internally with nitrogen, to minimize moisture intrusion and condensation.
Thisensures that the connected electrical equipment performs as required, and ensurescontainment leak-tightness.
The EPP system consists of piping, valves and pressureinstrumentation which connect to these penetrations to monitor the penetration internalpressure; and a permanently connected external pressurization source of nitrogen to allow formanual 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 tomaintain the qualification of the penetration.
The EPP system is applicable to Unit 2 only. The Unit 1 electrical penetration design allowsfor 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.BoundaryThe EPP System license renewal scoping boundary starts at the branch connection off the lowflow nitrogen makeup to the primary containment, and continues to the Unit 2 electrical penetrations.
The EPP System includes piping, valves and components which can supplysupplemental nitrogen for penetration pressurization if required, and flexible connections between the safety-related and the nonsafety-related components.
The EPP System alsocontains pressure instruments at each electrical penetration to monitor penetration
- pressure, and a test connection for leak rate testing.
The components within the scope of licenserenewal consist of the safety-related components in the system, specifically the pressureinstrument and test connection at each penetration, and the nitrogen supply piping and valvesbetween the electrical penetrations and the flexible connections.
Not included in the EPP System scoping boundary are the electrical penetrations which arepart of the primary containment, and are evaluated with the Primary Containment structure forlicense 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 anintended
- function, and are therefore not included in the scope of license renewal.LaSalle County Station, Units 1 and 2 2.3-74License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsReason for Scope Determination The Electrical Penetration Pressurization System meets 10 CFR 54.4(a)(1) because it is asafety-related system that is relied upon to remain functional during and following design basisevents. The Electrical Penetration Pressurization System is not in scope under 10 CFR54.4(a)(2) because failure of nonsafety-related portions of the system would not preventsatisfactory 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 notrelied 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 CFR50.62), and Station Blackout (10 CFR 50.63).Intended Functions
- 1. Provide primary containment boundary.
The EPP System components connect directly tothe Unit 2 electrical penetration assemblies and have the potential for structural interaction with them. 10 CFR 54.4(a)(1)
UFSAR References 6.2.6.23.8.1.1Table 3.2-1Figure 3.8-21License Renewal Boundary DrawingsLR-LAS-M-148, Sheet 1Table 2.3.3-10 Electrical Penetration Pressurization SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionPiping, piping components, and piping Pressure BoundaryelementsValve Body Pressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-10 Electrical Penetration Pressurization SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 2.3-75License Renewal Application Section 2 -Scoping and Screening Methodology and Results2.3.3.11 Essential Cooling Water SystemDescription The Essential Cooling Water (ECW) System is a standby system designed to circulate lakewater from the ultimate heat sink to the Residual Heat Removal (RHR) System heatexchangers, diesel generator
- coolers, core standby cooling system area coolers, LowPressure 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 sealcoolers, and LPCS pump motor coolers.
The ECW System accomplishes this function bycirculating 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 alsoprovides containment flooding water for post-accident recovery.
The ECW Systemaccomplishes these functions by providing water from the ultimate heat sink to the spent fuelpool emergency makeup pumps and requires installation of a pipe spool piece which isnormally installed on the emergency makeup pump test line. Flooding of the containment isaccomplished by providing water from the ultimate heat sink to the containment through pipespool 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 ofemergency core cooling systems and the emergency diesel generators.
The RHR servicewater portion of the system is required to operate during all unit shutdowns to remove coreresidual 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 operatedor when the LPCS System pumps are operated.
The core standby cooling system cubiclearea coolers require cooling water only when the core standby cooling system pumps areoperating and the normal Reactor Building ventilation systems are not functioning.
The ECW System pumps take suction from the service water tunnel located in the basementof the Lake Screen House. Traveling screens on the inlet to the service water tunnel preventlarge pieces of debris from entering the system and blocking flow or damaging equipment.
Anormally closed bypass around the travelling screens is installed to assure access to acontinuous supply of water from the ultimate heat sink in the event that all travelling screensbecome blocked.
A shad net is installed across the Lake Screen House intake flume to deterand 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 linesfrom 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.BoundaryThe ECW System license renewal scoping boundary begins with the ultimate heat sink portionof the Cooling Lake and continues through the service water tunnel located in the Lake ScreenLaSalle County Station, Units 1 and 2 2.3-76License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsHouse, including the 54-inch travelling screen bypass line. The ECW system piping extendsfrom the service water tunnel, through the ECW pumps and pump discharge strainers, to thecomponents requiring cooling and return piping to the Cooling Lake for each reactor unit. Theboundary includes the tube sides of the RHR heat exchangers, shell side of the RHR pumpseal coolers, tube side of the diesel generator cooling water coolers, the tube side of the corestandby cooling system equipment cubicle area coolers, and the connections to the LPCSpump motor housing.
The LPCS pump motor is an active assembly and is not subject to agingmanagement review.The ECW System includes the fuel pool emergency makeup pumps that interface with thecontainment flooding piping interface with the RHR System and provide capability for make-upto 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 cablingAll associated piping, components and instrumentation contained within the boundarydescribed above are also included in the ECW System scoping boundary.
Also included in the ECW scoping boundary are those portions of nonsafety-related piping andequipment that extend beyond the safety-related/nonsafety-related interface up to the locationof the first seismic anchor, or to a point where there is no longer the potential for spatialinteraction with safety-related equipment, whichever extends furthest.
This includes thenonsafety-related portions of the system located within the Diesel Generator Building.
Included in this boundary are pressure-retaining components relied upon to preserve theleakage boundary intended function of this portion of the system. For more information, referto 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 anchorsfor 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 withthe 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. TheEssential 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 for10 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 thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48), 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 plantevaluations to perform a function that demonstrates compliance with the Commission's LaSalle County Station, Units 1 and 2 2.3-77License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsregulations for Anticipated Transient Without Scram (10 CFR 50.62).Intended Functions
- 1. Remove residual heat from the reactor coolant system. The Essential Cooling WaterSystem provides cooling to equipment that removes decay heat from the reactor during normaloperation and accident conditions.
- 2. Provide heat removal from safety-related heat exchangers.
The Essential Cooling WaterSystem removes heat from the RHR heat exchangers and ECCS pump seal and motorcoolers during normal operation and accident conditions.
- 3. Provide emergency heat removal from primary containment and provide containment pressure control.
The Essential Cooling Water System removes heat from the RHR heatexchangers during transient and accident conditions.
The Essential Cooling Water Systemprovides containment flooding water for post-accident recovery.
- 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.
- 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.
- 6. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The Essential Cooling Water System contains nonsafety-related fluidfilled lines in the Auxiliary Building which provide structural support or have potential spatialinteractions 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). TheEssential Cooling Water System provides cooling to equipment that is credited withmaintaining reactor level and cooling the reactor and containment for Fire Safe Shutdown.
- 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.
- 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). TheEssential Cooling Water System provides cooling for equipment that is credited withmaintaining reactor water injection and for containment heat removal for Station Blackoutcoping. 10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 2.3-78License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsUFSAR 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 7.3.39.1.3.2.3.6 9.2.19.2.6License Renewal Boundary DrawinasLR-LAS-M-87, Sheets 1, 2, 3LR-LAS-M-134, Sheets 1, 2, 3LR-LAS-M-91, Sheet 3LR-LAS-M-96, Sheet 4LR-LAS-M-98, Sheet 1LR-LAS-M-137, Sheet 3LR-LAS-M-142, Sheet 4LR-LAS-M-144, Sheet 1LR-LAS-M-1 53, Sheets 4, 6LR-LAS-M-EDGECW, Sheet 1Table 2.3.3-11Essential Cooling Water SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureFish Barrier FilterFlow Device Pressure BoundaryThrottleHeat Exchanger
-(CSCS Equipment Area Heat TransferCubicle Coolers)
Tubes Pressure BoundaryHeat Exchanger
-(D/G Cooler) Tube Pressure BoundarySheetHeat Exchanger
-(D/G Cooler) Tube Side Pressure BoundaryComponents Heat Exchanger
-(D/G Cooler) Tubes Heat TransferPressure BoundaryHeat Exchanger
-(LPCS Pump Motor Pressure BoundaryCooler) Shell Side Components Heat Exchanger
-(LPCS Pump Motor Pressure BoundaryCooler) Tube Side Components Heat Exchanger
-(LPCS Pump Motor Heat TransferCooler) Tubes Pressure BoundaryHeat Exchanger
-(RHR Heat Exchanger)
Pressure BoundaryLaSalle County Station, Units 1 and 2License Renewal Application 2.3-79 Section 2 -Scoping and Screening Methodology and ResultsComponent Type Intended FunctionTube SheetHeat Exchanger
-(RHR Heat Exchanger)
Pressure BoundaryTube Side Components Heat Exchanger
-(RHR Heat Exchanger)
Heat TransferTubes Pressure BoundaryHeat Exchanger
-(RHR Pump Seal Pressure BoundaryCooler) Shell Side Components Heat Exchanger
-(RHR Pump Seal Pressure BoundaryCooler) Tube Side Components Heat Exchanger
-(RHR Pump Seal Heat TransferCooler) Tubes Pressure BoundaryHoses Pressure BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (DIG Cooling Water Pressure BoundaryODG01 P)Pump Casing (DIG Cooling Water Pressure Boundary1 DG01 P/2DG01 P)Pump Casing (Fuel Pool Emergency Pressure BoundaryMakeup)Pump Casing (HPCS DIG Cooling Water) Pressure BoundaryPump Casing (RHR Service Water) Pressure BoundaryStrainer Body Pressure BoundaryStrainer Element FilterValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-11Essential Cooling Water SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-80 Section 2 -Scoping and Screening Methodology and Results2.3.3.12 Fire Protection SystemDescription The Fire Protection System is a standby system common to both Units 1 and 2 that isdesigned 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 designfeatures which support safe shutdown of the plant. The Fire Protection System is in scope forlicense renewal.
- However, portions of the system are not required to perform intendedfunctions and are not in scope.The purpose of the Fire Protection System is to prevent fires from starting, quickly detect anyfires, 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 toprevent 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 normallykept pressurized by two fire protection jockey pumps. If a system demand occurs, the motordriven intermediate fire pump is automatically activated.
If the system demand exceeds thecapacity 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 firepump 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 abackup to provide the system demand. The fire pumps take suction from the service watertunnel in the Lake Screen House and supply water to the yard ring header. The fire hydrantsystem is supplied by separate header connections to each of the two diesel driven firepumps. The yard loop is sectionalized, permitting independence of each unit if desired.
Fireprotection water is distributed to the hydrants, hose stations, and water suppression systemsin 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 thestandpipes, hose stations and sprinkler, spray and deluge water systems.
Wet standpipes forhose stations are located throughout the plant to allow use of fire hoses to support local firebrigade activity.
Wet pipe sprinkler operation is initiated automatically when ambienttemperature exceeds the melting point of the fusible links of the sealed sprinklers, causing thespray 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 localambient temperatures rise due to a fire. System actuation transmits alarm signals to thecontrol 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 trippingdevice which opens the deluge valve, thus supplying water under pressure to the open spraynozzles.
Deluge valves can also be tripped open manually.
System actuation transmits alarmsignals to the control room.LaSalle County Station, Units 1 and 2 2.3-81License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsDeluge 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 manuallyopened when a temperature detector actuates a local alarm system and registers an alarmcondition in the control room.An automatic carbon dioxide flooding extended discharge system is provided for each of thefive diesel generator rooms. Each system is activated by a fixed temperature rise detectorsystem and may also be manually activated.
The carbon dioxide systems consist of acommon refrigerated storage unit and associated piping, headers, and valves to the five dieselgenerator rooms. Hose reels are also provided for manually fighting fires. Audible and visualpredischarge alarms warn that the carbon dioxide flooding system is about to actuate so thatpersonnel 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 carbondioxide 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 servicebuilding, QA archives in the north service building, and the records storage building.
Audibleand visual predischarge alarms warn that the halon system is about to actuate so thatpersonnel may leave the area. Actuation of the halon system automatically shuts down thelocal fans and closes the local dampers in the ventilation system.The Fire Protection System includes features to isolate safety-related systems fromunacceptable 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. Inaddition, curbs and walls are provided to minimize the spread of flammable fluids in the eventof a spill.Fire detection instrumentation, consisting of ionization and heat detectors, is included in thescope of the Fire Protection System.For more detailed information, see UFSAR Section 9.5.1 and Appendix H, Fire Protection Report.BoundaryThe Fire Protection System license renewal boundary begins in the Lake Screen House wherethe fire pumps take suction from the service water tunnel and supply water to the fire main ringheader and yard fire hydrants, and extends into the building fire distribution piping for hosestation standpipes, water spray subsystems, water sprinkler subsystems, and water delugesubsystems throughout the plant. Included is the interface with the Nonessential CoolingWater System that provides a source of fire water in the event the fire water pumps are notavailable.
The diesel engines for the diesel driven fire pumps are a complex active assemblyand are, therefore, not subject to aging management review.The carbon dioxide fire suppression subsystem begins at the carbon dioxide storage unit andextends 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 thatconsist 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 theLaSalle County Station, Units 1 and 2 2.3-82License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsReactor Buildings, Turbine Buildings, Auxiliary
- Building, Lake Screen House, RadwasteBuilding, and Diesel Generator Buildings.
The fire damper housings are subject to agingmanagement review. The fire barrier function of all fire damper housings is evaluated with theFire Protection System for license renewal aging management review. The pressureboundary 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 agingmanagement review. The Fire Protection System includes fire rated doors in the ReactorBuildings, Turbine Buildings, Auxiliary
- Building, and Diesel Generator Buildings.
Airsupervised preaction sprinkler systems are provided with individual air compressors tomaintain air pressure.
These compressors are active components and are not subject toaging management review.The racks, reels, and supports that makeup the fire hose stations are included within thescoping boundary of the Fire Protection System. Hoses are considered consumables, and aretherefore, 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 ofnonsafety-related piping and equipment located in areas where there are potential spatialinteractions with safety-related equipment.
This includes the nonsafety-related portions of thesystem located within the Reactor Buildings, Turbine Buildings, Auxiliary
- Building, LakeScreen House, Offgas Building, and Diesel Generator Buildings.
Included in this boundary arepressure-retaining components relied upon to preserve the leakage boundary intendedfunction of this portion of the system. For more information, refer to the License RenewalBoundary Drawings for identification of this boundary, shown in red.Not included in the Fire Protection System scoping boundary are the drains from fire watersystem components and areas protected by the fire water system which are evaluated with thePlant Drainage System.Not included in the Fire Protection System scoping boundary are the fire detection andsignaling systems and associated circuitry which are evaluated with Electrical Commodities.
Not included in the Fire Protection System scoping boundary are the Lake Screen Housetraveling water screens.
This equipment is evaluated with the Nonessential Cooling WaterSystem.Not included in the Fire Protection System scoping boundary is the fuel oil supply piping anddiesel fuel fire pump day tank for the fire pump diesel engines which are evaluated with theDiesel Generator and Auxiliaries System.Not included in the scope of license renewal is the carbon dioxide supply piping to the maingenerator alterex housings and purge gas for the main generators.
This equipment isprovided for asset protection and does not perform or support an intended function inaccordance with 10 CFR 54.4(a)(3).
Not included in the scope of license renewal is the halon fire suppression system that servicesthe computer room in the south service building and records storage areas in the north servicebuilding and records storage building.
These areas do not contain any safety-related LaSalle County Station, Units 1 and 2 2.3-83License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsequipment, and the halon systems do not perform or support an intended function inaccordance with 10 CFR 54.4(a)(3).
Not included in the scope of license renewal are fire rated dampers and fire rated doors thatdo 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 ofthe system are safety-related and relied upon to remain functional during and following designbasis events. The Fire Protection System meets 10 CFR 54.4(a)(2) because failure ofnonsafety-related portions of the system could prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
The Fire Protection System also meets 10 CFR54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform afunction 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 plantevaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49), Anticipated Transient WithoutScram (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 asafety-related function.
The Fire Protection System includes nonsafety-related SSCs with thepotential for spatial and structural interaction with safety-related equipment in the ReactorBuildings, Auxiliary
- Building, Turbine Buildings, Diesel Generator Buildings, and OffgasBuilding.
- 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 FireProtection System provides the capability to control postulated fires in plant areas to maintainsafe shutdown ability.
UFSAR References 9.5.15.9Appendix H3.2-1License Renewal Boundary Drawinqgs LR-LAS-M-68, Sheet 1LR-LAS-M-71, Sheets 1, 2, 3LR-LAS-M-72, Sheets 1, 2, 5LR-LAS-M-78, Sheet 1LR-LAS-M-89, Sheet 1LR-LAS-M-1 26, Sheets 1, 2, 3LR-LAS-M-1 29, Sheets 3, 4, 7LR-LAS-M-1442, Sheet 2LaSalle County Station, Units 1 and 2 2.3-84License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsLR-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 2Sheet 1Sheets 2, 3Sheet 2Sheet 2Sheets 2, 3Sheet 2Sheets 1, 2, 3, 4Sheet 1Sheet 1Sheets 1, 3Table 2.3.3-12 Fire Protection SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureFire Barriers (Damper Housing)
Fire BarrierFire Barriers (Doors) Fire BarrierFire Barriers (For Steel Components)
Fire BarrierFire Barriers (Penetration Seals and Fire Fire BarrierStops)Fire Barriers (Walls and Slabs) Fire BarrierFire Hydrant Pressure BoundaryHose Stations (Racks, Reels, and Structural SupportSupports)
Hoses (Diesel Fire Pump) Pressure BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (Diesel Fire Pump) Pressure BoundaryPump Casing (Fire Intermediate Pump) Pressure BoundaryPump Casing (Fire Jockey Pump) Pressure BoundarySpray Nozzles SpraySprinkler Heads Pressure BoundarySprayStrainer Element FilterTanks (Cardox Storage)
Pressure BoundaryTanks (Retard Chamber)
Pressure BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-12Fire Protection SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-85 Section 2 -Scoping and Screening Methodology and Results2.3.3.13 Fuel Pool Cooling and Storage SystemDescription The Fuel Pool Cooling and Storage System is a normally operating system designed toprovide an environment to safely and temporarily store new and used nuclear fuel andconsumable 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, andnew fuel storage racks. The Fuel Pool Cooling and Storage System also includes skimmersurge tanks, heat exchangers, pumps, water purifying loops, discharge diffusers within the fuelpools, and associated valves, piping components and instrumentation.
The Fuel Pool Coolingand Storage System is in scope for license renewal.
- However, portions of the system are notrequired 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 thespent fuel pools and new fuel storage vault in a safe subcritical configuration.
The systemaccomplishes this by removing decay heat from spent fuel assemblies stored in the spent fuelpools, maintaining fuel pool water temperature and level within required limits, purifying waterin the spent fuel pools, and minimizing contamination and radiation exposure from fission andcorrosion product buildup in the spent fuel pool water. The Fuel Pool Cooling and StorageSystem also supports filling and draining of the reactor wells and dryer/separator pits insupport of refueling operations.
The fuel storage pools, are located in the refueling area within the Reactor Building.
EachLaSalle unit has a spent fuel pool and dryer/separator pit. The cask well and new fuel storagevault are common to both units. The spent fuel pools communicate with the reactor wellsthrough fuel transfer canals. Removable gates are inserted in the canal openings to provide awatertight boundary except during refueling when the reactor well is also flooded forunderwater 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 ofthe Reactor Building.
They are lined with stainless steel plate to minimize leakage.
The spentfuel pools contain high-density storage racks equipped with thermal neutron poison materialfor storage of new and spent fuel. The spent fuel pools also contain storage racks designed tostore control rod blades, fuel channels, defective fuel storage containers and other corecomponents 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 toprovide radiation shielding for normal building occupancy by operating personnel.
The spentfuel storage racks, defective fuel storage racks, and control rod blade storage racks within thespent fuel storage pools and new fuel storage racks are safety-related and designed toSeismic 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 isprovided by the Condensate System. A Seismic Category 1 emergency make-up source isprovided 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 tocirculate, cool, and process water from the reactor well and dryer/separator pit.Interconnections are provided to the Suppression Pool Cleanup System to facilitate filling andLaSalle County Station, Units 1 and 2 2.3-86License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsdraining 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 surgetanks to the RHR System and the return piping from the RHR System to the spent fuel pools issafety-related.
Piping and equipment in the flowpath through the fuel pool cooling pumps, filterdemineralizers, heat exchangers and back to the fuel pool is nonsafety-related.
Piping thatroutes and detects leakage of the fuel pool gates and reactor well drain piping to the primarycontainment penetrations, is also safety-related up to normally closed valves. All otherportions 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.BoundaryThe Fuel Pool Cooling and Storage System license renewal scoping boundary begins at theweirs at the surface of the spent fuel pools, reactor wells, and dryer/separator pits, andcontinues within the Reactor Building through piping to the skimmer surge tanks to the fuelpool cooling water pumps and connection to the RHR System. From the pump discharge thepiping leaves the Reactor Building, passes through the Auxiliary
- Building, enters the TurbineBuilding, and continues to the filter demineralizers.
From the filter demineralizers, the pipingreturns through the Auxiliary Building to the Reactor Building and continues through the fuelpool heat exchangers to the spent fuel pools, reactor wells and dryer/separator pits. Includedare the fuel pool cooling supply connections to the RHR System, the RHR System returnpiping to the spent fuel pools, supply and return connections to the Suppression Pool CleanupSystem, and the connections to the Condensate System.Also included is the piping installed to drain the cask washdown area and new fuel storagevault, 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 caskwell.The Fuel Pool Cooling and Storage System scoping boundary also includes the spent fuelstorage racks, defective fuel storage racks and control rod blade storage racks within thespent fuel storage pools, and new fuel storage racks.All associated piping, components, and instrumentation contained within the boundarydescribed above are also included in the Fuel Pool Cooling and Storage System scopingboundary.
Also included in the Fuel Pool Cooling and Storage System scoping boundary are thoseportions 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 pointwhere 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 locatedin the Reactor Buildings and Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of thisportion of the system. For more information, refer to the License Renewal Boundary Drawingsfor identification of this boundary, shown in red.Not included in the Fuel Pool Cooling and Storage System scoping boundary is the piping andequipment associated with the emergency make-up water source to the spent fuel pools whichLaSalle County Station, Units 1 and 2 2.3-87License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsis evaluated with the ECW System.Not included in the Fuel Pool Cooling and Storage System scoping boundary are the spentfuel pools, transfer canals, reactor wells, dryer/separator pits and cask well including theirliners, new fuel storage vault, and fuel storage pool gates which are evaluated with theReactor 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 andStorage System located within the Turbine Building, as this portion of the system is not locatedin areas where there are potential spatial interactions with safety-related components.
Components that are not required to support the system's leakage boundary intendedfunctions 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 basisevents. The Fuel Pool Cooling and Storage System meets 10 CFR 54.4(a)(2) because failureof nonsafety-related portions of the system could prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
The Fuel Pool Cooling and Storage System is notin scope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plantevaluations 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 waterinventory.
10 CFR 54.4(a)(1) 2, Prevents criticality of fuel assemblies stored in the spent fuel pool. The spent fuel storageracks maintain new and spent nuclear fuel in a subcritical configuration, with at least 5 percentsubcriticality margin. 10 CFR 54.4(a)(1)
- 3. Provides protection for safe storage of new and spent fuel. The spent fuel storage racksprovide physical
- support, shelter and protection for new and spent nuclear fuel. 10 CFR54.4(a)(1)
- 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The system includes nonsafety-related piping that has the potential tospatially and structurally interact with safety-related components located in the Reactor andAuxiliary Buildings.
LaSalle County Station, Units 1 and 2 2.3-88License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsUFSAR References Table 3.2.17.7.129.1License Renewal Boundary DrawingsLR-LAS-M-98, Sheets 1, 4LR-LAS-M-144, Sheet 1LR-LAS-M-91, Sheet 1LR-LAS-M-96, Sheets 2, 5LR-LAS-M-103, Sheet 19LR-LAS-M-137, Sheet 1LR-LAS-M-142, Sheet 2, 5Table 2.3.3-13 Fuel Pool Cooling and Storage SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureControl 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 NeutronsStructural Integrity Fuel Storage Racks (Unit 2 Spent Fuel) Absorb NeutronsStructural Integrity Heat Exchanger
-(Fuel Pool Cooling)
Leakage BoundaryShell Side Components Hoses Leakage BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (Fuel Pool Cooling Pump) Leakage BoundaryStrainer Element (Inside Skimmer Surge FilterTank)Tanks (Skimmer Surge Tanks) Pressure BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-13Fuel Pool Cooling and Storage SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-89 Section 2 -Scoping and Screening Methodology and Results2.3.3.14 Nonessential Cooling Water SystemDescription The Nonessential Cooling Water System is a normally operating system that is designed toprovide cooling water to the main condensers and other plant heat exchangers.
TheNonessential 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 ofthe Nonessential Cooling Water System are not required to perform intended functions andare not included in the scope of license renewal.Circulating WaterThe 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 fromthe man-made Cooling Lake, pumping the water through the condensers and returning theheated water to the Cooling Lake.Service WaterThe 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 turbinebuilding and reactor building closed cooling water systems.
Water for the traveling screenwash is also provided by this system. The service water system provides water for filling thefire protection system and serves as a back-up supply for fire water. The service water systemalso provides water for use in the radwaste system. The circulating water systemaccomplishes this by taking water from the man-made Cooling Lake, pumping it throughvarious plant equipment and returning water to the Cooling Lake.Piping in the service water system provides water from the Cooling Lake to the service watertunnel 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 theevent that both diesel fire water pumps are unavailable at the same time.Screen WashThe purpose of the screen wash system is to provide water to wash and remove debris fromthe traveling screens in the Lake Screen House. The screen wash system accomplishes thisby providing screened pressurized water to spray onto the traveling screens to dislodge debrisfrom the screen surface for collection and removal.Chemical FeedThe purpose of the chemical feed system is to minimize the macroscopic biological fouling andmicrobiologically influenced corrosion in plant systems.
The chemical feed systemaccomplishes this by injection of chemicals into the water supplied from the Cooling Lake tothe plant, such as biocides, scale inhibitors, corrosion inhibitors, and silt dispersants.
LaSalle County Station, Units 1 and 2 2.3-90License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsGland WaterThe purpose of the gland water system is to provide cooling water to plant equipment.
Thegland water system accomplishes this by providing cooling and sealing water to plant rotatingequipment, including the circulating water pumps.Lake Make-up and BlowdownThe purpose of the lake make-up and blowdown system is to maintain an acceptable waterlevel in the Cooling Lake, control dissolved solids in the Cooling Lake water, and dilute anddischarge 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 lostdue to evaporation,
- seepage, and blowdown.
Dissolved solids in the Cooling Lake water arecontrolled 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 thendischarging the diluted waste to the Illinois River.For more detailed information see UFSAR Sections 9.2.2, 9.2.12, and 10.4.5.BoundaryThe Nonessential Cooling Water System license renewal scoping boundary includes thatportion of the system that provides water to fill the fire water system and to provide a source ofpressurized water to the fire water system if the fire pumps are unavailable.
The scopingboundary begins with the traveling water screens and piping in the Lake Screen House thatprovides water from the Cooling Lake to fill the service water tunnel. The service water pumpsas well as the fire water pumps take their suction from the service water tunnel located in theLake Screen House. The in scope boundary for the service water piping extends from theservice water tunnel to the service water pump and discharge piping and continues throughstrainers to, and including piping and isolation valves in branch lines downstream of the firewater system supply line interface for each unit. The Nonessential Cooling Water Systemscoping 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 agingmanagement review.All associated piping, components, and instrumentation contained within the boundaries described above are also included in the Nonessential Cooling Water System scopingboundary.
Also included in the Nonessential Cooling Water System scoping boundary are those waterfilled portions of nonsafety-related piping and equipment located in areas where there arepotential spatial interactions with safety-related equipment.
This includes the nonsafety-related portions of the system located within the Reactor Buildings, Turbine Buildings, andAuxiliary Building.
Included in this boundary are pressure-retaining components relied upon topreserve the leakage boundary intended function of this portion of the system. For moreinformation, 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 watertunnel which is evaluated with the Lake Screen House.LaSalle County Station, Units 1 and 2 2.3-91License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsNot 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 notlocated in areas that contain safety-related systems or components, and therefore are notincluded 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 noportions of the system are safety-related and relied upon to remain functional during andfollowing design basis events. The Nonessential Cooling Water System meets 10 CFR54.4(a)(2) because failure of nonsafety-related portions of the system could preventsatisfactory 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 safetyanalyses and plant evaluations to perform a function that demonstrates compliance with theCommission's regulations for Fire Protection (10 CFR 50.48). The Nonessential CoolingWater System is not relied upon in any safety analyses or plant evaluations to perform afunction that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR 50.62), andStation Blackout (10 CFR 50.63).Intended Functions
- 1. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The Nonessential Cooling Water System contains nonsafety-related fluid filled lines in the Reactor Buildings, Turbine Buildings, and Auxiliary Building which havepotential 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). TheNonessential Cooling Water System provides a source of fire water and provides a creditedbackup 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 2.4.8.42.5.6.4.5 3.29.2.9.2.29.2.1210.4.5FPR Section 30LaSalle County Station, Units 1 and 2 2.3-92License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsLicense Renewal Boundary DrawingsLR-LAS-M-68, Sheet 1LR-LAS-M-69, Sheets 1, 2, 3, 4LR-LAS-M-125, Sheets 1, 2, 3LR-LAS-M-63, Sheet 4LR-LAS-M-70, Sheet 1LR-LAS-M-77, Sheet 1LR-LAS-M-87, Sheet 1LR-LAS-M-89, Sheet 1LR-LAS-M-91, Sheets 1, 3LR-LAS-M-1 15, Sheet 2LR-LAS-M-1 34, Sheet 1LR-LAS-M-1 37, Sheets 1, 3LR-LAS-M-1 53, Sheets 4, 6LR-LAS-M-1 59, Sheet 2LR-LAS-M-1467, Sheet 3LaSalle County Station, Units 1 and 2License Renewal Application 2.3-93 Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.3-14 Nonessential Cooling Water SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureStructural Integrity Heat Exchanger
-(Aux Bldg HVAC Leakage BoundaryCondenser Unit) Tube Side Components Heat Exchanger
-(Aux Bldg HVAC Leakage BoundaryCondenser Unit) TubesHeat Exchanger
-(Counting Room HVAC Leakage BoundaryCondenser Unit) Tube Side Components Heat Exchanger
-(Counting Room HVAC Leakage BoundaryCondenser Unit) TubesHeat Exchanger
-(Fuel Pool Cooling)
Leakage BoundaryTube Side Components Heat Exchanger
-(Primary Containment Leakage BoundaryVentilation Chiller Service WaterCondenser)
Tube Side Components Heat Exchanger
-(Primary Containment Leakage BoundaryVentilation Chiller Service WaterCondenser)
TubesHeat Exchanger
-(Process Computer Leakage BoundaryRoom A/C Unit) Tube Side Components Heat Exchanger
-(Process Computer Leakage BoundaryRoom A/C Unit) TubesHeat Exchanger
-(Reactor Building Leakage BoundaryClosed Cooling Water Heat Exchanger)
Tube Side Components Piping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (Service Water) Pressure BoundaryTanks (Clean Gland Water) Leakage BoundaryTraveling Water Screen Framework Structural Integrity Valve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-14 Nonessential Cooling Water SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-94 Section 2 -Scoping and Screening Methodology and Results2.3.3.15 Nonsafety-Related Ventilation SystemDescription The intended function of the Nonsafety-Related Ventilation (NSV) System for license renewalis to maintain leakage boundary integrity to preclude system interactions.
For this reason, thissystem's pressure-retaining components located in areas where there are potential spatialinteractions with components performing safety-related functions have been included in thescope of license renewal.
This system is not required to operate to support license renewalintended 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 stationheat recovery plant system.The NSV System provides ventilation to the following plant areas: Auxiliary Buildingequipment areas, Auxiliary Building office areas, Auxiliary Building laboratory, Lake ScreenHouse, machine shop, Offgas Building, Radwaste
- Building, Service Building, Service Buildingstoreroom, interim radwaste storage facility, River Screen House, QA records vault, and 345kV 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 wintertime, 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.BoundaryThe NSV System license renewal scoping boundary encompasses the liquid-filled portions ofnonsafety-related piping and equipment located in areas where there are potential spatialinteractions with safety-related equipment.
This includes the nonsafety-related liquid-filled portions of the system located within the Auxiliary Building.
Included in this boundary arepressure-retaining components relied upon to preserve the leakage boundary intendedfunction of this system; specifically the station heat recovery components that are locatedwithin the Auxiliary Building.
For more information, refer to the License Renewal BoundaryDrawing 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 fireprotection function and are evaluated with the Fire Protection System. Additionally, the fireprotection 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 isnonsafety-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 doesnot create a concern for (a)(2) spatial concern.
This includes the ventilation portion of the NSVsystem and the components in the station heat recovery portion of the system that are locatedin nonsafety-related buildings; for example, the Radwaste Building.
LaSalle County Station, Units 1 and 2 2.3-95License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsReason for Scope Determination The Nonsafety-Related Ventilation System is not in scope under 10 CFR 54.4(a)(1) becauseno portions of the system are safety-related or relied upon to remain functional during andfollowing design basis events. The Nonsafety-Related Ventilation System meets 10 CFR54.4(a)(2) because failure of nonsafety-related portions of the system could preventsatisfactory 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 reliedupon 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 CFR50.62), and Station Blackout (10 CFR 50.63).Intended Functions
- 1. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The NSV system includes nonsafety-related water filled piping andcomponents 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 9.4.39.4.69.4.79.4.89.4.119.4.129.4.139.2.10License Renewal Boundary DrawingsLR-LAS-M-1 02, Sheets 1, 2, 3, 5, 6, 7, 8, 9, 10, 11LR-LAS-M-1 29, Sheet 2LR-LAS-M-1 51, Sheet 4LaSalle County Station, Units 1 and 2 2.3-96License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.3-15 Nonsafety-Related Ventilation SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureHeat Exchanger
-(Primary Containment Leakage BoundaryVent Chiller Glycol Condenser)
Tube SideComponents Heat Exchanger
-(Primary Containment Leakage BoundaryVent Chiller Glycol Condenser)
TubesHeat Exchanger
-(Reactor Bldg, Turb Leakage BoundaryBldg, Switchgear Rm Supply and ExhaustCoils) Tube Side Components Heat Exchanger
-(Reactor Bldg, Turb Leakage BoundaryBldg, Switchgear Rm Supply and ExhaustCoils) TubesPiping, piping components, and piping Leakage BoundaryelementsPump Casing (Heat Recovery Transfer Leakage BoundaryPumps, Fill Pump, Make-up Tank Pump,Heat Coil Drain Pump)Tanks (Glycol Electric Heaters)
Leakage BoundaryTanks (Heat Recovery System Expansion Leakage BoundaryTank)Tanks (Heat Recovery System Make-up Leakage BoundaryTank)Valve Body -Leakage BoundaryThe aging management review results for these components are provided in:Table 3.3.2-15Nonsafety-Related Ventilation SystemSummary of Aging Management Evaluation LaSalle County Station, Units I and 2License Renewal Application 2.3-97 Section 2 -Scoping and Screening Methodology and Results2.3.3.16 Plant Drainage SystemDescription The Plant Drainage System is a normally operating system designed to collect various liquidwastes generated in the operation of the plant. The Plant Drainage System consists of severalplant systems including floor and equipment drain systems for the Primary Containment, Reactor Building, Auxiliary
- Building, Diesel Generator
- Building, Radwaste
- Building, OffgasBuilding, Turbine Building, Service Building, and Lake Screen House. The Plant DrainageSystem also includes the HVAC equipment drain system, generator vent and drain system,roof drain system, wastewater treatment system, and sewage treatment system. The PlantDrainage System is in scope for License Renewal.
- However, portions of the Plant DrainageSystem are not required to perform intended functions and are not in scope.Equipment and Floor Drainage SystemsThe 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 systemaccomplishes this by collecting waste liquids from their points of origin and transferring themfor eventual processing.
Radioactive, nonradioactive, and oily wastes are segregated andprocessed 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 chamberairspace prior to exiting the primary containment are in scope to ensure their pressureboundary integrity to prevent drywell to suppression chamber bypass leakage.The nonsafety-related floor drain system in the Reactor Building is credited for the mitigation offlooding 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, andTurbine Building are credited for the removal of fire water from areas containing safe shutdownequipment and are in scope for Fire Safe Shutdown.
Portions of the floor drain system in theDiesel 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 havepotential spatial interaction with safety-related equipment in the Primary Containment, ReactorBuilding, Auxiliary
- Building, Diesel Generator
- Building, and Offgas Building perform a licenserenewal intended function and are in scope for potential spatial interaction.
HVAC Equipment Drain SystemThe purpose of the HVAC equipment drain system is to prevent water accumulation withinHVAC ventilation units. The HVAC equipment drain system accomplishes this by collecting condensate from the ventilation unit plenums and draining it for eventual processing.
TheHVAC equipment drain system is not required to operate to support license renewal intendedfunctions.
Only the exposed, non-embedded portions of the HVAC equipment drain systemLaSalle County Station, Units 1 and 2 2.3-98License Renewal Application Section 2 -Scoping and Screening Methodology and Resultswhich 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 inscope for potential spatial interaction.
Generator Vent and Drain SystemThe purpose of the generator vent and drain system is to collect equipment leakoff anddrainage from the main turbine and associated components.
The generator vent and drainsystem accomplishes this by collecting leakoff and drainage and transferring them for eventualprocessing.
The generator vent and drain system does not perform a license renewalintended function.
Roof Drain SystemThe purpose of the roof drain system is to prevent the accumulation of precipitation on plantbuilding roofs. The roof drain system accomplishes this by collecting roof drainage anddischarging it into the storm drain system. The roof drain system is not required to operate tosupport license renewal intended functions.
Roof drains are not credited to mitigate the effectsof the probable maximum precipitation (PMP). The roofs of safety-related structures aredesigned for the maximum accumulation of water assuming the roof drains are clogged.
Onlythe exposed, non-embedded portions of the roof drain branch lines and headers which havepotential spatial interaction with safety-related equipment in the Reactor Building, Auxiliary
- Building, and Diesel Generator Building perform a license renewal intended function and are inscope for potential spatial interaction.
Wastewater Treatment SystemThe purpose of the wastewater treatment system is to process the station's wastewater tocomply with state and federal Environmental Protection Agency (EPA) guidelines regulating the effluent returned to the cooling lake. The wastewater system accomplishes this byprocessing plant waste water through oil separators, equalization tanks, flocculator-clarifier tanks, and media filters prior to releasing through the cooling lake discharge flume. Thewastewater treatment system does not perform a license renewal intended function.
Sewage Treatment SystemThe purpose of the sewage treatment system is to collect and process plant sewage to meetthe effluent quality limits set by the Illinois Environmental Protection Agency. The sewagetreatment system accomplishes this by collecting sanitary waste through the sanitary wastedrain system and transferring the waste to lift stations for processing through primary andsecondary aerated lagoon cells. The effluent of the lagoon is treated by sand filtration for totalsuspended solids reduction then disinfected prior to release.
The sewage treatment system isnot 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 intendedfunction 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 2.3-99License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsBoundaryThe license renewal scoping boundary of the Plant Drainage System begins at floor andequipment drains and continues through individual drain lines and drain headers which routethe collected drainage to plant collection sumps. Included in this scoping boundary are thecollection 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 primarycontainment 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 chamberbypass 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 aresult of a high energy line break (HELB) or a moderate energy line break (MELB). Theboundary begins at the individual floor drains and continues through individual drain lines anddrain headers and terminates at the Reactor Building floor drain collection sump.The floor drain system for the Auxiliary
- Building, Diesel Generator
- Building, and TurbineBuilding are credited for the removal of fire water from areas containing safe shutdownequipment.
Additionally, the floor drain system in the Diesel Generator Building is credited toprevent the accumulation of oil in areas containing safe shutdown equipment.
The boundarybegins at the individual floor drains and continues through individual drain lines and drainheaders and terminates at the Auxiliary
- Building, Diesel Generator
- Building, or TurbineBuilding floor drain collection sumps.All associated piping, components, and instrumentation contained within the boundarydescribed 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 includesthe nonsafety-related portions of the system located within the Primary Containment andReactor Building.
Included in this boundary are pressure-retaining components relied upon topreserve the leakage boundary intended function of this portion of the system. Also includedin 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 systemlocated 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 thisportion of the system. For more information, refer to the License Renewal Boundary Drawingfor identification of this boundary, shown in red.Not included in the Plant Drainage System scoping boundary is the storm sewer system. Thestorm sewer system is evaluated with Yard Structures.
LaSalle County Station, Units 1 and 2 2.3-100License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsNot 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 thePrimary 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 andwastewater treatment system which do not perform or support intended functions.
Also notincluded in the scope of license renewal are the portions of the Plant Drainage System that arenonsafety-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 systemthat is relied upon to remain functional during and following design basis events. The PlantDrainage System meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of thesystem could prevent satisfactory accomplishment of function(s) identified for 10 CFR54.4(a)(1).
The Plant Drainage System also meets 10 CFR 54.4(a)(3) because it is reliedupon 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) andEnvironmental Qualification (10 CFR 50.49). The Plant Drainage System is not relied upon inany 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 asafety-related function.
The Plant Drainage System contains nonsafety-related water filledlines in the Reactor Building, Primary Containment, Auxiliary
- Building, Diesel Generator
- Building, Offgas Building, and Turbine Building which provide structural support or havepotential spatial interactions with safety-related SSCs. The nonsafety-related floor drainsystem in the Reactor Building is credited for the mitigation of flooding as a result of a highenergy 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 theirpressure boundary integrity to prevent drywell to suppression chamber bypass leakage.
- 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.
- 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 floordrain systems in the Auxiliary
- Building, Diesel Generator
- Building, and Turbine Building arecredited for the removal of fire water from areas containing safe shutdown equipment.
TheLaSalle County Station, Units 1 and 2 2.3-101License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsfloor drain system in the Diesel Generator Building is credited to prevent the accumulation ofoil in areas containing safe shutdown equipment.
UFSAR References 2.4.2.3Table 3.2-13.4.1.4Table 3.8-13.11.1.15.2.5.1.1 6.2.4.2.2 Table 6.2-21Table 6.2-287.3.2.2.11 7.6.2.27.7.159.2.59.3.39.5Appendix J.4License Renewal Boundary DrawingsLR-LAS-M-91, Sheets 1, 2, 3, 4, 5, 6LR-LAS-M-1 04, Sheets 1, 2, 3LR-LAS-M-1 05, Sheets 1, 2, 3LR-LAS-M-1 06, Sheets 4, 8LR-LAS-M-129, Sheets 1, 2, 3, 4, 7, 8, 9LR-LAS-M-1 37, Sheets 1, 2, 3, 4, 5, 6LR-LAS-M-149, Sheets 1, 2, 3LR-LAS-M-1 50, Sheet 2LR-LAS-M-151, Sheets 3, 4LR-LAS-M-55, Sheets 1, 2, 7, 8LR-LAS-M-66, Sheets 1, 3, 5, 9, 10, 11LR-LAS-M-72, Sheets 1, 2, 5LR-LAS-M-76, Sheet 4LR-LAS-M-83, Sheets 1, 2, 3LR-LAS-M-85, Sheet 1LR-LAS-M-86, Sheet 1LR-LAS-M-87, Sheets 1, 2, 3LR-LAS-M-89, Sheet 1LR-LAS-M-90, Sheets 1, 2, 3LR-LAS-M-93, Sheets 1, 2, 4LR-LAS-M-94, Sheet 1LR-LAS-M-95, Sheet 1LR-LAS-M-96, Sheets 1, 2, 3, 4LR-LAS-M-97, Sheets 1, 2, 3, 4LR-LAS-M-98, Sheets 1, 4LR-LAS-M-99, Sheet 1LR-LAS-M-100, Sheets 1, 3, 4LaSalle County Station, Units 1 and 2 2.3-102License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsLR-LAS-M-101, Sheets 1, 2LR-LAS-M-102, Sheet 11LR-LAS-M-103, Sheets 15, 16, 19LR-LAS-M-109, Sheet 1LR-LAS-M-1 15, Sheets 2, 12LR-LAS-M-1 16, Sheets 2, 7LR-LAS-M-1 26 Sheets 1, 2, 3LR-LAS-M-130, Sheets 1, 2LR-LAS-M-132, Sheet 1LR-LAS-M-133, Sheet 1LR-LAS-M-134, Sheets 1, 2, 3LR-LAS-M-1 36, Sheets 1, 2, 3LR-LAS-M-139, Sheets 1, 2, 4LR-LAS-M-140, Sheet 1LR-LAS-M-141, Sheet 1LR-LAS-M-142, Sheets 1, 2, 3, 4LR-LAS-M-143, Sheets 1, 2, 3, 4LR-LAS-M-144, Sheet 1LR-LAS-M-145, Sheet 1LR-LAS-M-146, Sheets 1, 3, 4LR-LAS-M-147, Sheets 1, 2LR-LAS-M-1 53, Sheets 4, 6LR-LAS-M-159, Sheet 2Table 2.3.3-16 Plant Drainage SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureHeat Exchanger
-(Drywell Equipment Leakage BoundaryDrain Sump Heat Exchanger)
Tube SideComponents Heat Exchanger
-(Reactor Building Leakage BoundaryEquipment Drain Tank Heat Exchanger)
Tube Side Components Hoses Leakage BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (Drywell Floor and Drywell Leakage BoundaryEquipment Drain Pumps)Pump Casing (Reactor Building Leakage BoundaryEquipment Drain Pump)Pump Casing (Sump Pumps) Leakage BoundaryTanks (Gland Seal Leakoff Reservoir)
Leakage BoundaryTanks (Reactor Building Equipment Drain Leakage BoundaryTank)Valve Body Leakage BoundaryPressure BoundaryLaSalle County Station, Units 1 and 2License Renewal Application 2.3-103 Section 2 -Scoping and Screening Methodology and ResultsThe aging management review results for these components are provided in:Table 3.3.2-16 Plant Drainage SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-104 Section 2 -Scoping and Screening Methodology and Results2.3.3.17 Primary Containment Ventilation SystemDescription The Primary Containment Ventilation (PCV) System is a normally operating system designedto limit the maximum average temperature of the air to maintain drywell air temperature withinequipment operating limits.The purpose of the PCV System is to maintain a suitable environment inside the drywell forequipment 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 arenot in scope.The PCV System is composed of two subsystems, the primary containment ventilation plantsystem and the primary containment chilled water plant system. The two subsystems worktogether to maintain the reliability of equipment located in the drywell.
The ventilation subsystem circulates cooling air within the drywell.
The chilled water subsystem removes heatfrom the drywell air.A portion of the PCV system performs a safety-related function.
The chilled water piping thatpenetrates Primary Containment and the associated primary containment isolation valves aresafety-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.BoundaryThe ventilation portion of the PCV system consists of two supply systems, each containing asupply fan which takes suction from the drywell, circulates this air through a drywell coolertrain, and discharges the cooled air to two ring headers inside the drywell.
The lower ringheader supplies cooled air to the lower levels of the drywell.
The upper ring header containssix 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 trainsand 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 chilledwater 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 portionof the system, the primary containment isolation valves on the chilled water supply and returnpiping and associated piping and valves.All associated piping, components, and instrumentation contained within the boundarydescribed above are also included in the PCV System scoping boundary.
Also included in the PCV scoping boundary are those portions of nonsafety-related piping andequipment that extend beyond the safety-related/nonsafety-related interface up to the locationof the first seismic anchor, or to a point where there is no longer the potential for spatialinteraction with safety-related equipment, whichever extends furthest.
This includes theLaSalle County Station, Units 1 and 2 2.3-105License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsnonsafety-related portions of the system located within the Primary Containment, the ReactorBuildings and the Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of this portion ofthe system, including all associated piping, components and instrumentation.
For moreinformation, refer to the License Renewal Boundary Drawings for identification of thisboundary, shown in red.Not included in the PCV System scoping boundary are the components associated with thecooling 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 buildingclosed cooling water plant system, which can be aligned to provide an alternate source ofcontainment cooling when the reactor is shut down and the normal chilled water subsystem isunavailable.
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 isnonsafety-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 drywellthat 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 basisevents. The Primary Containment Ventilation System meets 10 CFR 54.4(a)(2) becausefailure 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 Systemalso meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analyses and plantevaluations 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 afunction 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 primarycontainment isolation valves in the chilled water piping to and from the drywell.
- 2. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The PCV system includes nonsafety-related water filled piping andcomponents 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 2.3-106License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsvalves that are environmentally qualified.
UFSAR References 9.2.99.4.9Table 3.2-1License Renewal Boundary DrawinQsLR-LAS-M-86, Sheets 1, 3LR-LAS-M-1 33, Sheets 1, 3LR-LAS-M-1453, Sheet 1LR-LAS-M-1454, Sheet 1LR-LAS-M-90, Sheet 3LR-LAS-M-1 02, Sheet 11LR-LAS-M-136, Sheet 3LR-LAS-M-1 29, Sheets 1, 8, 9Table 2.3.3-17 Primary Containment Ventilation SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureDucting and Components Leakage BoundaryHeat Exchanger
-(Primary Containment Leakage BoundaryVent Chiller Compressor Oil Cooler) ShellSide Components Heat Exchanger
-(Primary Containment Leakage BoundaryVent Chiller Evaporator)
Tube SideComponents Heat Exchanger
-(Primary Containment Leakage BoundaryVent Chiller Evaporator)
TubesHeat Exchanger
-(Primary Containment Leakage BoundaryVentilation HX and Drywell Area Cooler)TubesPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (Primary Containment Leakage BoundaryChilled Water Pumps)Tanks (Chilled Water Holdup and Leakage BoundaryExpansion Tanks, Chilled WaterChemical Feeders)Valve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:LaSalle County Station, Units 1 and 2License Renewal Application 2.3-107 Section 2 -Scoping and Screening Methodology and ResultsTable 3.3.2-17 Primary Containment Ventilation SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 2.3-108License Renewal Application Section 2 -Scoping and Screening Methodology and Results2.3.3.18 Process Radiation Monitoring SystemDescription The Process Radiation Monitoring System is a normally operating system designed to monitorthe 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 forcertain systems, support the prevention of an uncontrolled release of radioactive liquids,gases, and particulates by providing isolation signals to the monitored systems.
The ProcessRadiation Monitoring System consists of safety-related and nonsafety-related portions and isin scope for license renewal.
- However, portions of the Process Radiation Monitoring Systemare not required to perform intended functions and are not in scope.The following process radiation monitors within the Process Radiation Monitoring System aresafety-related:
The main steam line radiation monitors are located downstream of the outboard main steamisolation valves, providing indication of radiation levels external to the main steam lines. Anabnormal high radiation condition indicates a release of fission products from the fuel andresults in a control room alarm.The Reactor Building ventilation exhaust radiation monitors indicate and record radiation levelsfrom 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 thelicense 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 fromthe fuel floor area vent exhaust duct upstream of the duct isolation valves. An abnormal highradiation condition results in automatic isolation of the Reactor Building ventilation system,start of the Standby Gas Treatment System, closure of primary containment purge and ventvalves, and a control room alarm.The control room ventilation intake radiation monitors indicate and record radiation levels fromthe 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 isthen 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 GasTreatment 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 controlroom alarm.The following process radiation monitors within the Process Radiation Monitoring System arenonsafety-related:
The residual heat removal (RHR) service water (part of the Essential Cooling Water licenserenewal system) effluent radiation monitors are located on the cooling water pipingdownstream of each of the two RHR heat exchangers.
Indication of radiation level is providedin the control room. An abnormal high radiation condition results in a control room alarm.LaSalle County Station, Units 1 and 2 2.3-109License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsThe service water (part of the Non-Essential Cooling Water license renewal system) effluentradiation monitor is located at the inlet to the circulating water standpipe prior to discharge tothe cooling lake. Indication of radiation level is provided in the control room. An abnormalhigh radiation condition results in a control room alarm.The liquid radwaste effluent radiation monitor is located on the radwaste effluent line prior tomixing with lake blowdown flow prior to entering the river. Indication of radiation level isprovided 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 Waterlicense 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 therecombiner upstream of the charcoal beds. Indication of radiation level is provided in thecontrol 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 thecharcoal beds upstream of the discharge valve. Indication of radiation level is provided in thecontrol room. An abnormal high radiation condition results in automatic closure of the carbonbed 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 ofradiation level is provided in the control room. An abnormal high radiation condition results ina control room alarm.The station vent stack effluent radiation monitor draws a sample from the station vent stackexhaust.
Indication of radiation level is provided in the control room. An abnormal highradiation 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, and11.5.BoundaryThe scoping evaluation boundary for the Process Radiation Monitoring System begins at thesample panel inlet valve on each of the following sample panels: RHR service water effluentmonitor loops A and B, RBCCW monitor, service water effluent
- monitor, and liquid radwasteeffluent monitor.
The scoping boundary continues through the sample pump, samplechamber, flow control valve, flow indicator, and ends at the sample panel outlet valve, fromwhich the sample is routed back to the process piping. The components within theseboundaries 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) spatialand/or structural support functions.
The scoping boundary for the radiation monitor systems for the main steam lines, control roomLaSalle County Station, Units 1 and 2 2.3-110License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsair intake, reactor building ventilation
- exhaust, and fuel floor vent plenum exhaust onlyincludes the radiation elements since the radiation elements are external to the process flowpath and do not have associated tubing or piping components.
These radiation elements aresafety-related components that are within the scope of license renewal.
The scopingboundary for the off-gas gas carbon bed vault radiation monitor system also only includes theradiation elements since the radiation elements are external to the process flow path and donot 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 licenserenewal.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 andincludes all piping components, sample pumps, and instrumentation on the panels. Theseradiation monitoring systems are nonsafety-related and do not have the potential for spatialinteraction with safety- related equipment since they do not contain fluids. Therefore they donot 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 thepiping connections to the standby gas treatment stack and continues to the standby gastreatment vent monitoring panels (OPL58JA and OPL58JB) and continues via the piping thatreturns to the stack. The radiation elements on these monitoring panels are abandoned inplace, do not have intended functions, and are not in scope for license renewal.
The scopingboundary 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 pipingthat returns to the stack where the boundary ends. Included are piping components, samplepumps, 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 pipingconnections to the station vent stack and continues to the station vent stack sampleconditioner panel, continues to the station vent stack wide range gas monitor panel, andcontinues via the piping that returns to the stack where the boundary ends. Included arepiping components, sample pumps, and instrumentation on the panels. The components within this boundary are nonsafety-related but the alarm function from the station vent stackwide range radiation monitor is credited for prompting operator actions in response to aradioactive gaseous leak abnormal operational transient.
Therefore, the station vent stackeffluent monitor and associated piping components are within the scope of license renewal.All associated piping, components, and instrumentation contained within the boundarydescribed above are also included in the Process Radiation Monitoring System scopingboundary.
Also included in the Process Radiation Monitoring System scoping boundary are thoseportions 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 pointwhere 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 locatedwithin the Reactor Buildings and Auxiliary Buildings.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of thisportion of the system. For more information, refer to the License Renewal Boundary Drawingsfor identification of this boundary, shown in red.LaSalle County Station, Units 1 and 2 2.3-111License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsNot included in the Process Radiation Monitoring System scoping boundary are those portionsof piping, piping components, and piping elements coming from the various plant systemsconnected to the radiation monitoring systems.
While in scope for license renewal, they areevaluated with the license renewal system from which the fluid originates.
These systemsinclude the Closed Cooling Water System, Nonessential Cooling Water System, RadwasteSystem, Essential Cooling Water System, and Standby Gas Treatment System. The stationvent 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 basisevents. The Process Radiation Monitoring System meets 10 CFR 54.4(a)(2) because failureof nonsafety-related portions of the system could prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
The Process Radiation Monitoring System alsomeets 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 forEnvironmental Qualification (10 CFR 50.49). The Process Radiation Monitoring System is notrelied 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 safetyfeatures actuation.
The Process Radiation Monitoring System monitors plant processes forradiation level and initiates appropriate protective action to limit the potential release ofradioactive 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 roomventilation 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 asafety-related function.
Some nonsafety-related portions of the system provide structural restraint or support for safety-related components.
Some nonsafety-related portions of thesystem are liquid-filled and have the potential for spatial interaction with safety-related equipment in the Reactor and Auxiliary Buildings.
- 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The station vent stack wide range radiation monitor is credited tosense process conditions and generate signals to actuate control room alarms to promptoperator actions in response to a radioactive gas waste system leak or failure abnormaloperational transient.
- 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 isenvironmentally qualified to remain functional during post-accident conditions.
LaSalle County Station, Units 1 and 2 2.3-112License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsUFSAR References 6.47.1.27.3.47.6.17.7.149.4.111.515.7.1License Renewal Boundary Drawinqgs LR-LAS-M-153, Sheets 1, 3, 4, 6, 7Table 2.3.3-18 Process Radiation Monitoring SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureHoses Leakage BoundaryPiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryStructural Integrity Pump Casing ( SGTS and SVS Wide Pressure BoundaryRange Sample Pumps)Pump Casing (RHR Service Water Leakage BoundarySample Pumps)Pump Casing (SGTS Vent Monitor Structural Integrity 0PL058 Sample Pumps)Pump Casing (Sample Pumps -Leakage BoundaryRadwaste, Service Water, RBCCW)Valve Body Leakage BoundaryPressure BoundaryStructural Integrity The aging management review results for these components are provided in:Table 3.3.2-18Process Radiation Monitoring SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-113 Section 2 -Scoping and Screening Methodology and Results2.3.3.19 Process Sampling and Post Accident Monitoring SystemDescription The Process Sampling and Post Accident Monitoring System is a normally operating systemdesigned to provide indication of critical parameters within containment, to obtainrepresentative samples from process streams and convey them to central sample stations foruse 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 SystemThe purpose of the containment monitoring system is to provide indication and alarms forvarious containment parameters during normal and abnormal operating conditions.
Most ofthe containment monitoring system is designed to operate during and following a design basisLOCA, and is therefore safety-related.
All subsystems, except oxygen monitoring, tritium grabsample station, and continuous air monitoring (CAMS), continue to operate during LOCAconditions and are provided with redundant instrumentation which are powered by separate byESF 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 floodingwater levels, DW and SC oxygen and hydrogen concentrations, DW gross radiation and DW 0and SC airborne radiation levels.Process Sampling SystemThe purpose of the process sampling portion of the system is to provide the capability forsampling various process systems during normal plant power operation and shutdownconditions.
Plant process sampling stations are located in the Reactor,
- Turbine, andRadwaste Buildings, and the River Screen House. The process sampling system has nosafety-related function.
It accomplishes this purpose by taking representative samples fromvarious process lines. The Reactor Building and Turbine Building sample stations areequipped with analyzers that continuously monitor critical parameters.
Grab samples may betaken periodically from each station to determine constituents.
At each station, samples areadjusted for pressure and temperature as required by the monitoring instruments and foroperators' safety. Sample wastes are returned to the condenser, radwaste drains, orequipment drain system as appropriate.
Post-Accident SamplingThe purpose of the post-accident portion of the system is to obtain representative liquid andgas grab samples from the reactor coolant system and within containments for radiological and chemical analysis under accident conditions.
The post-accident sampling system has nosafety-related function.
Failure of the system does not compromise any safety-related systemor component, or prevent safe shutdown of the plant. The post-accident portion of the systemwas originally designed to satisfy certain requirements of NUREG-0737, however elimination Vof the requirements to have and maintain the post-accident sampling system, has beenLaSalle County Station, Units 1 and 2 2.3-114License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsapproved by plant license amendments.
Gaseous and liquid samples are capable of being taken by the post-accident sampling systemfrom the suppression chamber and drywell atmospheres, secondary containment atmosphere, reactor coolant, and drywell equipment and floor drain sumps. Suppression chamber anddrywell atmosphere samples are taken utilizing the containment monitoring system.Secondary containment atmosphere samples are taken from the Reactor Building in thevicinity 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 ResidualHeat Removal System (RHR) loop sample points. The RHR System sample points providesuppression pool inventory samples when operating in suppression pool cooling, spray, or lowpressure coolant injection modes. Fuel pool inventory liquid samples can be obtained whenRHR is operating in the fuel pool cooling assist mode. Gaseous samples are returned to thesuppression chamber.
Liquid samples and leakage collected in the High Radiation SamplingSystem (HRSS) waste tank are returned either to the waste collection tank or the drywellequipment sump.For more detailed information, see UFSAR Sections 7.5.2, 9.3.2, and 11.5.5.BoundaryThe scoping evaluation boundary for containment monitoring system begins at various samplepoints located within containment and are connected to various sampling panels andinstruments.
The sensing lines have installed excess flow check valves in series with manualisolation valves. Sample lines have series mounted solenoid valves on both sample sourceand return lines to provide containment isolation when required.
Sample stations are enclosedunits preventing internal leakage from impacting surrounding in scope equipment.
The samplestation enclosures are evaluated as a structural commodities as they serve as piping anchorpoints for (a)(1) in scope piping. Components within the sample station enclosure, notrequired 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 tosupport specific (a)(3) functions, are identified on boundary drawings in green. Systemcomponents that are in scope for spatial interaction or structural support are shown onboundary drawings marked in red.The scoping boundary for the process sampling system begins at the point where the variousprocess lines connect to sample panel inlet isolation valves. It continues through samplecoolers and where installed, specific sampling instrumentation.
It ends where the sampledfluid is returned to the condenser, turbine building drains, reactor building equipment or floordrains, radwaste or lake sample pit based on the specific sample station.
Components withinthe sample station enclosures, not required for license renewal functions, are not in scope forspatial 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 thevarious process lines connect to sample panel inlet isolation valves. It continues throughsample coolers and where installed, specific sampling instrumentation.
Process fluids arepiped to the HRSS waste tank where they can be returned to the unit waste collection tank ordrywell equipment sumps based on sampling results.
The scoping boundary ends where thepiping system connects to the Radwaste System (waste collection tank) and the PlantDrainage System (drywell equipment drain sump). Components within the sample stationLaSalle County Station, Units 1 and 2 2.3-115License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsenclosure, not required for license renewal functions, are not in scope for spatial interaction orstructural support.
The post-accident sampling system is not safety-related and is only inscope for spatial interaction or structural support.All associated piping, components, and instrumentation contained within the boundarydescribed 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 scopingboundary are those portions of nonsafety-related piping and equipment that extend beyondsafety-related/nonsafety-related interface up to the location of the first seismic anchor, or to apoint where there is no longer the potential for spatial interaction with safety-related equipment, whichever extends furthest.
This includes the nonsafety-related portions of thesystem located within the Reactor Buildings and Auxiliary Building.
Included in this boundaryare pressure-retaining components relied upon to preserve the leakage boundary intendedfunction of this portion of the system. For more information, refer to the License RenewalBoundary Drawing for identification of this boundary, shown in red.Not included in the Process Sampling and Post Accident Monitoring System scoping boundaryare those portions of piping, piping component, and piping elements coming from various plantsystems 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.
Systemsinclude Closed Cooling Water System, Condensate System, Nonessential Cooling WaterSystem, Reactor Coolant Pressure Boundary System, Reactor Water Cleanup System, andthe Residual Heat Removal System. The sample enclosures and compressed gas bottlestorage racks are in scope and are evaluated with the Structural Commodity Group. The heattrace that is installed on containment monitoring piping is evaluated with the Heat TraceSystem.Not included in the scope of license renewal for the Process Sampling and Post AccidentMonitoring System are piping and components not supporting an intended
- function, locatedwithin the sample enclosures surrounding the sample stations, piping racks, and sample chillerassemblies located in the Reactor Buildings, Auxiliary
- Building, and Turbine Buildingstructures, as these sample enclosures contain no safety-related equipment.
The sampleenclosures provide physical shielding, and the enclosed components do not have the potential for spatial interaction with safety-related components.
The sample enclosures preventleakage or spray from impacting safety-related components.
Also not included in the scope oflicense 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 andfollowing design basis events. The Process Sampling and Post Accident Monitoring Systemmeets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the system couldprevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
TheProcess 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 thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48), Environmental Qualification (10 CFR 50.49), and Station Blackout (10 CFR 50.63).LaSalle County Station, Units 1 and 2 2.3-116License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsThe Process Sampling and Post Accident Monitoring System is not relied upon in any safetyanalyses or plant evaluations to perform a function that demonstrates compliance with theCommission'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 featureactuation.
The Process Sampling and Post Accident Monitoring System includes containment pressure instrumentation that actuates a reactor trip and an actuation of emergency corecooling system and primary and secondary containment isolation.
- 2. Provide primary containment boundary.
The Process Sampling and Post AccidentMonitoring System includes piping and isolation valves that are part of the primarycontainment boundary.
- 3. Control combustible gas mixtures in the primary containment atmosphere.
The ProcessSampling and Post Accident Monitoring System includes equipment that samples thecontainment atmosphere and provides indication of oxygen and hydrogen concentration.
- 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
Some portions of the nonsafety-related the Process Sampling andPost Accident Monitoring System are relied upon to preserve the structural support intendedfunction of the safety-related piping used for sampling and instrumentation as well as forcontainment isolation.
Some portions of the sampling system may be liquid filled and have thepotential for spatial interaction with safety-related equipment found in the Reactor andAuxiliary Buildings.
- 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 Shutdownrequirements.
- 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 designbasis 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 undercoping requirements.
UFSAR References 7.5.29.3.211.5.5LaSalle County Station, Units 1 and 2 2.3-117License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsLicense Renewal Boundary DrawingsLR-LAS-M-92, Sheets 1, 2LR-LAS-M-93, Sheets 4, 5LR-LAS-M-115, Sheets 1, 2, 12, 13, 14, 15LR-LAS-M-138, Sheets 1, 2LR-LAS-M-1 39, Sheets 4, 5LR-LAS-M-1 56, Sheets 1, 2, 3, 4, 5LR-LAS-M-158, Sheets 1, 2, 3, 4LR-LAS-M-159, Sheets 1, 2Table 2.3.3-19Process Sampling and Post Accident Monitoring SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureCompressor Housing Structural Integrity Flow Device Pressure BoundaryThrottlePiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryStructural Integrity Pump Casing (H2/02 Sample Pumps) Pressure BoundaryPump Casing (HRSS Room Sump Pump) Leakage BoundaryPump Casing (HRSS Sample Pump) Leakage BoundaryPump Casing (HRSS Waste Pumps) Leakage BoundaryTanks (HRSS Waste Tank) Leakage BoundaryValve Body Leakage BoundaryPressure BoundaryStructural Integrity The aging management review results for these components are provided in:Table 3.3.2-19Process Sampling and Post Accident Monitoring SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-118 Section 2 -Scoping and Screening Methodology and Results2.3.3.20 Radwaste SystemDescription The intended function of the Radwaste System for license renewal is to maintain leakageboundary integrity to preclude system interactions.
For this reason, this system's pressure-retaining components located in areas where there are potential spatial interactions withsafety-related equipment have been included in the scope of license renewal.
This system isnot required to operate to support license renewal intended functions, and is in scope only forpotential 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, andgaseous 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 andare not in scope.Liquid Radwaste SystemThe liquid radwaste plant system includes the waste/equipment drain processing subsystem, the floor drain processing subsystem, the chemical waste subsystem, the laundry wastesubsystem, and the sludge subsystem.
The purpose of the liquid radwaste system is tocollect,
- monitor, and process all potentially radioactive liquid wastes produced by the station.The waste/equipment drain processing subsystem collects and processes high purity (lowconductivity) sources of radioactive liquid waste such as plant equipment drains. This water istreated by settling, filtration, and demineralization and is returned for station reuse through thecycled 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 usingportable vendor supplied waste treatment equipment and is returned for station reuse throughthe 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 ofradioactive liquid waste such as decontamination and laboratory drains, and, spent resin andsludge tank decantate.
This water is treated using portable vendor supplied waste treatment equipment and is returned to liquid radwaste system tanks for additional processing.
Thechemical waste subsystem includes mixed bed demineralizers which may be used to assist inprocessing.
The laundry waste subsystem collects and processes laundry waste or other soapy, highorganic 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 ofprocessing radioactive liquid wastes. Sludge subsystem tanks provide settling capability forseparation of liquid and solid wastes, holdup for radioactive decay, and storage of slurries priorto transfer to the solid radwaste system.LaSalle County Station, Units 1 and 2 2.3-119License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsSolid Radwaste SystemThe purpose of the solid radwaste plant system is to process all radioactive wet solid wastesproduced 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 tooffsite shipment and disposal.
The solid radwaste system also receives, decontaminates and/or compacts, and provides temporary storage for all radioactive dry wastes produced bythe station prior to offsite shipment and disposal.
Gaseous Radwaste SystemThe purpose of the gaseous radwaste plant system is to process and control the release ofgaseous radioactive wastes to the site environment.
The gaseous radwaste systemaccomplishes this through the use of high-temperature catalytic recombining, holdup fordecay, high-efficiency particulate filtration, and charcoal adsorption prior to discharging to thestation vent stack (evaluated with the Auxiliary Building structure).
For more detailed information see UFSAR Sections 11.2, 11.3, and 11.4.BoundaryThe 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 locatedwithin the Reactor Building and Auxiliary Building.
Included in this boundary are pressure-retaining components relied upon to preserve the leakage boundary intended function of thissystem. For more information, refer to the License Renewal Boundary Drawing foridentification 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 PlantDrainage 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 systemwide range gas monitoring sample pump. The standby gas treatment system wide range gasmonitoring 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 thesystem are safety-related or relied upon to remain functional during and following design basisevents. 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 for10 CFR 54.4(a)(1).
The Radwaste System is not in scope under 10 CFR 54.4(a)(3) because itis not relied upon in safety analyses or plant evaluations to perform a function thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48), Environmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10CFR 50.62), and Station Blackout (10 CFR 50.63).LaSalle County Station, Units 1 and 2 2.3-120License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsIntended Functions
- 1. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The Radwaste System contains nonsafety-related fluid filled lines inthe Reactor Building and Auxiliary Building which have potential spatial interactions withsafety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References 1.2.3.42.4.123.1.2.6.2.3 Table 3.2-17.7.107.7.1111.211.311.411.5.2.3.3 License Renewal Boundary DrawingsLR-LAS-M-97, Sheet 1LR-LAS-M-103, Sheets 15, 16, 27LR-LAS-M-113, Sheet 1LR-LAS-M-143, Sheet 1LR-LAS-M-1 53, Sheet 4Table 2.3.3-20 Radwaste SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosurePiping, piping components, and piping Leakage BoundaryelementsPump Casing (Cleanup Phase Separator Leakage BoundarySludge Pump)Tanks (RWCU Cleanup Phase Leakage BoundarySeparators)
Valve Body Leakage BoundaryThe aging management review results for these components are provided in:Table 3.3.2-20 Radwaste SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2 2.3-121License Renewal Application Section 2 -Scoping and Screening Methodology and Results2.3.3.21 Reactor Water Cleanup SystemDescription The Reactor Water Cleanup (RWCU) System is designed to maintain high purity reactorwater. 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 cleanup reactor coolant.The purpose of the RWCU System is to: remove solid and dissolved impurities fromrecirculated reactor coolant; discharge excess reactor water during startup,
- shutdown, and hotstandby conditions; minimize temperature gradients in the recirculation piping and vesselduring periods of low flow rates; and conserve reactor heat. The RWCU System accomplishes these purposes by forced circulation of reactor coolant through regenerative andnon-regenerative heat exchangers and filter-demineralizers.
The RWCU System also provides for monitoring the durability and effectiveness of noble metalcompounds deposited on reactor vessel and piping surfaces.
The RWCU Systemaccomplishes this by processing reactor coolant through a material monitoring system and adata 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 providesfor long-term leakage control in the event of a piping failure in the RWCU System. Anonsafety-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 andinstrumentation for the determination of RWCU System high differential flow. The highdifferential flow signal is an indication of leakage or a break in RWCU piping and is used toautomatically isolate the RWCU system from the reactor coolant pressure boundary.
The RWCU blowdown flow control valve, RWCU discharge to main condenser valve, andRWCU drain to waste surge tanks valve are credited as high-low pressure interfaces for FireSafe Shutdown.
For more detailed information see UFSAR Section 5.4.8.BoundaryThe RWCU System license renewal scoping boundary begins downstream of the RWCUSystem suction outboard containment isolation valve. The boundary continues through thetwo RWCU recirculation pumps, the common pump discharge header, the tube sides of thetwo regenerative heat exchangers, the tube sides of the two non-regenerative heatexchangers (the shell sides are evaluated with the Closed Cycle Cooling Water System),
andthe 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 theFeedwater System. The RWCU System license renewal scoping boundary includesblowdown lines to the main condenser (evaluated with the Condenser and Air RemovalSystem) and waste surge tanks (evaluated with the Radwaste System).LaSalle County Station, Units 1 and 2 2.3-122License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsIncluded 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 noblemetal compounds deposited on reactor vessel internals and reactor coolant pressureboundary piping surfaces.
The material monitoring system samples reactor coolant from thecommon discharge header of the RWCU pumps and returns reactor coolant to the commonheader upstream of the RWCU pumps.All associated piping, components and instrumentation contained within the boundarydescribed 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe 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 preservethe 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 inred.Not included in the RWCU System scoping boundary are the reactor coolant pressureboundary and containment isolation piping and components associated with the suctionportion of the system which are evaluated with the Reactor Coolant Pressure BoundarySystem.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. TheReactor 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 for10 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 thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48) and Environmental Qualification (10 CFR 50.49). The Reactor Water Cleanup Systemis not relied upon in any safety analyses or plant evaluations to perform a function thatdemonstrates compliance with the Commission's regulations for Anticipated Transient WithoutScram (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 leakagecontrol 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 safetyLaSalle County Station, Units 1 and 2 2.3-123License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsfeatures actuation.
The RWCU System includes safety-related flow elements andinstrumentation for the determination of RWCU System high differential flow. The highdifferential flow signal is an indication of leakage or a break in RWCU piping and is used toautomatically isolate the RWCU System from the reactor coolant pressure boundary.
- 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The RWCU System contains nonsafety-related high energy andmoderate 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 RWCUblowdown flow control valve, RWCU discharge to main condenser valve, and RWCU drain towaste surge tanks valve are credited as high-low pressure interfaces for Fire Safe Shutdown.
- 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 onthe return line to the reactor.
UFSAR References 1.2.2.3.5 1.2.2.6.6 Table 3.2-15.2.5Table 5.2-85.4.86.2.4.2.1 Table 6.2-21Table 6.2-287.3.2.2.3.8 7.6.2.2.6 7.7.8Appendix CLicense Renewal Boundary DrawingsLR-LAS-M-97, Sheets 1, 2, 3, 4, 5LR-LAS-M-143, Sheets 1, 2, 3, 4, 5LR-LAS-M-57, Sheet 1LR-LAS-M-91, Sheets 1, 2LR-LAS-M-100, Sheet 1LR-LAS-M-103, Sheets 15,16, 19LR-LAS-M-115, Sheets 1, 12LR-LAS-M-118, Sheet 1LR-LAS-M-1 37, Sheets 1, 2LR-LAS-M-146, Sheet 1 0LR-LAS-M-159, Sheet 1LaSalle County Station, Units I and 2 2.3-124License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.3-21Reactor Water Cleanup SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureHeat Exchanger
-(Clean-Up Leakage BoundaryRegenerative Heat Exchangers)
ShellSide Components Heat Exchanger
-(Clean-Up Leakage BoundaryRegenerative Heat Exchangers)
TubeSide Components Heat Exchanger
-(Clean-up Non- Leakage BoundaryRegenerative Heat Exchanger)
Tube SideComponents Heat Exchanger
-(RWCU Pump Heat Leakage BoundaryExchanger)
Shell Side Components Piping, piping components, and piping Leakage Boundaryelements Pressure BoundaryPump Casing (Clean-Up Filter Leakage BoundaryDemineralizer Holding Pump)Pump Casing (Clean-Up Filter Leakage BoundaryDemineralizer Precoat Pump)Pump Casing (Reactor Water Clean-Up Leakage BoundaryRecirculation Pump)Tanks (Clean-Up Filter Demineralizer Leakage BoundaryPrecoat Tank)Tanks (Clean-Up Filter Demineralizer)
Leakage BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-21Reactor Water Cleanup SystemSummary of Aging Management Evaluation LaSalle County Station, Units I and 2License Renewal Application 2.3-125 Section 2 -Scoping and Screening Methodology and Results2.3.3.22 Safety-Related Ventilation SystemDescription The Safety-Related Ventilation (SRV) System is a normally operating system designed toprovide a favorable environment for plant equipment and personnel while preventing thespread of contamination in the plant. The SRV System also includes dampers and ductworkthat are part of the secondary containment boundary.
The SRV System is in scope for licenserenewal.
- 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 plantsystems:
Reactor Building ventilation system, ECCS equipment cooling ventilation system,diesel generator room ventilation system, switchgear heat removal system, and TurbineBuilding ventilation system.Reactor Building Ventilation The Reactor Building ventilation plant system provides filtered outdoor air to control theReactor Building temperature in generally accessible areas, and to maintain a minimumnegative pressure of 0.25 inches of water with respect to atmospheric pressure.
The systemperforms 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, theexhaust duct pressure relief dampers and excess flow check dampers ensure the integrity ofthe Seismic Category I exhaust plenum walls.ECCS Equipment Cooling Ventilation The ECCS equipment cooling ventilation plant system performs the safety-related function toprovide cooling to the ECCS equipment cubicles whenever the ECCS equipment is requiredfor service.
The system removes equipment heat from the ECCS equipment areas andmaintains temperatures within equipment limits.Diesel Generator Room Ventilation The diesel generator room ventilation plant system provides safety-related ventilation to thediesel generator rooms, the diesel generator storage tank rooms, the diesel generator daytank 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 RemovalThe switchgear heat removal plant system provides safety-related ventilation to the reactorprotection system MG Set room, the essential switchgear areas, and battery rooms. Thesystem 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 theTurbine Building to maintain area temperatures within equipment requirements.
The steamLaSalle County Station, Units 1 and 2 2.3-126License Renewal Application Section 2 -Scoping and Screening Methodology and Resultstunnel check dampers in this system perform a safety-related function to close during highenergy line break conditions to form a pressure boundary between the main steam tunnel andthe HPCS switchgear room. The Turbine Building ventilation exhaust through the station ventstack provides a pathway for the potential release of fission products following certainabnormal operating conditions.
For more detailed information, see UFSAR Sections 6.2.3, 7.3.7, 9.4.2, 9.4.4, 9.4.5, and15.7.1.BoundaryThe SRV System license renewal scoping boundary includes the following plant systems asdiscussed in the System
Description:
Reactor Building ventilation system, ECCS equipment cooling ventilation system, diesel generator room ventilation system, switchgear heat removalsystem, and Turbine Building ventilation system. The scoping boundary begins where outsideair provides fresh air to supply fans and ends where exhaust air either exits the structure orenters 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 ductsfrom elevation 843'6" to elevation 736'6" inside the Reactor Building; and the steam tunnelisolation dampers.
The SRV System also includes the ECCS equipment cooling ventilation equipment including the cubicle cooling fans and coils and associated ductwork.
Also includedare the diesel generator room ventilation and switchgear heat removal plant systems, whichinclude supply and exhaust fans, filters and associated dampers and ductwork, and theTurbine Building ventilation exhaust to the plant vent stack and associated components andductwork.
The SRV boundary also includes the associated instrumentation and controls forthe above equipment.
All associated piping, components, and instrumentation contained within the boundarydescribed 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe nonsafety-related portions of the system located within the Reactor Buildings.
Included inthis boundary are pressure-retaining components relied upon to preserve the leakageboundary intended
- function, specifically the CSCS equipment area cubicle cooler drain pans.For more information, refer to the License Renewal Boundary Drawing for identification of thisboundary, shown in red.Not included in the SRV System scoping boundary are the components associated with thecooling water supply to the ECCS equipment cubicle coolers which are evaluated with theEssential Cooling Water System. Additionally, the fire protection function of fire dampers isevaluated with the Fire Protection System. The ventilation stack that receives exhaust air fromthe Reactor Building ventilation system is evaluated with the Auxiliary Building Structure.
TheSRV system interfaces with the heat recovery plant system, which heats the air entering thebuilding.
The heat recovery subsystem components are evaluated with the Nonsafety-Related Ventilation System.LaSalle County Station, Units 1 and 2 2.3-127License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsNot included in the scope of license renewal are the nonsafety-related portions of the ReactorBuilding and Turbine Building ventilation systems since they do not perform or support systemintended 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. TheSafety-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 CFR54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform afunction 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 CFR50.63). The Safety-Related Ventilation System is not relied upon in any safety analyses orplant 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 theessential switchgear rooms is maintained.
- 2. Provide secondary containment boundary.
The SRV System contains isolation damperswhich close when secondary containment isolation is required.
- 3. Provide a pathway to the station vent stack for the potential release of fission productsfollowing certain abnormal operating conditions.
- 4. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The SRV System includes water filled components that have thepotential for spatial interactions (spray or leakage) with safety-related SSCs. 10 CFR54.4(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 ECCSequipment cooling ventilation, diesel generator room ventilation, and switchgear heat removalplant portions of the SRV license renewal system are relied upon to operate during a Fire SafeShutdown 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 theSRV System contain components that are environmentally qualified.
- 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 SRVSystem is relied upon to provide equipment cooling for the diesel generators and other safety-LaSalle County Station, Units 1 and 2 2.3-128License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsrelated equipment during SBO coping and recovery.
UFSAR References 6.2.37.3.79.4.29.4.49.4.515.7.1License Renewal Boundary DrawingsLR-LAS-M-92, Sheet 1LR-LAS-M-1 04, Sheet 1LR-LAS-M-129, Sheet 1LR-LAS-M-1 38, Sheet 1LR-LAS-M-149, Sheet 1LR-LAS-M-1444, Sheet 1LR-LAS-M-1445, Sheet ILR-LAS-M-1446, Sheet 1LR-LAS-M-1447, Sheet 1LR-LAS-M-1455, Sheets 1, 2, 3LR-LAS-M-1459, Sheets 1, 2LR-LAS-M-1460, Sheets 1, 2LR-LAS-M-1456, Sheets 1, 2, 3LR-LAS-M-1462, Sheets 1, 2LR-LAS-M-1463, Sheet 1LR-LAS-M-1464, Sheet 1LR-LAS-M-1465, Sheet 1LaSalle County Station, Units 1 and 2 2.3-129License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.3-22 Safety-Related Ventilation SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureDucting and Components Leakage BoundaryPressure BoundaryFlexible Connection Pressure BoundaryHeat Exchanger
-(CSCS Equipment Area Heat TransferCubicle Coolers)
FinsHeat Exchanger
-(CSCS Equipment Area Pressure BoundaryCubicle Coolers)
Shell Side Components Heat Exchanger
-(CSCS Equipment Area Heat TransferCubicle Coolers)
Tubes Pressure BoundaryPiping, piping components, and piping Pressure BoundaryelementsValve Body Pressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-22Safety-Related Ventilation SystemSummary of Aging Management Evaluation 0LaSalle County Station, Units 1 and 2License Renewal Application 2.3-130 Section 2 -Scoping and Screening Methodology and Results2.3.3.23 Standby Liquid Control SystemDescription The Standby Liquid Control (SLC) System is a standby system that is manually operated toshutdown the reactor if the normal reactivity control provisions become inoperative.
Thesystem is designed to bring the reactor to a shutdown condition at any time in core lifeindependent of control rod insertion capability.
The most severe requirement for which thesystem is designed is shutdown from a full power operating condition assuming completefailure of the Control Rod Drive (CRD) System to respond to a scram signal. The SLC Systemis in scope for license renewal.
- However, portions of the SLC System are not required toperform intended functions and are not in scope.The primary purpose of the SLC System is to shutdown the reactor independent of the CRDSystem. The SLC System accomplishes this purpose by injecting sodium pentaborate solution directly into the reactor vessel to absorb thermal neutrons.
The SLC Systemoperation is also credited during a Loss of Coolant Accident to maintain suppression poolwater 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 basisas well as the requirement for the reduction of risks from an Anticipated Transient WithoutScram (ATWS) as specified in 10 CFR 50.62 (ATWS Rule).For more detailed information see UFSAR Section 9.3.5.BoundaryThe SLC System license renewal scoping boundary begins at the SLC solution tank andcontinues through two positive displacement pumps, pulsation dampeners, pump discharge relief valves, and up to two parallel explosive actuated valves that open upon SLC Systemmanual initiation.
Also included in the system boundary are the electric heaters and airsparger within the SLC solution tank, heat tracing on piping that normally contains sodiumpentaborate
- solution, and the SLC test tank.All associated piping, components and instrumentation contained within the boundarydescribed 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 tothe location of the first seismic anchor, or to a point where there is no longer the potential forspatial interaction with safety-related equipment, whichever extends furthest.
This includesthe nonsafety-related portions of the system located within the Reactor Buildings.
Included inthis boundary are pressure-retaining components relied upon to preserve the leakageboundary intended function of the system. For more information, refer to the License RenewalBoundary Drawing for identification of the boundary, shown in red.Not included in the SLC System scoping boundary are the piping and components from thetwo parallel explosive actuated injection valves to the nozzle on the reactor pressure vesselwhich 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 tracethat is installed on the SLC System piping that normally contains SLC solution while theLaSalle County Station, Units 1 and 2 2.3-131License Renewal Application Section 2 -Scoping and Screening Methodology and Resultssystem 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. TheStandby 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 for10 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 thatdemonstrates compliance with the Commission's regulations for Anticipated Transient WithoutScram (10 CFR 50.62). The Standby Liquid Control System is not relied upon in any safetyanalyses or plant evaluations to perform a function that demonstrates compliance with theCommission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10CFR 50.49), and Station Blackout (10 CFR 50.63).Intended Functions
- 1. Introduce emergency negative reactivity to make the reactor subcritical.
The SLC Systemprovides backup capability for reactivity
- control, independent of normal reactivity controlprovisions in the nuclear reactor, to be able to shutdown the reactor if the normal control everbecomes inoperative.
- 2. Control and treat radioactive materials released to the secondary containment.
In the eventof a Loss of Coolant Accident, the SLC System is manually initiated from the control room topump sodium pentaborate into the reactor to maintain suppression pool pH at a level of 7.0 orhigher to minimize iodine releases from primary containment to the environment.
- 3. Resist nonsafety-related SSC failure that could prevent satisfactory accomplishment of asafety-related function.
The SLC System includes nonsafety-related fluid filled lines in theReactor 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 (10CFR 50.62). The SLC System injects sodium pentaborate solution into the reactor to achieveshutdown for mitigation of an Anticipated Transient Without Scram. 10 CFR 54.4(a)(3)
UFSAR References 9.3.57.4.2Table 3.2-1Table 6.2-2815.8License Renewal Boundary DrawingsLR-LAS-M-99, Sheet 1LR-LAS-M-145, Sheet 1LaSalle County Station, Units 1 and 2 2.3-132License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.3-23 Standby Liquid Control SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosurePiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryStructural Integrity Pump Casing (SLC Pump) Pressure BoundaryTanks (SLC Solution Tank) Pressure BoundaryTanks (SLC Test Tank) Leakage BoundaryValve Body Leakage BoundaryPressure BoundaryStructural Integrity The aging management review results for these components are provided in:Table 3.3.2-23Standby Liquid Control SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-133 Section 2 -Scoping and Screening Methodology and Results2.3.3.24 Suppression Pool Cleanup SystemDescription The intended function of the Suppression Pool Cleanup (SPC) System for license renewal is tomaintain leakage boundary integrity to preclude system interactions.
For this reason, thissystem's pressure-retaining components located in areas where there are potential spatialinteractions 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 inscope 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 thereactor well and the dryer-separator well in support of refueling operations.
The SPC Systemcan also be used to transfer suppression pool water to the main condenser.
The SPC Systemdoes 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 arenot in scope.The SPC System includes two pumps for each unit that can be aligned to circulate water fromthe suppression pool via Residual Heat Removal (RHR) System piping, through thecondensate 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 reactorwell or the dryer/separator pit via Fuel Pool Cooling and Storage System piping. The SPCSystem can also be aligned to provide a flowpath from the fuel pool cooling demineralizers tothe suppression pool to drain the reactor well or the dryer/separator pit. All SPC Systempiping interconnections with the RHR System, Feedwater System, Fuel Pool Cooling andStorage System and Condensate System are via removable piping spool pieces that arephysically removed with blank flanges installed during plant operation.
For more detailed information see UFSAR Section 9.2.11.BoundaryThe 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 locatedwithin the Reactor Buildings, Turbine Buildings, and Auxiliary Building.
Included in thisboundary are pressure-retaining components relied upon to preserve the leakage boundaryintended function of this system. For more information, refer to the License RenewalBoundary 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 noportions of the system are safety-related or relied upon to remain functional during andfollowing design basis events. The Suppression Pool Cleanup System meets 10 CFR54.4(a)(2) because failure of nonsafety-related portions of the system could preventsatisfactory 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 inLaSalle County Station, Units 1 and 2 2.3-134License Renewal Application Section 2 -Scoping and Screening Methodology and Resultssafety analyses or plant evaluations to perform a function that demonstrates compliance withthe 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 asafety-related function.
The SPC System contains nonsafety-related fluid filled lines in theReactor Buildings, Turbine Buildings, and Auxiliary Building which have potential spatialinteractions with safety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References 9.2.11License Renewal Boundary DrawingsLR-LAS-M-91, Sheets 1, 5LR-LAS-M-96, Sheets 3, 5LR-LAS-M-1 37, Sheets 1, 5LR-LAS-M-142, Sheets 3, 5Table 2.3.3-24 Suppression Pool Cleanup SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosurePiping, piping components, and piping Leakage BoundaryelementsPump Casing (Suppression Pool Cleanup Leakage BoundaryPump)Valve Body Leakage BoundaryThe aging management review results for these components are provided in:Table 3.3.2-24Suppression Pool Cleanup SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-135 Section 2 -Scoping and Screening Methodology and Results2.3.3.25 Traversing Incore Probe SystemDescription The Traversing Incore Probe (TIP) System is a standby system designed to calibrate the LocalPower Range Monitor (LPRM) Neutron Monitoring System detectors and update parameters that incorporate LPRM and TIP data into local power distribution calculations.
The TIP Systemincludes mechanical components that provide primary containment boundaries and supportinsertion 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 byutilizing five neutron monitoring detectors and positioning systems capable of moving the fluxdetectors to various locations in the core corresponding to the locations of the LPRMdetectors.
The moveable TIP detectors generate signals that are processed to indicate localpower 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 arenot in scope.The five TIP detectors are normally fully withdrawn from the core and stored outside of primarycontainment within a radiation shield chamber.
Each detector has a drive mechanism thatincludes a motor and drive reel assembly.
The detectors are attached to a drive and signalcable that that inserts and retracts the detector from the reactor core, driven by the drivemechanism.
Digital position indicators provide continuous indication of detector position andcore top and core bottom position for the selected location.
TIP guide tubing provides a guidefor the TIP detector throughout its travel from the shield chamber to the core top positioninside the reactor vessel. An indexing mechanism associated with each detector allows theselection of the core locations, including a core location common to all five detectors used forcross-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 theplant computer for determining local power. The power supply provides operating power tothe flux amplifier and to the detector.
A drive control unit in the main control room providescontrol 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 ballvalve located outside primary containment that perform a primary containment isolation function.
The ball valve is normally closed except when the detector is inserted.
The ballvalve can be manually controlled, but is normally opened and closed automatically, withinterlocks to open the valve when the detector leaves the shield, and to de-energize the drivemechanism should the ball valve not open after the insert operation is selected for the TIPdetector.
Upon receipt of a primary containment isolation signal, an inserted TIP detector isfully retracted and the ball valve automatically closes when the detector reaches the shieldchamber.
The explosive-actuated shear valve is used only to isolate the guide tube while adetector is inserted past the ball valve and power is lost to the drive mechanism or some otherfault 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, aguillotine 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 indexingmechanisms within containment.
The Compressed Air System provides a purge supply of dryLaSalle County Station, Units 1 and 2 2.3-136License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsair to the TIP drive mechanisms outside of containment.
The majority of the TIP System is notin 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.BoundaryThe TIP system license renewal scoping boundary begins outside containment at the TIP drivemechanisms and includes the detectors, drive reel assembly, and drive and signal cable. Theboundary 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 tubescontinue to the TIP indexing mechanisms, from which multiple TIP guide tubes continue to thereactor vessel. Included are the five-way connector (which provides a pathway for eachindexing mechanism to send a detector to the same location for calibration),
drive and signalcables, 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 forlicense renewal.
This includes shear valves, ball valves, and TIP guide tubing from the shearvalve assembly on each of the five TIP system trains, through the downstream ball valves tothe primary containment penetration.
Not included in the TIP System scoping boundary are the dry tubes inside the reactor vesselwhich 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 nitrogenpurge 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 airpurge supply to the TIP drive mechanisms which are evaluated with the Compressed AirSystem.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. TheTraversing Incore Probe System is not in scope under 10 CFR 54.4(a)(2) because failure ofnonsafety-related portions of the system would not prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
The Traversing Incore Probe System is not inscope under 10 CFR 54.4(a)(3) because it is not relied upon in safety analyses or plantevaluations 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 2.3-137License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsIntended Functions
- 1. Provide primary containment boundary.
The TIP System ball valves, shear valves, and TIPtubing between the shear valves and the primary containment penetrations form a primarycontainment boundary.
UFSAR References 7.7.6.4Table 3.2-1Table 6.2-21License Renewal Boundary DrawingsNone.Table 2.3.3-25Traversing Incore Probe SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionPiping, piping components, and piping Pressure BoundaryelementsValve Body Pressure BoundaryThe aging management review results for these components are provided in:Table 3.3.2-25Traversing Incore Probe SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-138 Section 2 -Scoping and Screening Methodology and Results2.3.4 STEAM AND POWER CONVERSION SYSTEMThe 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 2.3-139License Renewal Application Section 2 -Scoping and Screening Methodology and Results2.3.4.1 Condensate SystemDescription The Condensate System is a normally operating system designed to provide filtered anddemineralized condensate from the condenser hotwell to the Feedwater System. TheCondensate System also provides for the storage of clean and cycled condensate water foruse in normal plant operations and refueling operations.
The Condensate System consists ofthe following plant systems:
acid feed, caustic handling, clean condensate, condensate, condensate
- booster, condensate polishing, cycled condensate gland water, and cycledcondensate.
The Condensate System is in scope for license renewal.
- However, portions ofthe Condensate System are not required to perform intended functions and are not in scope.Acid Feed and Caustic Handling SystemsAcid and caustic are no longer used for resin regeneration at LaSalle.
The acid and causticstorage and day tanks have been abandoned in place. The tanks contents have beenremoved and the tanks neutralized and cleaned.
The tanks have been isolated, vented, anddrained.
Therefore, these tanks do not create the potential for spatial interaction and are notin scope for license renewal.Clean Condensate SystemThe purpose of the clean condensate system is to provide clean (non-contaminated) reactorgrade water to various plant systems.
The clean condensate system accomplishes this bydistributing clean condensate from the clean condensate storage tank to plant equipment andwater service connections located in the Turbine Building, Radwaste
- Building, Offgas Building, Service Building, Auxiliary
- Building, Reactor Building, Diesel Generator
- Building, and otherareas in the plant.Clean condensate is also provided to water service connections inside the primarycontainment for use during reactor shutdown and outages.
The clean condensate supply lineswhich penetrate the primary containment are equipped with manually operated primarycontainment isolation valves.Condensate and Condensate Booster SystemThe purpose of the condensate and condensate booster systems is to provide a means oftransferring water from the condenser hotwell to the suction of the reactor feed pumps. Thecondensate and condensate booster systems also provide cooling for the steam jet airejectors, steam packing exhauster, offgas condenser, and low pressure heaters.
Thecondensate and condensate booster systems accomplish this by taking suction from thecondenser hotwell using the condensate pumps, delivering the condensate through the steamjet air ejector condensers, gland steam packing exhauster condensers, off-gas condensers, and condensate polishing system to the condensate booster pumps, which discharge throughthe low-pressure feedwater heaters to the reactor feed pumps.Condensate Polishing SystemThe purpose of the condensate polishing system is to remove dissolved and suspended solidsLaSalle County Station, Units 1 and 2 2.3-140License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsfrom the condensate in order to maintain high quality reactor feedwater.
The condensate polishing system accomplishes this by processing condensate through prefilters andcondensate demineralizers.
Cycled Condensate Gland Water SystemThe 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 fromthe cycled condensate gland seal head tank to each pump gland.Cycled Condensate SystemThe purpose of the cycled condensate system is to provide the necessary source ofcondensate (potentially contaminated) to various systems in the plant and also to provideadditional water for on-line and refueling activities.
The cycled condensate systemaccomplishes this through the distribution of condensate from the cycled condensate storagetanks to various systems throughout the plant.The cycled condensate storage tanks are credited for Fire Safe Shutdown as a suction sourcefor 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, and10.4.7.BoundaryThe Condensate System license renewal scoping boundary includes that portion of the systemnecessary to achieve primary containment isolation.
The clean condensate supply lines whichpenetrate the primary containment are equipped with manually operated primary containment isolation valves which are locked closed during reactor operations.
In addition, each line isequipped with a spool piece which is removed and respective blank flanges installed duringreactor operations.
The Condensate System license renewal scoping boundary also includes the cycledcondensate storage tank and attached piping and valves necessary to maintain a usablesupply 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 toautomatically swap the RCIC pump suction to the suppression pool. This instrumentation isevaluated 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 thepotential for spatial interaction with safety-related equipment, whichever extends furthest.
Thisincludes the nonsafety-related portions of the system located within the Primary Containment, Auxiliary
- Building, Reactor Building, Diesel Generator
- Building, Offgas Building, and TurbineBuilding.
Included in this boundary are pressure-retaining components relied upon to preserveLaSalle County Station, Units 1 and 2 2.3-141License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsthe 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 inred.Reason for Scope Determination The Condensate System meets 10 CFR 54.4(a)(1) because it is a safety-related system that isrelied 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 systemcould prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
TheCondensate System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safetyanalyses and plant evaluations to perform a function that demonstrates compliance with theCommission's regulations for Fire Protection (10 CFR 50.48). The Condensate System is notrelied 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 whichpenetrate 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 asafety-related function.
The Condensate System contains nonsafety-related fluid filled lines inthe Primary Containment, Auxiliary
- Building, Reactor Building, Diesel Generator
- Building, Offgas Building, and Turbine Building which provide structural support or have potential spatialinteractions 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 cycledcondensate storage tanks are credited for Fire Safe Shutdown as a suction source for theReactor Core Isolation Cooling System (RCIC) for both the basic and alternate shutdownmethods.
UFSAR References 1.2.2.3.10 1.2.3.1.5 3.1.2.4.6 Table 3.2-1Table 3.8-14.6.1.1.2.4.2.1 5.4.6.36.1.1.26.2.4.2.2 Table 6.2-217.4.1.2.2 9.1.3.2.3.6 9.2.4.1.2 LaSalle County Station, Units 1 and 2 2.3-142License Renewal Application Section 2 -Scoping and Screening Methodology and Results9.2.710.4.610.4.711.2.215.9.3Appendix JLicense Renewal Boundary DrawingsLR-LAS-M-74, Sheet 1LR-LAS-M-75, Sheets 1, 2, 3, 4LR-LAS-M-77, Sheet 1LR-LAS-M-1 13, Sheet 1LR-LAS-M-127, Sheet ILR-LAS-M-86, Sheet 1LR-LAS-M-89, Sheet 1LR-LAS-M-90, Sheet 1LR-LAS-M-96, Sheets 1, 2, 3LR-LAS-M-97, Sheets 1, 5LR-LAS-M-98, Sheet 1LR-LAS-M-99, Sheet 1LR-LAS-M-1 00, Sheet 1LR-LAS-M-102, Sheets 1, 10LR-LAS-M-103, Sheets 15, 16, 19, 27LR-LAS-M-105, Sheet 1LR-LAS-M-115, Sheets 1, 12,13LR-LAS-M-129, Sheet 3LR-LAS-M-1 30, Sheets 1, 2LR-LAS-M-133, Sheet 1LR-LAS-M-136, Sheet 1LR-LAS-M-1 42, Sheets 1, 2, 3LR-LAS-M-143, Sheets 1, 5LR-LAS-M-144, Sheet 1LR-LAS-M-145, Sheet 1LR-LAS-M-146, Sheet 1LR-LAS-M-159, Sheet 1LaSalle County Station, Units 1 and 2 2.3-143License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.3.4-1Condensate SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosurePiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryTanks (Cycled Condensate Gland Seal Leakage BoundaryHead Tank)Tanks (Cycled Condensate Storage Pressure BoundaryTank)Valve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.4.2-1Condensate SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-14 Section 2 -Scoping and Screening Methodology and Results2.3.4.2 Condenser and Air Removal SystemDescription The Condenser and Air Removal System is a normally operating system designed to provide aheat sink for exhaust steam from the main turbine and reactor feed pump turbines duringnormal operation.
The system also removes noncondensible gases from the condenser andexhausts them to the gaseous radwaste system. The system has a function to providepassive hold-up for leakage from the main steam isolation valves following an accident andisolate the main condenser off-gas outlet lines upon detection of high radiation in the mainsteam lines when the mechanical vacuum pump is operating.
The Condenser and AirRemoval System consists of the following plant systems:
main condenser and maincondenser evacuation system. The Condenser and Air Removal System is in scope forlicense renewal.
- However, portions of the Condenser and Air Removal System are notrequired 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, turbinebypass steam, and other turbine cycle flows, and to receive and collect flows for return to thereactor.
The main condenser accomplishes these functions by passing circulating waterthrough the condenser tubes to condense the steam from turbine exhausts and other sources,removing noncondensible gases during normal operation and plant startup, and providing avolume for collection and storage of condensate to be returned to the reactor.
Attached to themain condenser is safety-related and environmentally qualified instrumentation to sense lossof condenser vacuum and initiate closure of the MSIVs and main steam line drains. Thecondenser also provides passive hold-up and plateout of radioactive material that leaksthrough the main steam isolation valves following a LOCA by receiving input from drains forthe main steam lines.Condenser Evacuation SystemThe purpose of the condenser evacuation system is to maintain a vacuum in the condenser forthe three low pressure turbine exhausts.
The system accomplishes this function by removingthe 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 maincondenser off-gas outlet isolation valves and manual trip of the mechanical vacuum pumpwhen high radiation is detected in the main steam lines when the mechanical vacuum pump isin 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.BoundaryThe license renewal scoping boundary of the Condenser and Air Removal System includesthe main condenser and the off-gas air ejector supply piping from the condenser up to andincluding the main condenser off-gas outlet isolation valves. The scoping boundary alsoincludes the safety-related main condenser vacuum instrumentation that initiates isolation ofLaSalle County Station, Units 1 and 2 2.3-145License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsthe 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 ofthese components, shown in green.Not included in the Condenser and Air Removal System scoping boundary are the main steamline drains that route MSIV leakage from the steam lines to the condenser for holdup andplateout which are evaluated with the Main Steam System.Not included in the Condenser and Air Removal System scoping boundary are the lowpressure turbine exhaust hoods, which form a portion of the post-accident holdup boundarywith 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 basisevents. 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 AirRemoval System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safetyanalyses and plant evaluations to perform a function that demonstrates compliance with theCommission'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 toperform a function that demonstrates compliance with the Commission's regulations for FireProtection (10 CFR 50.48), Anticipated Transient Without Scram (10 CFR 50.62), and StationBlackout (10 CFR 50.63).Intended Functions
- 1. Sense process conditions and generate signals for reactor trip or engineered safetyfeatures actuation.
Main condenser low vacuum instrumentation initiates MSIV closure andmain steam line drain isolation.
- 2. Post-accident containment holdup and plate out of MSIV bypass leakage.
The maincondenser is credited for holdup and plateout of MSIV leakage following a LOCA. 10 CFR54.4(a)(2)
- 3. Minimize the release of radioactive material to the environment.
Manual isolation of themain condenser off-gas outlet valves and manual tripping of the mechanical vacuum pump iscredited following a control rod drop accident to minimize radioactive releases.
- 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 switchesto sense loss of condenser vacuum and initiate closure of the MSIVs and main steam linedrains. 10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2 2.3-146License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsUFSAR References 1.2.3.1.3 3.26.87.3.2.2.3.12 10.4.110.4.215.4.915.6.5.515.7.1License Renewal Boundary DrawingsLR-LAS-M-56, Sheets 2, 3, 4LR-LAS-M-1 17, Sheets 2, 3, 4LR-LAS-M-80, Sheet 2LR-LAS-M-128, Sheet 2LR-LAS-M-88, Sheet 1LR-LAS-M-135, Sheet 1Table 2.3.4-2Condenser and Air Removal SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosureHeat Exchanger
Shell Containment, Holdup and PlateoutSide Components Piping, piping components, and piping Pressure BoundaryelementsValve Body Pressure BoundaryThe aging management review results for these components are provided in:Table 3.4.2-2Condenser and Air Removal SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-147 Section 2 -Scoping and Screening Methodology and Results2.3.4.3 Feedwater SystemDescription 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 thefollowing plant systems:
feedwater, feedwater heaters and drains, feedwater miscellaneous drains, feedwater
- control, zinc injection,
TheFeedwater 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 takinghigh quality, preheated feedwater from the feedwater heaters and injecting the feedwater intothe 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 primarycontainment isolation check valves (evaluated with the Reactor Coolant Pressure BoundarySystem).
The check valves provide for immediate isolation should a break occur in thefeedwater line outside of the primary containment.
The motor-operated valve provides forlong-term leakage protection and isolation capability.
Feedwater Heaters and Drains/Feedwater Miscellaneous DrainsThe 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 drainsaccomplish this by using cascading drains and extraction steam to heat reactor feedwater through the use of feedwater heaters.Feedwater ControlThe 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 levelsover the entire power range of the reactor.
The feedwater control system accomplishes this byusing a three-element controller to regulate the feedwater flow. The controller uses mainsteam flow rate, feedwater flow rate, and reactor water level. The feedwater control signalmaintains a predetermined level by varying the speed of the turbine driven feed pumps and/orby varying the flow control valve position on the discharge of the constant speed motor drivenfeed pump. Operation in a single element control that utilizes reactor water level only is alsoavailable.
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 therecirculation piping. The zinc injection system accomplishes this by injecting a solution ofdepleted zinc oxide into the suction header of the reactor feed pumps using a zinc injection skid.LaSalle County Station, Units 1 and 2 2.3-148License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsHydrogen SystemThe purpose of the hydrogen system is to provide a source of hydrogen for hydrogen waterchemistry.
The hydrogen system accomplishes this by providing regulated hydrogen from acryogenic hydrogen storage facility to the hydrogen water chemistry injection system.Hydrogen Water Chemistry SystemThe purpose of the hydrogen water chemistry system is to reduce rates of intergranular stresscorrosion cracking (IGSCC) in recirculation piping and reactor vessel internals.
The hydrogenwater chemistry system accomplishes this by injecting hydrogen into the condensate boosterpump suction header (evaluated with the Condensate System) to suppress the formation ofradiolytic oxygen in the reactor coolant.For more detailed information see UFSAR Sections 5.4.15, 6.2, 7.7.4, and 10.4.7BoundaryThe Feedwater System license renewal scoping boundary includes that portion of the systemnecessary to achieve primary containment isolation and maintain reactor coolant systempressure boundary.
The feedwater primary containment penetrations are provided with aseries arrangement of three isolation valves. The scoping boundary begins with the outerfeedwater inlet outboard motor-operated containment isolation valve and continues up to, butdoes 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 thepotential for spatial interaction with safety-related equipment, whichever extends furthest.
Thisincludes 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 ofthe system. For more information, refer to the License Renewal Boundary Drawing foridentification 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 ofthe system are either gas filled or liquid filled, are not located in areas where there arepotential spatial interactions with components performing safety-related functions, and do notperform 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 2.3-149License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsReason for Scope Determination The Feedwater System meets 10 CFR 54.4(a)(1) because it is a safety-related system that isrelied 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 systemcould prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
TheFeedwater System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safetyanalyses and plant evaluations to perform a function that demonstrates compliance with theCommission'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 thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR50.63).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 leakagecontrol 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 asafety-related function.
The Feedwater System contains nonsafety-related fluid filled lines inthe Reactor Building, Auxiliary
- Building, and Turbine Building which provide structural supportor 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 includecomponents that are environmentally qualified.
UFSAR References 1.2.3.1.5 1.2.3.3.2 Table 3.2-15.4.95.4.156.2.4.2.1 Table 6.2-21Table 6.2-287.7.49.5.1.2.2 10.3.610.4.710.4.8LaSalle County Station, Units 1 and 2 2.3-150License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsAppendix CAppendix J. 1License Renewal Boundary Drawingqs LR-LAS-M-57, Sheet 1LR-LAS-M-1 18, Sheet 1Table 2.3.4-3Feedwater SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosurePiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryValve Body Leakage BoundaryPressure BoundaryThe aging management review results for these components are provided in:Table 3.4.2-3Feedwater SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-151 Section 2 -Scoping and Screening Methodology and Results2.3.4.4 Main Steam SystemDescription The Main Steam System is a normally operating system that is designed to convey steamproduced in the reactor to the main turbine and direct steam from the main steam relief valvedischarge to the suppression pool. The Main Steam System consists of the following plantsystems:
main steam system and MSIV leakage control system. The Main Steam Systemincludes the MSIV Isolated Condenser Leakage Treatment Method components that controland minimize the release of fission products which could leak through the closed main steamisolation 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 inscope.The purpose of the Main Steam System is to provide the high pressure steam produced by thereactor to the main turbine during normal plant operation.
It accomplishes this function via thefour main steam lines between the outboard primary containment isolation valves, the mainturbine stop valves, and the main turbine bypass valves.The purpose of the Main Steam System is to also provide the capability to bypass steamaround the main turbine.
It accomplishes this by operation of main turbine bypass valves thatdischarge to the main condenser.
The purpose of the Main Steam System is also to providesteam 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 controlvalves at each of the steam users.The Main Steam System also includes the discharge piping from the main steam relief valvesinside the primary containment.
The purpose of this portion of the Main Steam System is toroute the MSRV discharge to the suppression pool to minimize the thermal effects of openingthe relief valves. It accomplishes this function by routing the steam from the MSRV into thesuppression pool, below the normal water level, to a quencher to facilitate condensation of thesteam. Several of the discharge lines are no longer used for MSRV steam discharge and areinstalled in the primary containment and capped in the drywell to prevent bypass leakagebetween the drywell and suppression pool air space.The purpose of the Main Steam System is also to contain main steam isolation valve leakagefollowing a LOCA. It accomplishes this function by providing a volume within the largediameter main steam piping for plateout and holdup and a flow path through main steam drainlines to the main condenser for additional plateout and holdup in the condenser.
The MainSteam System includes the station main steam isolation valve leakage control system which isabandoned in place for Unit 1 and deleted for Unit 2.Portions of the Main Steam System are located in areas where there are potential spatialinteractions with safety-related equipment in the Reactor Building.
The intended function ofthese portions of the Main Steam System is to resist nonsafety-related SSC failure that couldprevent 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 2.3-152License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsBoundaryThe license renewal scoping boundary of the Main Steam System includes the main steamlines from the outboard containment isolation valves up to and including the main turbine stopvalves, main turbine bypass valves, and isolation valves to steam users.The license renewal scoping boundary of the Main Steam System also includesinstrumentation that is part of the plant reactor protection system, including turbine stop valveclosure, 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 theMSRVs, is not included in the Main Steam System and is evaluated with the Reactor CoolantPressure Boundary System for license renewal.The main turbine control valves and downstream piping are also not included in the scope ofthe Main Steam System and are evaluated with the Main Turbine and Auxiliaries System forlicense 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 MSRVdischarge piping that is capped in the drywell and no longer used.The license renewal scoping boundary of the Main Steam System includes the MSIV isolatedcondenser leakage treatment method. This includes nonsafety-related drain lines from themain steam lines outside the primary containment to the main condenser.
The maincondenser is not included in the scope of the Main Steam System and is evaluated with theCondenser and Air Removal System for license renewal.The plant MSIV leakage control system is part of the Main Steam System. This system isdeleted for Unit 2 and abandoned in place for Unit 1. This portion of the Main Steam Systemfor 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 licenserenewal.
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 thoseportions 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 pointwhere 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 locatedin the Reactor Building.
Included in this boundary are pressure-retaining components that arerelied 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 thisboundary, shown in red.LaSalle County Station, Units 1 and 2 2.3-153License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsReason for Scope Determination The Main Steam System meets 10 CFR 54.4(a)(1) because it is a safety-related system that isrelied upon to remain functional during and following design basis events. The Main SteamSystem meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the systemcould prevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
TheMain Steam System also meets 10 CFR 54.4(a)(3) because it is relied upon in the safetyanalyses and plant evaluations to perform a function that demonstrates compliance with theCommission's regulations for Fire Protection (10 CFR 50.48), Environmental Qualification (10CFR 50.49), and Station Blackout (10 CFR 50.63). The Main Steam System is not relied uponin 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 safetyfeatures actuation.
The Main Steam System contains reactor protection systeminstrumentation 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 whichprevents bypass leakage between the drywell and suppression pool and routes MSRVdischarge to the suppression pool. 10 CFR 54.4(a)(1)
- 3. Post-accident containment holdup and plateout of MSIV bypass leakage.
The Main SteamSystem contains leakage from MSIVs and routes the leakage to the main condenser forholdup 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 asafety-related function.
The Main Steam System includes nonsafety-related SSCs with thepotential for spatial and structural interaction with safety-related SSCs in the Reactor Building.
- 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 MainSteam System includes the MSRV discharge piping which is used to reduce and controlreactor pressure to support Fire Safe Shutdown.
- 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 therequirements 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 MainSteam System includes the MSRV discharge lines which are used during station blackout toreduce and control reactor pressure.
LaSalle County Station, Units 1 and 2 2.3-154License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsUFSAR References 1.2.3.1.2 1.2.2.4.5 3.25.4.96.76.87.210.315.2.615.6.5.515.9.3License Renewal Boundary DrawinasLR-LAS-M-55, Sheets 1, 2, 3, 7LR-LAS-M-92, Sheet 1LR-LAS-M-116, Sheets 1, 2, 3, 7LR-LAS-M-138, Sheet 1Table 2.3.4-4Main Steam SystemComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Mechanical ClosurePiping, piping components, and piping Leakage Boundaryelements Pressure BoundaryValve Body Pressure BoundaryThe aging management review results for these components are provided in:Table 3.4.2-4Main Steam SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-155 Section 2 -Scoping and Screening Methodology and Results2.3.4.5 Main Turbine and Auxiliaries SystemDescription The Main Turbine and Auxiliaries System is a normally operating system designed to convertthe 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 toperform intended functions and are not in scope.Main TurbineThe main turbine consists of one double-flow high pressure and three double-flow lowpressure turbines on the same shaft. The turbine system also includes two (2) horizontal moisture separator reheaters and associated piping running from the main turbine controlvalves and ending at the low pressure turbine inlets. The purpose of the main turbine is toconvert 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 holdupvolume in conjunction with the main condenser following an accident for any leakage throughthe Main Steam Isolation Valves (MSIV). It accomplishes the first purpose by passing mainsteam through the turbine blade stages to turn the turbine rotors which are coupled directly tothe generator shaft. It accomplishes the second purpose using the exhaust hoods of the lowpressure turbines which are mounted on the top of the main condenser to form the boundaryfor holdup of MSIV leakage.Gland Seal SteamThe purpose of the sealing steam system is to provide a source of clean (low levelradioactivity) steam to the shaft seals for the main high and low pressure turbine rotors, shaftseals for the reactor feed pump turbine rotors, and large main steam valves including the mainturbine stop valves, main turbine control valves, main turbine bypass valves, combinedintermediate 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 sealsteam keeps radioactive steam inside the sealed components while keeping outside air frompenetrating the seals.Turbine Lube OilThe purpose of the lube oil system is to provide clean pressurized oil to the main turbine thrustbearing, main turbine journal bearings, lift pump suction, hydrogen seal oil and reactor feedpump turbine control system and bearings.
It accomplishes this by purifying the lube oil andproviding the pressurized oil to the selected users and returning it to the purification equipment.
Electro-Hydraulic Control (EHC) systemThe purpose of the EHC system is to provide hydraulic fluid for control of main steam headerpressure, turbine speed, and steam flow during normal operating and transient conditions.
Itaccomplishes this by positioning the main steam stop valves, control valves, combinedLaSalle County Station, Units 1 and 2 2.3-156License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsintermediate valves, and bypass valves.Turbine TestThe purpose of turbine test system is to provide various system connection points such thatthermal performance testing can be performed on the turbine assembly.
It accomplishes thisby installed instrumentation connection points to monitor process variables in the Main Turbineand Auxiliaries System. This system is only installed on Unit 2 and is used to perform ASMEperformance testing on newly installed turbine components.
For more detailed information, see UFSAR Section 10.2.BoundaryThe Main Turbine and Auxiliaries System scoping evaluation boundary begins at the outletside of the turbine main stop valves. The scoping boundary continues through the highpressure
- turbine, the moisture separator reheaters, and then the low pressure turbines.
Itincludes the piping from the outlet of the turbine bypass valves and ends at the inlets to themain condenser.
The scoping boundary also includes the EHC system components whichbegin at the EHC reservoir.
The scoping boundary continues through the system supplypiping, 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.
Thescoping boundary also includes the components associated with the turbine oil system. Thescoping 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 endswhere the system return piping enters the main turbine oil reservoir.
The gland steam systembegins at the inlet to the steam seal evaporator, continues through system piping to turbineshaft seals, the steam packing exhauster, and ends at the outlet pipe connecting to the mainstack. The system boundary also includes sealing steam supplies to various main turbine andfeed pump turbine valve stem seals and ends where the piping system connects to thecondenser.
All associated piping, components and instrumentation, contained within theflowpath 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. Thisincludes 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. Formore information, refer to the License Renewal Boundary Drawings for the identification of thisboundary shown in green.Not included in the Main Turbine and Auxiliaries System scoping boundary is theinstrumentation within the Main Turbine and Auxiliaries System boundary associated with theReactor 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 noportions of the system are safety-related or relied upon to remain functional during andfollowing design basis events. The Main Turbine and Auxiliaries System meets 10 CFRLaSalle County Station, Units 1 and 2 2.3-157License Renewal Application Section 2 -Scoping and Screening Methodology and Results54.4(a)(2) because failure of nonsafety-related portions of the system could preventsatisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The Main Turbineand Auxiliaries System is not in scope under 10 CFR 54.4(a)(3) because it is not relied upon insafety analyses or plant evaluations to perform a function that demonstrates compliance withthe 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 takenfor holdup and plateout in the main condenser for MSIV leakage.
The low pressure turbineexhaust hoods form part of this holdup boundary with the main condenser.
UFSAR References 6.87.7.510.210.4.310.4.4License Renewal Boundary DrawinqsLR-LAS-M-55, Sheet 4LR-LAS-M-1 16, Sheet 4Table 2.3.4-5Main Turbine and Auxiliaries SystemComponents Subject to Aging Management ReviewComponent TypeIntended FunctionTurbine Casings (Low Pressure Turbine Containment, Holdup and PlateoutExhaust Hoods)The aging management review results for these components are provided in:Table 3.4.2-5Main Turbine and Auxiliaries SystemSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application 2.3-158 Section 2 -Scoping and Screening Methodology and Results2.4 SCOPING AND SCREENING RESULTS:
STRUCTURES AND COMPONENT SUPPORTSThe 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 2License Renewal Application Page 2.4-1 Section 2 -Scoping and Screening Methodology and Results2.4.1 Auxiliary BuildingDescription The Auxiliary Building is a Seismic Category I safety-related multi-story structure.
Portions ofthe 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 ReactorBuilding, and east of the Turbine Building.
The Diesel Generator Buildings are located northand south of the Auxiliary Building.
The shear walls for the Reactor Building, Auxiliary
- Building, Turbine Building, Radwaste
- Building, Diesel Generator Buildings, and Off-gas FilterBuilding are interconnected.
These shear walls have been considered to act together to resistlateral loads applied to these buildings.
Therefore, the shear walls for these buildings areSeismic Category I.The Auxiliary Building is comprised of a reinforced concrete shear wall structure supported ona reinforced concrete mat foundation on soil which is continuous with the mat foundation underthe reactor,
- turbine, and diesel generator buildings.
Above the mat the Auxiliary Building isstructurally 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 gradeare steel framing with concrete slabs. Exterior walls are reinforced concrete.
Interiorpartitioning 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 singlepoint 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 asteel structure and it is designed to withstand postulated seismic and tornado conditions.
Theroof also supports exhaust vent lines leading to the vent stack.The Auxiliary Building houses the main steam tunnel, Turbine Building access elevator, ventstack, HVAC equipment, laboratories, electrical equipment, 4160-volt and 6900-volt switchgear, 480-volt substation, battery rooms, instrument room, computer room, control roomand offices, and facilities for shift operating personnel.
The Auxiliary Building is divided into compartments designed to protect Unit 1 and Unit 2safety-related systems and components.
Among these compartments are the control roomenvelope, switchgear compartments, and miscellaneous equipment compartments.
The control room envelope consists of control room and auxiliary electric equipment rooms forboth 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 ofthe 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 designbasis accident for the duration of the accident.
The control room is protected by a minimum of2 feet of concrete shielding.
The outside air for the control room supply is brought in throughindependent and separate missile-protected roof openings.
The control room is isolated fromLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-2 Section 2 -Scoping and Screening Methodology and Resultsthe Turbine Building through leak tight double doors.The purpose of the Auxiliary Building is to provide structural
- support, shelter and protection tosystems, structures and components (SSCs) along with personnel housed within the buildingduring normal plant operations, and during and following postulated design basis accidents and extreme environmental conditions.
The building also contains the control room, which isthe 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 roomenvelope in conjunction with the ventilation system provides a habitable environment for plantoperators so that the plant can be safely operated and shutdown under design basis accidentconditions.
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, masonrywalls, metal components such as the control room ceiling, metal decking, pipe whip restraints, reinforced concrete elements of the building, steel components, steel elements (including theventilation stack), and structural bolting.Refer to the "Components Subject to Aging Management Review" table below for a completelist of components included in the boundary of the Auxiliary Building.
Included within the boundary of the Auxiliary Building and determined not to be within thescope 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 areprovided to facilitate miscellaneous operational support.
These components and structures donot perform a license renewal intended
- function, such that their failure will not preventsatisfactory 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 withthe Fire Protection System. Component
- supports, including their respective
- bolting, areevaluated 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 areevaluated with their respective mechanical and electrical license renewal system or commodity group.For more detailed information, see UFSAR Sections 3.8.4 and 3.8.5LaSalle County Station, Units 1 and 2 Page 2.4-3License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsReason for Scope Determination The Auxiliary Building meets 10 CFR 54.4(a)(1) because it is a safety-related structure that isrelied 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 thestructure could prevent satisfactory accomplishment of function(s) identified for 10 CFR54.4(a)(1).
The Auxiliary Building also meets 10 CFR 54.4(a)(3) because it is relied upon inthe 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), andStation Blackout (10 CFR 50.63).Intended Functions
- 1. Provide physical
- support, shelter, and protection for safety-related
- systems, structures, andcomponents (SSCs). 10 CFR 54.4(a)(1)
- 2. Provide centralized area for control and monitoring of nuclear safety-related equipment.
- 3. Provides for the discharge of treated gaseous waste to meet the requirements of 10 CFR50.67 or 10 CFR 100. 10 CFR 54.4(a)(1)
- 4. Controls the potential release of fission products to the external environment so that offsiteconsequences 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 offunction(s) identified for 10 CFR 54.4(a)(1).
- 6. Provides structural support or restraint to SSCs not in scope of license renewal to preventinteraction 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 CFR54.4(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 (10CFR 50.62). 10 CFR 54.4(a)(3)
- 10. Provides physical
- support, shelter, and protection for systems, structures, andcomponents relied upon in safety analyses or plant evaluations to perform a function thatLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-4 Section 2 -Scoping and Screening Methodology and Resultsdemonstrates compliance with the Commission's regulations for Station Blackout (10 CFR50.63). 10 CFR 54.4(a)(3)
UFSAR References 1.11.2.2.2Table 3.2-13.5.2.2Figure 3.5-43.8.1.4.2 3.8.43.8.4.13.8.4.1.2 3.8.4.1.4 3.8.4.1.6.1 3.8.53.8.5.1.1 6.4.29.5.1.2.2 12.3.1.5License Renewal Boundary DrawinasLR-M-3Table 2.4-1Auxiliary BuildingComponents Subject to Aging Management ReviewComponent Type Intended FunctionBlowout Panels Pressure ReliefBolting (Structural)
Structural SupportConcrete Anchors Structural SupportConcrete Curbs Direct FlowConcrete Embedments Structural SupportConcrete:
Above-grade Exterior Flood Barrier(accessible areas) Missile BarrierShelter, Protection Shielding Structural Pressure BarrierStructural SupportConcrete:
Above-grade Exterior Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Shielding Structural Pressure BarrierStructural SupportConcrete:
Below-grade Exterior Flood BarrierLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-5 Section 2 -Scoping and Screening Methodology and ResultsComponent Type Intended Function(accessible areas) Missile BarrierShelter, Protection Shielding Structural Pressure BarrierStructural SupportConcrete:
Below-grade Exterior Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Structural Pressure BarrierStructural SupportConcrete:
Foundation, Subfoundation Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Structural SupportComponent Type Intended FunctionConcrete:
Interior Flood BarrierMissile BarrierShelter, Protection Shielding Structural Pressure BarrierStructural SupportEquipment Supports and Foundations Structural SupportHatches/Plugs Flood BarrierMissile BarrierShelter, Protection Shielding Structural SupportMasonry Walls: Interior
- Shelter, Protection Shielding Structural SupportMetal Components (Including Control Structural SupportRoom Ceiling)Metal Decking Structural SupportPipe Whip Restraints Pipe Whip Restraint Steel Components:
Structural Steel Structural SupportSteel Elements (Ventilation Stack) Gaseous Release PathStructural SupportSteel Elements:
Liner, Liner Anchors, Water Retaining BoundaryIntegral Attachments (accessible areas -Sump)The aging management review results for these components are provided in:Table 3.5.2-1Auxiliary BuildingSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-6 Section 2 -Scoping and Screening Methodology and Results2.4.2 Component Supports Commodity GroupDescription 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 includeseismic anchors or restraints, support frames, constant and variable spring hangers, rodhangers, guides, stops, straps, and clamps. Specialty components include snubbers, andsliding surfaces.
The commodity group is comprised of the following supports:
-Supports for ASME Class 1, 2, and 3, and MC piping and components, including reactorvessel anchorage.
-Supports for cable trays, conduit, HVAC ducts, tube track, instrument tubing and non-ASMEpiping and components.
-Supports for emergency diesel generators, HVAC system components and othermiscellaneous mechanical equipment.
-Supports for platforms, spray shields, and other miscellaneous structures.
-Supports for racks, panels, cabinets and enclosures for electrical equipment andinstrumentation.
The purpose of a support is to transfer loads such as gravity,
- thermal, seismic, and otherlateral and vertical loads imposed on, or by the system, structure, or component to thesupporting building structural element or foundation.
Sliding surfaces when incorporated intothe support design permit release of lateral forces but are relied upon to provide verticalsupport.
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 andinstrumentation
- systems, components, and structures that are within the scope of licenserenewal.
The group also includes supports for SSCs, which are not within the scope of licenserenewal, 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 andbolted connections, sliding surfaces and bearings, concrete
- anchors, concrete embedments, and grout.Included in the boundary of the Component Supports Commodity Group for each of thesupports 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 tobuilding 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 2License Renewal Application Page 2.4-7 Section 2 -Scoping and Screening Methodology and Resultsreview 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 completelist of components included in the boundary of the Component Supports Commodity Group.Not included in the boundary of the Component Supports Commodity Group are concreteequipment foundations, pipe whip restraints,
- columns, concrete embedments, and concreteanchors used for components other than supports listed herein. These commodities areevaluated 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 basisevents. The Component Supports Commodity Group meets 10 CFR 54.4(a)(2) becausefailure 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 Groupalso meets 10 CFR 54.4(a)(3) because supports are relied upon in the safety analyses or plantevaluations 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 preventinteraction with safety-related SSCs. 10 CFR 54.4(a)(2)
UFSAR References Table 3.2-13.6.2.3.2 3.6.2.3.2.6 3.6.2.3.3 3.7.3.33.9.23.9.33.108.3.1Appendix G.2Appendix J.3License Renewal Boundary DrawingsLR-M-3LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-8 Section 2 -Scoping and Screening Methodology and ResultsTable 2.4-2Component Supports Commodity GroupComponents Subject to Aging Management ReviewComponent Type Intended FunctionSupports for ASME Class 1 piping and Structural Supportcomponents (Building concrete atlocations of expansion and groutedanchors; grout pads for support baseplates)Supports for ASME Class 1 piping and Structural Supportcomponents (Constant and variable loadspring hangers; guides; stops)Supports for ASME Class 1 piping and Structural Supportcomponents (Support members; welds;bolted connections; support anchorage tobuilding structure)
Supports for ASME Class 2 and 3 piping Structural Supportand components (Building concrete atlocation of expansion and groutedanchors; grout pads for support baseplates)Supports for ASME Class 2 and 3 piping Structural Supportand components (Constant and variableload spring hangers; guides; stops)Supports for ASME Class MC Structural Supportcomponents (Building concrete at locationof expansion and grouted anchors; groutpads for support base plates)Supports for ASME Class 2 and 3 piping Structural Supportand components (Support members;welds; bolted connections; supportanchorage to building structure)
Supports for ASME Class MC Structural Supportcomponents (Constant and variable loadspring hangers; guides; stops)Supports for ASME Class MC Structural Supportcomponents (Support members; welds;bolted connections; support anchorage tobuilding structure)
Supports for Cable Trays, Conduit, HVAC Structural SupportDucts, Tube Track, Instrument Tubing,Non-ASME Piping and Components (Support members; welds; boltedconnections; support anchorage tobuilding structure)
LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-9 Section 2 -Scoping and Screening Methodology and ResultsComponent TypeIntended FunctionSupports for Cable Trays, Conduit, HVACDucts, Tube Track, Instrument Tubing,Non-ASME Piping and Components (Building concrete at location ofexpansion and grouted anchors; groutpads for support base plates)Structural SupportSupports for Emergency DieselGenerator, HVAC System Components, and Other Misc. Mechanical Equipment (Building concrete at location ofexpansion and grouted anchors; groutpads for support base plates)Structural SupportSupports for Emergency Diesel Structural SupportGenerator, HVAC System Components, and Other Misc. Mechanical Equipment (Support members; welds; boltedconnections; support anchorage tobuilding structure)
Supports for Platforms, Jet Impingement Structural SupportShields, Masonry Walls, and Other Misc.Structures (Building concrete at locationof expansion and grouted anchors; groutpads for support base plates)Supports for Platforms, Jet Impingement Structural SupportShields, Masonry Walls, and OtherMiscellaneous Structures (Supportmembers; welds; bolted connections; support anchorage to building structure)
Supports for Racks, Panels, Cabinets, Structural Supportand Enclosures for Electrical Equipment and Instrumentation (Building concrete atlocation of expansion and groutedanchors; grout pads for support baseplates)Supports for Racks, Panels, Cabinets, Structural Supportand Enclosures for Electrical Equipment and Instrumentation (Support members;welds; bolted connections; supportanchorage to building structure)
The aging management review results for these components are provided in:Table 3.5.2-2Component Supports Commodity GroupSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-10 Section 2 -Scoping and Screening Methodology and Results2.4.3 Cooling LakeDescription The Cooling Lake is located over 800 feet east of the power block building complex.
TheCooling 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 pipelineoutfall structure and makeup and blowdown valve house, service spillway (which is also knownas 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 ofthe shore line (plant side) is made up of natural topography.
The lake also has peripheral dikeembankments 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 designedto contain the Cooling Lake water level at a normal water level of 700' MSL which is 10 feetbelow plant grade. The purpose of the Cooling Lake is to provide a source of cooling water forthe Nonessential Cooling Water System which includes the circulating water and service watersystems.
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 theCooling Lake during normal plant operations.
The Cooling Lake has an internal dike system toincrease the flow path of returning warm water for efficient heat dissipation.
Failure of theCooling 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 ultimateheat sink. Failure of the Cooling Lake embankment would not result in flooding of plantfacilities since plant grade and floor elevations are 710 feet and 710.5 feet respectively.
Theupper portion of the Cooling Lake including the embankment and discharge structure anddischarge flume are not safety-related and do not perform an intended function for licenserenewal.
The submerged CSCS pond and intake flume (ultimate heat sink) as well as theCSCS outfall structure which are located within the Cooling Lake are safety-related and areevaluated 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) pondwhich includes the intake flume. The CSCS pond and intake flume are excavated from thelocal soil and is contained within and underlies the Cooling Lake and the natural grade of thesite. Failure of the Cooling Lake embankment and internal dikes does not affect any intendedfunction and does not affect the ultimate heat sink. The intake flume and CSCS pond have acombined surface area of 85 acres and depth of 5 feet. The submerged CSCS Pond andintake flume design emergency water level is 690 feet MSL, which is 10 feet below the CoolingLake normal water level. The intake flume is 2,500 feet long. The upper flume walls areprotected against wave action by riprap placed over crushed stone. At the Lake ScreenHouse, the sides of the flume are formed by a concrete retaining wall on the south and a sheetpile retaining wall on the north. The concrete retaining wall and the sheet pile retaining wallare evaluated with the Lake Screen House. A nonsafety-related shad net is installed acrossthe end of the intake flume at the Cooling Lake. The purpose of the CSCS pond and intakeLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-11 Section 2 -Scoping and Screening Methodology and Resultsflume are to provide the ultimate heat sink by providing water for the Essential Cooling WaterSystem 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 thestation for 30 days with no makeup for both normal and accident conditions, and also provideswater for fire protection equipment.
The submerged CSCS pond and intake flume are inscope; since they are Seismic Category I, safety-related structures required to maintainstructural integrity and an adequate volume of cooling water for safety-related systems duringdesign 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 outletchute, or the CSCS pond water inlet chute is a safety-related structure consisting of concreteenclosing 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 outfallstructure is a safety-related structure which directs return flow from CSCS pipelines to theultimate heat sink and therefore is in scope for license renewal.Makeup Pipeline Outfall Structure and Makeup and Blowdown Valve HouseThe 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 whichdischarges to a reinforced concrete channel structure directing makeup water into the CoolingLake. The purpose of the makeup pipeline outfall structure is to discharge the makeup waterfrom the Illinois River into the lake. The makeup and blowdown valve house contains valvesfor the subject pipelines, and it is constructed of reinforced concrete below grade and concretemasonry block above grade. The emergency shutdown capability of the plant is notdependent on water input from the main Cooling Lake or makeup pipeline water from theIllinois River. The ultimate heat sink (UHS) provides sufficient cooling water to permit the safeshutdown and cool down of the station for 30 days with no makeup for both normal andaccident conditions.
The UHS also provides water for fire protection equipment.
Therefore, the nonsafety-related Lake Makeup Pipeline Outfall Structure and the Makeup and BlowdownValve 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 theblowdown valve house (pit) are constructed of reinforced concrete.
The purpose of the servicespillway is to direct lake water into the blowdown line for discharge into the Illinois River. Thespillway including its gates and valve pit provide for Cooling Lake level control, dilution ofwastes and control of the dissolved solids. The blowdown line connects with the lakeblowdown outfall structure located on the Illinois River which is evaluated withMiscellaneous 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 renewalintended 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 isLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-12 Section 2 -Scoping and Screening Methodology and Resultsto passively drain the Cooling Lake when the water level becomes sufficiently high to preventovertopping 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 notperform 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 oflicense renewal are reinforced concrete
- elements, concrete embedments, earthen and riprapelements, shad net anchors, and hatches and plugs which are part of the submerged CSCSpond, intake flume, and the CSCS outfall structure.
Refer to the "Components Subject to Aging Management Review" table below for a completelist 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 licenserenewal are the auxiliary
- spillway, cooling lake embankment (including discharge structure anddischarge flume), makeup pipeline outfall structure, service spillway, and lake blowdown valvepit. These structures are nonsafety-related and are designed to provide and maintain avolume of water for nonsafety-related cooling purposes, level control, waste dilution or toprotect the Cooling Lake embankment (dikes).
They are not necessary for the function of theUHS, fire protection, or to provide flood protection for LSCS plant. Additionally, there are otherfeatures in the immediate vicinity of the Cooling Lake which are associated with access to theLake, public recreation on the lake, and the fish hatchery.
These structural components andfeatures do not perform a license renewal intended function and their failure will not preventsatisfactory accomplishment of a safety-related function.
Not included within the boundary of the Cooling Lake are the Lake Screen House and theretaining 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 CoolingLake are the lake blowdown outfall structure and associated valve pit, and the river screenhouse 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 theshad 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 isrelied upon to remain functional during and following design basis events. The Cooling Lakemeets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of the structure couldprevent satisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
TheCooling Lake also meets 10 CFR 54.4(a)(3) because it is relied upon in the safety analysesand plant evaluations to perform a function that demonstrates compliance with theCommission's regulations for Fire Protection (10 CFR 50.48) and Station Blackout (10 CFR50.63). The Cooling Lake is not relied upon in any safety analyses or plant evaluations toperform a function that demonstrates compliance with the Commission's regulations forEnvironmental Qualification (10 CFR 50.49) and Anticipated Transient Without Scram (10 CFR50.62).LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-13 Section 2 -Scoping and Screening Methodology and ResultsIntended 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.
- 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).
- 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 CFR54.4(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 CFR54.4(a)(3)
UFSAR References 2.42.4.1.12.4.82.4.11.62.52.5.42.5.52.5.6Table 3.2-19.29.2.610.411.2License Renewal Boundary DrawingsLR-M-3LaSalle County Station, Units 1 and 2 Page 2.4-14License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.4-3Cooling LakeComponents Subject to Aging Management ReviewComponent Type Intended FunctionConcrete Embedments Structural SupportConcrete:
(CSCS Outfall Structure)
Direct FlowStructural SupportConcrete:
Shad Net Anchors Structural SupportEarthen Water-Control Structures (Intake Direct FlowFlume and Submerged CSCS Pond) Water retaining boundaryHatches/Plugs
- Shelter, Protection Structural SupportThe aging management review results for these components are provided in:Table 3.5.2-3Cooling LakeSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-15 Section 2 -Scoping and Screening Methodology and Results2.4.4 Diesel Generator BuildingDescription The Diesel Generator Building consists of a separate structure for each unit. One is locatednorth of the Auxiliary
- Building, the other south, both east of the Turbine Building.
Each DieselGenerator Building is a multi-level Seismic Category I structure.
These structures are part ofthe power generation complex which includes several contiguous buildings.
The shear wallsfor the Reactor Building, Auxiliary
- Building, Turbine Building, Radwaste
- Building, DieselGenerator Buildings, and Off-gas Filter Building are interconnected.
These shear walls havebeen considered to act together to resist lateral loads applied to these buildings.
The shearwalls 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 gradefloor. Exterior walls are reinforced concrete.
Structural steel columns support the upperelevation slabs. The roof is reinforced concrete with built up roofing.
The diesel intakes areprovided with a metal enclosure located on the roof. The Diesel Generator Buildings are alsodesigned to withstand
- tornados, missiles and flooding.
Each Diesel Generator Buildingincludes roof extensions for the air intakes, and diesel exhaust penthouses.
The purpose of the Diesel Generator Building is to provide structural
- support, shelter, accesscontrol, and protection to safety-related
- systems, components and structures housed within itduring 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 theUnit 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 dieselgenerators.
Each diesel generator unit is enclosed in its own reinforced concrete missile protected baywhich is designed to provide physical separation for redundant mechanical and electrical safety-related components.
Each bay contains a diesel generator, fuel oil day tank, airreceivers and compressor and control cabinets.
Each bay also contains overhead riggingbeams which support maintenance activities.
The upper mezzanine portion of each baycontains the air intakes,
- exhaust, ventilation, and coolant support system. The lowerelevations contain the fuel oil storage tanks.Included in the boundary of the Diesel Generator Building and determined to be in scope forlicense renewal are concrete
- anchors, concrete embedments, curbs, equipment supports andfoundations,
- hatches, plugs, masonry walls, metal decking, reinforced concrete elements ofthe building, steel components, steel elements, and structural bolting.Refer to the "Components Subject to Aging Management Review" table below for a completelist 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, fireLaSalle County Station, Units 1 and 2 Page 2.4-16License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsbarriers, component
- supports, and structural commodities.
Cranes and hoists are evaluated separately with the Cranes, Hoists and Refueling Equipment System. Fire barriers areevaluated separately with the Fire Protection System. Component
- supports, including theirrespective
- bolting, are evaluated with the Component Supports Commodity Group. TheStructural 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 areevaluated with their respective mechanical and electrical license renewal systems orcommodities group.For more detailed information, see UFSAR Sections 1.2.2.2, 3.5.1, 3.5.2, 3.7.1.4, and3.8.4.1.5.
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. TheDiesel Generator Building is not in scope under 10 CFR 54.4(a)(2) because failure ofnonsafety-related portions of the structure would not prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
The Diesel Generator Building also meets 10 CFR54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform afunction 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 notrelied 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.
- 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 CFR54.4(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 CFR54.4(a)(3)
LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-17 Section 2 -Scoping and Screening Methodology and ResultsUFSAR References 1.2.2.21.2.4.12.5.4.103.5.13.5.23.7.1.43.8.4.1.5 3.8.5.1.1 9.5.19.5.7.1.1 9.5.8.3Table 3.2-1Appendix H -Fire Hazards AnalysisLicense Renewal Boundary DrawingsLR-M-3Table 2.4-4Diesel Generator BuildingComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting (Structural)
Structural SupportConcrete Anchors Structural SupportConcrete Curbs Direct FlowConcrete Embedments Structural SupportConcrete:
(Exhaust Enclosure)
Above- Missile Barriergrade exterior
- Shelter, Protection Structural SupportConcrete:
Above-grade Exterior Flood Barrier(accessible areas) Missile BarrierShelter, Protection Structural SupportConcrete:
Above-grade Exterior Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Structural SupportConcrete:
Below-grade Exterior Flood Barrier(inaccessible areas) Shelter, Protection Structural SupportConcrete:
Foundation, Subfoundation Flood Barrier(inaccessible areas) Shelter, Protection Structural SupportConcrete:
Interior Flood BarrierMissile BarrierShelter, Protection LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-18 Section 2 -Scoping and Screening Methodology and ResultsComponent Type Intended FunctionStructural SupportEquipment Supports and Foundations Structural SupportHatches/Plugs Missile BarrierShelter, Protection Structural SupportMasonry Walls: Above-grade Exterior Missile BarrierShelter, Protection Structural SupportMasonry Walls: Interior Missile BarrierShelter, Protection Structural SupportMetal Decking Structural SupportMetal Siding Shelter, Protection Steel Components:
Structural Steel Structural SupportSteel Elements:
Liner, Liner Anchors, Water Retaining BoundaryIntegral Attachments (Sump Liner)The aging management review results for these components are provided in:Table 3.5.2-4Diesel Generator BuildingSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-19 Section 2 -Scoping and Screening Methodology and Results2.4.5 Lake Screen HouseDescription The Lake Screen House includes the service water tunnel, the two (2) flume retaining wallsdirectly north and south of the building, and the contiguous chemical feed building.
The southretaining wall is a reinforced concrete gravity wall. The north retaining wall is steel sheetpiling.The Lake Screen House is a multi-story building.
It consists of a reinforced concrete box typestructure.
A steel frame is constructed using block walls with a precast concrete roof. Thestructure 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-footthick reinforced concrete mat foundation on soil. The Seismic Category I service water tunnelis located in the building.
The Lake Screen House is designed to provide support and protection for the SeismicCategory I service water tunnel and the associated safety-related piping and valvecomponents.
The Lake Screen House is designed to provide a water retaining boundary andaccess to the submerged portion of the Core Standby Cooling Systems (CSCS) pond UHScooling water under postulated environmental and design basis accident loadings.
The LakeScreen House is also designed to provide support, shelter and protection of the station firepumps 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 waterpumps, traveling
- screens, bar racks (trash rack grill), fire protection pumps, the service watertunnel and associated piping. A normally closed bypass line is available to bypass thetraveling screens providing lake water directly to the service water tunnel. Buried CSCS pipingis connected to the service water tunnel and to safety-related CSCS pumps located within thepower block. The bypass line valve is housed in an external concrete valve enclosure which ispart of the below grade south exterior wall. The Lake Screen House structure also housesand supports various other nonsafety-related equipment including cranes and hoists, electrical equipment, and panels. A chemical feed system located near the Lake Screen Houseprovides 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 andincludes chemical storage and equipment for water treatment purposes.
The chemical feedbuilding is an above grade steel frame and metal siding structure on a concrete matfoundation.
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 sixbays where the nonsafety-related pumps are located.
Closure of the stop logs on theseopenings, and realignment of system valves allows isolation of each of the bays formaintenance and different modes of operation.
The purpose of the Lake Screen House is to provide structural
- support, shelter, protection, andaccess to submerged CSCS pond water (UHS) for Seismic Category I safety-related concretestructural components and mechanical components under postulated environmental andLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-20 Section 2 -Scoping and Screening Methodology and Resultsdesign basis accident loading conditions.
The Lake Screen House also provides a waterretaining 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 Iplant equipment and components, including fire protection pumps and associated piping,valves and related equipment.
The Lake Screen House is therefore in scope for licenserenewal.Evaluation of the chemical feed building with the chemical feed pump house determined that itdoes not perform an intended function delineated in 10 CFR 54.4(a);
however a portion of thechemical feed building is in the vicinity of, and in contact with, the Lake Screen House andtherefore, the chemical feed building structure is in scope for license renewal.
The adjacentchemical feed pump house south of the chemical feed building is not in scope for licenserenewal.Included within the boundary of the Lake Screen House which also includes the chemical feedbuilding, and determined to be within the scope of license renewal are reinforced concreteelements (including south flume wall), concrete embedments, concrete
- anchors, equipment supports and foundations, hatches and plugs, metal decking, masonry walls, steelcomponents (structural steel), steel elements (trash rack bar grill assembly) and piles (sheetpiling -north flume wall), precast concrete panels (roof slab), and metal siding. Also includedwithin 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 completelist 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 inscope for license renewal are the active stop logs and valve motor operators which are subjectto 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 preventsatisfactory accomplishment of a safety-related function.
Not included in the boundary of the Lake Screen House structure are cranes and hoists, firebarriers, structural commodities, and components supports.
Cranes and hoists are evaluated separately with the Cranes, Hoists and Refueling Equipment system, fire barriers areevaluated separately with the Fire Protection System. Component
- supports, including theirrespective
- 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 barriersand 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 ScreenHouse are evaluated with their respective mechanical and electrical license renewal systemsor commodities group. Also not included is the Cooling Lake, which is evaluated separately asthe 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 2License Renewal Application Page 2.4-21 Section 2 -Scoping and Screening Methodology and ResultsReason for Scope Determination The Lake Screen House meets 10 CFR 54.4(a)(1) because portions of the building include asafety-related structure that is relied upon to remain functional during and following designbasis 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 thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48) and Station Blackout (10 CFR 50.63). The Lake Screen House is not relied upon inany safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for Environmental Qualification (10 CFR 50.49) andAnticipated 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.
- 3. Provides physical
- support, shelter, and protection for nonsafety-related
- systems, structures, and components (SSCs) whose failure could prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
- 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 CFR54.4(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 CFR54.4(a)(3)
UFSAR References 1.2.2.22.5.4.10.3 3.8.4.13.8.4.1.7.2 3.3.2.33.4.1.39.2.1.39.2.12Table 3.2-1LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-22 Section 2 -Scoping and Screening Methodology and ResultsLicense Renewal Boundary DrawingsLR-M-3Table 2.4-5Lake Screen HouseComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting (Structural)
Structural SupportConcrete Anchors Structural SupportConcrete Embedments Structural SupportConcrete:
Above-grade Exterior Flood Barrier(accessible areas) Missile BarrierShelter, Protection Structural SupportConcrete:
Above-grade Exterior Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Structural SupportConcrete:
Below-grade Exterior Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Structural SupportWater retaining boundaryConcrete:
Foundation, Subfoundation Flood Barrier(inaccessible areas) Shelter, Protection Structural SupportWater retaining boundaryConcrete:
Interior Missile BarrierShelter, Protection Structural SupportEquipment Supports and Foundations Structural SupportHatches/Plugs Missile BarrierShelter, Protection Structural SupportMasonry Walls: Above-grade Exterior
- Shelter, Protection Structural SupportMasonry Walls: Interior
- Shelter, Protection Structural SupportMetal Siding Shelter, Protection Piles (Sheet Piling- North Flume Wall) Flood BarrierStructural SupportPrecast Panel (Roof Slab) Shelter, Protection Steel Components:
Structural Steel Structural SupportSteel Elements (Bar Grill) FilterThe aging management review results for these components are provided in:LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-23 Section 2 -Scoping and Screening Methodology and ResultsTable 3.5.2-5Lake Screen HouseSummary of Aging Management Evaluation 0LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-24 Section 2 -Scoping and Screening Methodology and Results2.4.6 Offgas BuildingDescription The Offgas Building, which is also known as the Off-gas Filter Building, is located east of theReactor Building.
The Offgas Building is part of the power generation complex which includesseveral contiguous buildings.
The shear walls for the Reactor Building, Auxiliary
- Building, Turbine Building, Radwaste
- Building, Diesel Generator Buildings, and Offgas Filter Buildingare interconnected.
These shear walls have been considered to act together to resist lateralloads applied to these buildings.
Therefore, the shear walls for these buildings are SeismicCategory I.The Offgas Building consists of reinforced concrete structural steel and metal siding withinterior, reinforced concrete and concrete block walls. Exterior walls are reinforced concreteand 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 theroof is reinforced concrete.
The Offgas Building is also contiguous with the equipment accessbuilding which is a part of the Reactor Building.
The majority of the south wall of theequipment access building is common with the north wall of the Offgas Building.
This commonwall 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 theother power generation complex shear walls and are Seismic Category I.The purpose of the Offgas Building is to provide structural
- support, shelter, and protection fornonsafety-related
- systems, structures, and components during normal plant operation.
TheOffgas Building contains the off-gas filters and associated equipment components and thesupport systems and components necessary to support Fire Protection.
The Offgas Buildingis in the vicinity of the Reactor Building, resists exterior
- flooding, and the foundation shearwalls 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 oflicense renewal are concrete
- anchors, concrete embedments, equipment supports andfoundations,
- hatches, plugs, masonry walls, metal decking, metal siding, reinforced concreteelements of the building, steel components, steel elements, and structural bolting.Refer to the "Components Subject to Aging Management Review" table below for a completelist 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 withthe Fire Protection System. Component
- supports, including their respective
- bolting, areevaluated 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 2License Renewal Application Page 2.4-25 Section 2 -Scoping and Screening Methodology and Resultsgaskets, 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 areevaluated 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 thestructure are safety-related and relied upon to remain functional during and following designbasis 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 itis relied upon in the safety analyses and plant evaluations to perform a function thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48). The Offgas Building is not relied upon in any safety analyses or plant evaluations toperform a function that demonstrates compliance with the Commission's regulations forEnvironmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR50.62), and Station Blackout (10 CFR 50.63).Intended Functions
- 1. Provides structural support or restraint to SSCs in the scope of license renewal.
- 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).
- 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 CFR54.4(a)(3)
UFSAR References 1.11.2.2.2Table 3.2-13.4.1.33.8.4.1.6.3 9.5License Renewal Boundary DrawingsLR-M-3LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-26 Section 2 -Scoping and Screening Methodology and ResultsTable 2.4-6Offqas BuildingComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting (Structural)
Structural SupportConcrete Anchors Structural SupportConcrete Curbs Flood BarrierConcrete Embedments Structural SupportConcrete:
Above-grade Exterior Flood Barrier(accessible areas) Missile BarrierShelter, Protection Shielding Structural SupportConcrete:
Above-grade Exterior Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Shielding Structural SupportConcrete:
Below-grade Exterior Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Structural SupportConcrete:
Foundation, Subfoundation Flood Barrier(inaccessible areas) Shelter, Protection Structural SupportConcrete:
Interior Missile BarrierShelter, Protection Shielding Structural SupportEquipment Supports and Foundations Structural SupportHatches/Plugs
- Shelter, Protection Structural SupportMasonry Walls: Interior
- Shelter, Protection Shielding Structural SupportMetal Decking Shelter, Protection Structural SupportMetal Siding Shelter, Protection Steel Components:
Structural Steel Structural SupportThe aging management review results for these components are provided in:Table 3.5.2-6Offgas BuildingSummary of Aging Management Evaluation LaSalle County Station, Units I and 2License Renewal Application Page 2.4-27 Section 2 -Scoping and Screening Methodology and Results2.4.7 Primary Containment Description The Primary Containment includes the LaSalle County Station Unit 1 and Unit 2 PrimaryContainment structures, and the containment internal structures.
Each Primary Containment is entirely enclosed and contained within the reinforced concrete Reactor Building.
TheReactor Building provides secondary containment, and shelter and protection for the PrimaryContainment 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 aconcrete structure with the exception of the drywell head and access penetrations, which arefabricated from steel. The containment is a BWR (boiling water reactor)
Mark II design ofover-under pressure suppression configuration with multiple downcomers penetrating areinforced concrete drywell floor and connecting the reactor drywell to the water pool in thesuppression chamber.
The Primary Containment consists of a steel dome head and post-tensioned concrete wall standing on a base mat of conventionally reinforced concrete.
Theinner 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 drywelland suppression chamber are connected four vacuum relief valves which are outside of thePrimary 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 theeffects of the postulated design basis line break and direct the steam released to thesuppression chamber pool. The suppression chamber provides a reservoir of water capableof 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 supportto safety and nonsafety-related
- systems, structures, and components housed within thePrimary Containment.
The steel lined concrete drywell and suppression chamber wallsprovide a structural pressure
- barrier, water retaining
- boundary, radiation shielding, andstructural 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 andassociated auxiliary
- systems, vent pipe system (downcomers) connecting the drywell andwetwell, 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 thesuppression 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 isreinforced with conventional reinforcing steel and with vertical and horizontal tendons.
Theunbounded tendons are protected by a corrosion protection medium. The Reactor Buildingfloor 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 thickLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-28 Section 2 -Scoping and Screening Methodology and Resultsreinforced concrete continuous under both the containment and the reactor building and isfounded on soil. The top of the base foundation slab is lined with a stainless steel liner platethat 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 forattachments and are anchored to the concrete containment wall by structural steel memberswelded to the outside of the liner plate and embedded in the concrete.
Loads from internalcontainment attachments are transferred directly into the containment concrete wall bythickening the liner, and by attaching structural weldments or embeds that transfer the load tothe concrete.
-Penetrations and access hatches-Services and access between the inside and the outsideof the containment are performed through penetrations.
Basic penetration types include pipepenetrations, electrical penetrations, and access hatches (equipment hatch, personnel lock,suppression chamber access hatches, and CRD removal hatch). Pipe penetration sleeves areembedded into the concrete.
The pipe is welded directly to the head fitting which is welded tothe sleeve. Air gaps are provided around the pipes. Pipe penetrations are of welded steelconstruction without expansion
Electrical penetration assemblies are used to extend electrical conductors through the pressure boundary of the Primary Containment.
The assembly issized to be inserted in steel penetration sleeves furnished as part of the containment.
Sealsare provided between each conductor and the electrical penetration end plate. Accesshatches 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 acylindrical lower flange. The head is made of steel plate and is secured with bolts at themating 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, supportrecirculation pumps, support piping and auxiliary equipment, and form the pressure-suppression system. These structures include the drywell floor, reactor stabilizer structure (orseismic truss), steam supply system supports, reactor pedestal, reactor shield (wall), platforms and galleries, the suppression chamber columns (concrete columns with an outer lining ofstainless 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 forthe downcomers.
It is a reinforced concrete circular slab, 3 feet thick. A stainless steel linerplate is provided on underside of the drywell floor. The drywell floor is supported by thereactor pedestal, the containment wall, steel lined reinforced concrete columns.
The drywellfloor is penetrated by 98 downcomers.
The cavity floor which is a reinforced concrete floorslab internal to the reactor pedestal is lined on both the upper and lower sides since it is alsothe floor of the drywell sump.The reactor stabilizer structure (also known as the seismic truss) is a steel truss which servesto laterally brace the top of the reactor shield wall to the containment wall.LaSalle County Station, Units I and 2License Renewal Application Page 2.4-29 Section 2 -Scoping and Screening Methodology and ResultsReactor steam supply system piping and pumps are supported by various component supports which are supported by the structural steel galleries, or the reactor shield orcontainment wall. These component supports are evaluated separately with the Component Supports Commodity Group. The reactor stabilizer bracket is included and evaluated with thePrimary Containment.
The reactor pedestal is an upright cylindrical reinforced concrete shell that rests on thecontainment base foundation slab, and supports the drywell floor slab, cavity floor slab, reactorvessel, reactor shield wall, platforms and galleries, downcomer
- bracing, and piping andequipment 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.
Thereactor 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, andseismic loads. The reactor shield wall is constructed of inner and outer carbon steel platesand 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 gratingand plate. The platforms and galleries consist of structural steel framing supported by thepedestal, containment, and shield walls with steel and aluminum grating.
Beams which spanbetween the shield or pedestal and the containment wall are provided with connections at thecontainment that allow for free thermal expansion.
The suppression chamber columns consist of stainless steel lined reinforced concrete columnswhich provide support the drywell floor slab.The stainless steel downcomers which connect the drywell to the pool of water in thesuppression chamber are provided with bracing in the suppression chamber.Other miscellaneous internal structural components include:
pipe whip restraints, wetwellplatforms, MSRV discharge pipe bracing and support, quencher
- supports, equipment andpiping 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, andinternal concrete structures.
Steel elements and components in the boundary of the PrimaryContainment include gallery structural
- members, pipe whip restraints, reactor shield, reactorstabilizer structure, reactor stabilizer
- bracket, downcomers and bracing, vacuum relief valvesand piping, refueling bellows assembly, seal plate, grating, liner, liner anchors and integralattachments, and the drywell head. Other components included in the boundary of thePrimary Containment are bolting (containment closure and structural),
Service Level 1coatings, concrete anchors and embedments, doors (reactor shield doors and plugs), electrical penetration assemblies, hatches and plugs, metal components
( including permanent drywellshielding),
penetration sleeves and flued head closures, personnel lock, equipment hatch,CRD hatch, and other hatches and closures, jet deflectors, seals and gaskets, and includesLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-30 Section 2 -Scoping and Screening Methodology and Resultsinternal structures mentioned above.Refer to the "Components Subject to Aging Management Review" table below for a completelist of components included in the boundary of the Primary Containment.
The Primary Containment performs intended functions delineated in 10 CFR 54.4 and is inscope for license renewal in it's entirely.
Not included in the boundary of the Primary Containment are main steam safety relief valvesand discharge lines, monorails and hoists, quenchers, drywell and suppression chamber sprayheaders, ECCS suction strainers, component
- supports, reactor coolant system and othermechanical systems and components, electrical systems and commodities, fire barriers, andpiping 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 otherenclosures for electrical equipment and instrumentation; and tube track. In addition, mechanical and electrical systems and components housed in or located within the PrimaryContainment are evaluated with their respective mechanical and electrical license renewalsystem 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 PrimaryContainment meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of thestructure could prevent satisfactory accomplishment of function(s) identified for 10 CFR54.4(a)(1).
The Primary Containment also meets 10 CFR 54.4(a)(3) because it is relied uponin 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), andStation Blackout (10 CFR 50.63).Intended Functions
- 1. Provides physical
- support, shelter, and protection for safety-related
- systems, structures, and components.
- 2. Provide primary containment boundary.
- 3. Controls the potential release of fission products to the external environment so that offsiteconsequences 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 adesign basis loss-of-coolant accident (LOCA) so that offsite consequences are withinLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-31 Section 2 -Scoping and Screening Methodology and Resultsacceptable 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 CFR54.4(a)(1)
- 6. Provides a source of water for emergency core cooling systems.
- 7. Provides physical
- support, shelter, and protection for nonsafety-related
- systems, structures, and components (SSCs) whose failure could prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
- 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 CFR54.4(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, andcomponents relied upon in safety analyses or plant evaluations to perform a function thatdemonstrates compliance with the Commission's regulation for Anticipated Transients WithoutScram (10 CFR 50.62). 10 CFR 54.4(a)(3)
- 11. Provides physical
- support, shelter, and protection for systems, structures, andcomponents relied upon in safety analyses or plant evaluations to perform a function thatdemonstrates compliance with the Commission's regulation for Station Blackout (10 CFR50.63). 10 CFR 54.4(a)(3)
UFSAR References Table 3.6-6Figure 3.6-273.8.13.8.23.8.3Table 3.8-1Figure 3.8-1 through 3.8-385.3.3.1.4 Table 6.1-16.2.1Table 6.2-1E.3E.4E.5E.6E.7LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-32 Section 2 -Scoping and Screening Methodology and ResultsLicense Renewal Boundary DrawingsLR-M-3LR-LAS-M-92, Sheet 2LR-LAS-M-1 38, Sheet 2Table 2.4-7Primary Containment Components Subject to AgingManagement ReviewComponent Type Intended FunctionBolting (Containment Closure)
Structural Pressure BarrierStructural SupportBolting (Structural)
Structural SupportBolting (Vacuum Relief Line Pipe Structural Pressure BarrierFlanges)
Structural SupportConcrete Anchors Structural SupportConcrete Embedments Structural Pressure BarrierStructural SupportWater retaining boundaryConcrete:
Containment Wall (accessible Missile Barrierareas -includes Buttresses)
- Shelter, Protection Shielding Structural Pressure BarrierStructural SupportConcrete:
Containment Wall (inaccessible Missile Barrierareas -includes Buttresses)
- Shelter, Protection Shielding Structural Pressure BarrierStructural SupportConcrete:
Foundation, Subfoundation,
- Shelter, Protection Basemat (accessible areas -Tendon Structural Pressure BarrierAccess Tunnel Ceiling)
Structural SupportConcrete:
Foundation, Subfoundation, Flood BarrierBasemat (inaccessible areas) Shelter, Protection Structural Pressure BarrierStructural SupportConcrete:
Interior (Drywell Floor and Direct FlowCavity Floor) Structural Pressure BarrierStructural SupportConcrete:
Interior (Pedestal)
Direct FlowStructural Pressure BarrierStructural SupportConcrete:
Interior (Suppression Pool Structural SupportColumns)Concrete:
Reactor Cavity Contiguous Shielding Fuel Pool Walls with TendonsLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-33 Section 2 -Scoping and Screening Methodology and ResultsComponent Type Intended FunctionConcrete:
Reactor Cavity Contiguous Structural SupportFuel Pool Walls with TendonsDoors (Reactor Shield Wall Doors) Shielding Structural SupportDowncomer Jet Deflectors Direct FlowShelter, Protection Electrical Penetration Assemblies
- Shelter, Protection (includes Penetration Sleeves and Structural Pressure BarrierClosure Plates)Hatches/Plugs Missile BarrierShelter, Protection Structural Pressure BarrierMechanical Penetrations (includes
- Shelter, Protection Penetration
- Sleeves, Flued Heads, and Structural Pressure BarrierClosure Plates for Pipe and Instrument Structural SupportPenetrations)
Metal Components (Permanent Drywell Shielding Shielding)
Structural SupportPenetration Sleeves:
Drywell Floor Structural Pressure Barrier(including Closure Rings, Plates, and Structural SupportCaps)Personnel
- Airlock, Equipment Hatch: Missile BarrierCRD Hatch Shelter, Protection Structural Pressure BarrierPersonnel
- Airlock, Equipment Hatch: Shelter, Protection Locks, Hinges, and Closure Mechanisms Structural Pressure BarrierPipe Whip Restraints and Jet Pipe Whip Restraint Impingement ShieldsPrestressing System: Anchorage Structural SupportComponents Prestressing System: Grease Cap at Shelter, Protection Tendon Anchorage Prestressing System: Tendons Structural SupportSeals and Gaskets Structural Pressure BarrierService Level I Coatings (Containment Maintain AdhesionBoundary)
Service Level I Coatings (Internal Maintain AdhesionStructures)
Sliding Surfaces (Support)
Structural SupportLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-34 Section 2 -Scoping and Screening Methodology and ResultsComponent TypeIntended FunctionSteel Components:
(Reactor Shield Wall) Shelter, Protection Shielding Structural SupportSteel Components:
(Reactor Stabilizer Structural SupportBracket Assembly)
Steel Components:
Reactor Stabilizer Structural SupportStructure (Stabilizer Truss)Steel Components:
Structural Steel Structural SupportSteel Elements:
(Grating)
Structural SupportSteel Elements:
(Refueling Bellows Flood BarrierAssembly)
- Shelter, Protection Structural SupportWater retaining boundarySteel Elements:
Downcomer Bracing Structural Support(Stiffeners)
Steel Elements:
Downcomers Direct FlowSteel Elements:
Drywell Floor and Cavity Direct FlowFloor Liner, Liner Anchors, Integral Structural Pressure BarrierAttachments Steel Elements:
Drywell Head Missile BarrierShielding Structural Pressure BarrierSteel Elements:
Drywell Liner, Liner Structural Pressure BarrierAnchors, Integral Attachments Structural Support(accessible areas)Steel Elements:
Drywell Liner, Liner Structural Pressure BarrierAnchors, Integral Attachments Structural Support(inaccessible areas)Steel Elements:
Liner for Concrete
- Shelter, Protection
- Columns, Liner Anchors, IntegralAttachments Steel Elements:
Liner, Liner Anchors, Direct FlowIntegral Attachments (Sump) Water retaining boundarySteel Elements:
Pedestal Liner, Liner Direct FlowAnchors, and Integral Attachments
- Shelter, Protection Structural Pressure BarrierSteel Elements:
Ring Girder Adapter (Unit Structural Support1 Vessel Skirt)Steel Elements:
Ring Girder Assembly Flood Barrier(includes Cone Skirt)LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-35 Section 2 -Scoping and Screening Methodology and ResultsComponent TypeIntended FunctionSteel Elements:
Ring Girder Assembly Structural Pressure Barrier(includes Cone Skirt) Structural SupportWater retaining boundarySteel Elements:
Seal Plate Flood BarrierStructural SupportWater retaining boundarySteel Elements:
Suppression Chamber Structural Pressure BarrierLiner, Liner Anchors, Integral Structural SupportAttachments (accessible areas) Water retaining boundarySteel Elements:
Suppression Chamber Structural Pressure BarrierLiner, Liner Anchors, Integral Structural SupportAttachments (inaccessible areas) Water retaining boundarySteel Elements:
Vacuum Breaker Valves, Pressure ReliefIsolation Valves, and Piping Structural Pressure BarrierTunnel (tendon access tunnel walls and Shelter, Protection floor)The aging management review results for these components are provided in:Table 3.5.2-7Primary Containment Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-36 Section 2 -Scoping and Screening Methodology and Results2.4.8 Radwaste BuildingDescription The Radwaste
- Building, which is also called the solid radwaste
- building, contains both thesolid and liquid processing portions of the Radwaste System. The Radwaste Building is amulti-story structure with above and below grade areas. The structure is a part of the powergeneration complex which includes several contiguous buildings.
The Radwaste Building islocated west of the Turbine Building.
The shear walls for the Reactor Building, Auxiliary
- Building, Turbine Building, Radwaste
- Building, Diesel Generator Buildings, and Off-gas FilterBuilding are interconnected.
These shear walls have been considered to act together to resistlateral loads applied to these buildings.
Therefore, the shear walls for these buildings areSeismic Category I. The Radwaste Building is designed to preclude accidental release ofradioactive 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 ofreinforced concrete and concrete block. The structure is supported on a reinforced concretemat foundation on soil. The Radwaste Building includes sump(s) to collect waste water, tankrooms 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 betteraccess 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 radwastefrom being released to the environment.
The Radwaste Building is classified as a SeismicCategory II, nonsafety-related structure.
- However, the Radwaste Building shear walls aredesigned to act together with the other power generation complex shear walls and areclassified as Seismic Category I, and additionally its walls protect against exterior floods. TheRadwaste Building also provides physical
- support, shelter and protection to portions of the FireProtection 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 oflicense renewal are the reinforced concrete
- elements, concrete embedments, concreteanchors, equipment supports and foundations, hatches and plugs, masonry walls, steelcomponents and steel elements of the radwaste building.
Also included within the boundary isstructural bolting associated with specific in scope components evaluated as part of theRadwaste Building.
Refer to the "Components Subject to Aging Management Review" table below for a completelist 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 FireProtection System. Component
- supports, including their respective
- bolting, are evaluated withLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-37 Section 2 -Scoping and Screening Methodology and Resultsthe Component Supports Commodity Group. Structural commodities, including theirrespective
- 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 areevaluated 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, andTable 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 thestructure are safety-related and relied upon to remain functional during and following designbasis 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 thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48). 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 forEnvironmental Qualification (10 CFR 50.49), Anticipated Transient Without Scram (10 CFR50.62), 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).
- 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 CFR54.4(a)(3)
UFSAR References 1.11.2.2.2.i 3.1.2.6.2.3 Table 3.2-13.4.1.33.8.4.13.8.4.1.7.1 LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-38 Section 2 -Scoping and Screening Methodology and Results3.11.1.27.7.11.2.2 9.1.3.1.2 9.4.3.4.2 11.2.1.9.1 11.4.2.712.3.1.6.1 12.3.2.415.7.3.115.7.3.2Appendix E -Construction MaterialLicense Renewal Boundary DrawinasLR-M-3Table 2.4-8Radwaste BuildingComponents Subject to Aging Management ReviewComponent TypeIntended FunctionBolting (Structural)
Structural SupportConcrete Anchors Structural SupportConcrete Curbs Direct FlowConcrete Embedments Structural SupportConcrete:
Above-grade Exterior Flood Barrier(accessible areas) Shelter, Protection Shielding Structural SupportConcrete:
Above-grade Exterior Flood Barrier(inaccessible areas) Shelter, Protection Shielding Structural SupportConcrete:
Below-grade Exterior Flood Barrier(inaccessible areas) Shelter, Protection Structural SupportWater retaining boundaryConcrete:
Foundation, Subfoundation Flood Barrier(inaccessible areas) Shelter, Protection Structural SupportWater retaining boundaryConcrete:
Interior
- Shelter, Protection Shielding Structural SupportWater retaining boundaryEquipment Supports and Foundations Structural SupportHatches/Plugs
- Shelter, Protection Shielding Structural SupportLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-39 Section 2 -Scoping and Screening Methodology and ResultsComponent TypeIntended FunctionMasonry Walls: Above-grade Exterior
- Shelter, Protection Shielding Structural SupportMasonry Walls: Interior
- Shelter, Protection Shielding Structural SupportSteel Components:
Structural Steel Structural SupportSteel Elements:
Liner, Liner Anchors, Water Retaining BoundaryIntegral Attachments (Sump or Pit Liners)Steel Elements:
Liner, Liner Anchors, Water Retaining BoundaryIntegral Attachments (Tank Room orCompartment Liner)The aging management review results for these components are provided in:Table 3.5.2-8Radwaste BuildingSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-40 Section 2 -Scoping and Screening Methodology and Results2.4.9 Reactor BuildingDescription The Reactor Building is a Seismic Category I safety-related structure which includes theequipment access building.
Portions of the multi-level structure are constructed above andbelow grade. The Reactor Building is comprised of an integral structure divided into separateUnit 1 and Unit 2 Reactor Building(s) which share a common foundation, common wallsdividing the Unit 1 and Unit 2 portions, common refueling floor area, equipment accessbuilding, 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 northand 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 acttogether to resist lateral loads applied to these buildings.
Therefore, the shear walls for thesebuildings are Seismic Category I.The Reactor Building consists of poured-in-place, reinforced concrete exterior walls up to therefueling floor. Above this level, the building structure is steel frame with insulated metalsiding with sealed joints. The Reactor Building is supported on a reinforced concrete matfoundation on soil that is continuous under the Primary Containment structure, Auxiliary
- Building, Diesel Generator Buildings, and Turbine Buildings.
The Reactor Building metalsiding is designed to blow-off during tornado winds. The roof consists of galvanized metaldecking 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 wallsare provided to isolate the residual heat removal and core spray pumps and to prevent otherareas of the Reactor Building from being flooded.
The exterior walls of the Reactor Buildingare 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 theequipment access building.
The refueling pools are located below the operating floor in theReactor Building and include the spent fuel and dryer-separator pools. The pools areintegrally connected to, and supported by, the containment vessel and exterior ReactorBuilding walls. The inside surfaces of the pools are lined with 1/4-inch thick stainless steelplate which serves as a leakage barrier.The Reactor Building includes a reinforced concrete main steam chase which connects theprimary containment to the main steam tunnel. It protects the main steam line piping fromexternal missiles and protects the other Seismic Category I components in the ReactorBuilding 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 ReactorBuilding, north of, and contiguous with, the Offgas Building.
It provides controlled access tothe Reactor Building for equipment, including a rail car, by means of an air lock equipped withinner bulkhead doors that are flood and missile proof. The air lock, and the equipment accessbuilding are an extension of the Reactor Building envelope and are therefore addressed aspart of the Reactor Building.
The equipment access building is Seismic Category I andLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-41 Section 2 -Scoping and Screening Methodology and Resultsconsists 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 toprovide better access for erecting and installing equipment.
The block walls also meet thestructural and radiation shielding requirements.
The Reactor Building completely encloses the Primary Containment.
The purpose of theReactor Building is to provide secondary containment when the Primary Containment is inservice 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, duringnormal plant operation, and during and following postulated design basis accidents andextreme environmental conditions.
The Reactor Building is a safety-related Seismic CategoryI 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 fuelstorage facilities, and other reactor safety and auxiliary systems.The Reactor Building is provided with various types of doors which allow personnel andequipment access to and from plant compartments.
Personnel access openings into thebuildings are provided with an interlocked double door airlock system to minimize ReactorBuilding air leakage.
The doors are addressed with the Structural Commodity Group. Safety-related systems and components are protected against failures of high energy lines byconcrete walls. Pipe whip restraints are provided in the primary containment and in the portionof the main steam tunnel located in the auxiliary building and are evaluated with thosestructures.
The ECCS pumps and their associated components are located in individual compartments within a Reactor Building to provide physical separation.
Compartment wallsmay also in some cases provide flood protection and function as missile barriers.
Protection against over pressurization of the various essential equipment compartments in the ReactorBuilding as a result of line breaks is provided by. steam venting paths between the variouscompartments 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, steelcomponents, steel elements including sump liners. Also included in the boundary of theReactor 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 renewaland subject to aging management review.Refer to the "Components Subject to Aging Management Review" table below for a completelist of components included in the boundary of the Reactor Buildings.
Not included in the boundary of the Reactor Buildings are the Primary Containments andassociated 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 2License Renewal Application Page 2.4-42 Section 2 -Scoping and Screening Methodology and Resultsplatform, new fuel storage racks and spent fuel storage racks, miscellaneous cranes, including reactor building crane and hoists, building elevators, component
- supports, and piping andcomponent insulation.
Mechanical and electrical systems and components housed inside thestructure are separately evaluated with their respective mechanical
- systems, electrical
- systems, or commodities.
Fire barriers are evaluated with the Fire Protection System and therefueling
- platform, new fuel storage racks, and spent fuel storage racks and the reactorbuilding crane and the miscellaneous cranes and hoists are evaluated with the Cranes, Hoistsand Refueling Equipment System. Component supports are evaluated with the Component Supports Commodity Group. Structural commodities, including their respective
- bolting, areevaluated 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 forelectrical equipment and instrumentation; penetration seals; penetration sleeves including endcaps; roofing; structural
- sealants, seismic gap seals, gaskets, flashing and other sealants andgap 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 isrelied upon to remain functional during and following design basis events. The ReactorBuilding meets 10 CFR 54.4(a)(2) because failure of nonsafety-related portions of thestructure could prevent satisfactory accomplishment of function(s) identified for 10 CFR54.4(a)(1).
The Reactor Building also meets 10 CFR 54.4(a)(3) because it is relied upon in thesafety analyses or plant evaluations to perform a function that demonstrates compliance withthe 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 offsiteconsequences 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 offunction(s) identified for 10 CFR 54.4(a)(1).
- 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 CFR54.4(a)(3)
LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-43 Section 2 -Scoping and Screening Methodology and Results6. 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 (10CFR 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 CFR54.4(a)(3)
UFSAR References 1.11.2.2.21.2.2.4.2 Figure 2.5-513.1.2.2.7 3.1.2.6.2 Table 3.2-1 with note 22 and 343.3.2.2.2 3.3.2.33.4.23.5.2.2Figure 3.5-33.8.43.8.4.1.1 3.8.4.1.3 3.8.4.1.6.2 3.8.4.1.6.3 3.8.4.33.8.53.11.1.16.2.39.1.29.5.1.2.2 License Renewal Boundary DrawingsLR-M-3LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-44 Section 2 -Scoping and Screening Methodology and ResultsTable 2.4-9Reactor BuildingComponents Subject to Aging Management ReviewComponent Type Intended FunctionBearing Pads Structural SupportBlowout Panels Pressure ReliefShelter, Protection Bolting (Structural)
Structural SupportConcrete Anchors Structural SupportConcrete Curbs Direct FlowConcrete Embedments Structural SupportConcrete:
Above-grade Exterior Flood Barrier(accessible areas) Missile BarrierShelter, Protection Shielding Structural Pressure BarrierStructural SupportConcrete:
Above-grade Exterior Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Shielding Structural Pressure BarrierStructural SupportConcrete:
Below-grade Exterior Flood Barrier(accessible areas) Missile BarrierShelter, Protection Shielding Structural Pressure BarrierStructural SupportConcrete:
Below-grade Exterior Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Structural Pressure BarrierStructural SupportConcrete:
Foundation, Subfoundation Flood Barrier(inaccessible areas) Missile BarrierShelter, Protection Structural Pressure BarrierStructural SupportConcrete:
Interior Flood BarrierHELB/MELB Shielding Missile BarrierLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-45 Section 2 -Scoping and Screening Methodology and ResultsComponent TypeIntended FunctionConcrete:
Interior
- Shelter, Protection Shielding Structural Pressure BarrierStructural SupportEquipment Supports and Foundations Structural SupportHatches/Plugs Flood BarrierHELB/MELB Shielding Missile BarrierShelter, Protection Shielding Structural SupportMasonry Walls: Interior Missile BarrierShelter, Protection Shielding Structural SupportMetal Decking Structural SupportMetal Panels (Includes Steel and Lead- Shielding Filled Steel Shield Panels) Structural SupportMetal Siding Pressure ReliefShelter, Protection Structural Pressure BarrierSpent Fuel Pool Gates Water retaining boundarySteel Components:
Structural Steel Structural SupportSteel Elements:
Fuel Pool Liner, Liner Structural SupportAnchors, and Integral Attachments Water retaining boundarySteel Elements:
Plates: includes Structural SupportCheckered Plate CoversSteel Elements:
Reactor Well, Dryer and Structural SupportSeparator Pool, and Cask Loading Pit Water Retaining BoundaryLiner, Liner Anchors, and IntegralAttachments Steel Elements:
Sump Liners and Integral Water Retaining BoundaryAttachments The aging management review results for these components are provided in:Table 3.5.2-9Reactor BuildingSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-46 Section 2 -Scoping and Screening Methodology and Results2.4.10 Structural Commodity GroupDescription The Structural Commodity Group shares material and environment properties allowingcommon 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; andstructural 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 tostationary louvers that are within the scope of license renewal and perform a license renewalintended function for filtering.
Cable Trays:Cable trays within the scope of license renewal include cable trays that provide licenserenewal intended functions of structural support and shelter/protection for various electrical and control system power, control, and instrumentation cables that are within the scope oflicense renewal.Compressible Joints and Seals:Compressible joints and seals within the scope of license renewal include those items thatperform a license renewal intended function of shelter/protection or water retaining boundaryfor structures or structural components which are within the scope of license renewal.
Thiscommodity group also includes flexible sections of iso-phase and non-segregated busductwork.
Conduit:Conduit within the scope of license renewal include conduit that provide license renewalintended functions of structural support and shelter/protection for various electrical and controlsystem 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 licenserenewal intended functions for shelter/protection, flood barrier, structural pressure barrier,radiation shielding, and HELB shielding for structures which are within the scope of licenserenewal.
Not included in the boundary for this commodity are fire barrier doors that perform anintended function for fire protection and containment airlocks and equipment hatches.
Firebarrier doors are identified and evaluated with the license renewal Fire Protection System.Containment airlocks and equipment hatches are identified and evaluated with the licenserenewal Primary Containment structure.
LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-47 Section 2 -Scoping and Screening Methodology and ResultsInsulation 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 thescope of license renewal.Metallic insulation consists of stainless steel mirror insulation.
Nonmetallic insulation consistsof fiberglass, calcium silicate, ceramic or glass fiber, polymers, and foamed plastic.Metallic insulation jacketing consists of aluminum, and stainless steel held in place by metallicstraps, clips or bolts.The purpose of the insulation is to improve thermal efficiency, minimize heat loads on theHVAC systems, provide for personnel protection, or prevent freezing of heat traced piping andsweating of cold piping and components.
The insulation jacketing maintains the integrity of theunderlying insulation and prevents water intrusion.
Piping and component insulation locatedinside of structures that are within the scope of license renewal can be required to resistseismic loading conditions and therefore, is within the scope of license renewal since failure ofthis 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 thescope of license renewal can be required to protect nearby safety-related components fromoverheating and therefore, is within the scope of license renewal since its failure could impacta 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 alsowithin the scope of license renewal under 10 CFR 54.4(a)(2).
Thermal piping and component insulation located inside structures that are not within thescope of license renewal is not within the scope of license renewal since failure of thisinsulation will not impact intended safety-related functions.
Louvers:Louvers within scope of license renewal include those louvers that perform a license renewalintended function for shelter and protection and are located in structures that are within thescope of license renewal.Spray Shields:Spray Shields within the scope of license renewal, includes metal shielding that performs alicense renewal intended function of shelter/protection and is located on components that arewithin the scope of license renewal and whose failure could impact a function defined for 10CFR 54.4(a)(1).
Miscellaneous Steel (catwalks, stairs, handrails,
- ladders, and platforms, etc.):Miscellaneous steel (catwalks, stairs, handrails
- ladders, and platforms, etc.) components thatperform 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 2License Renewal Application Page 2.4-48 Section 2 -Scoping and Screening Methodology and Resultsduring a seismic event could impact a function defined for 10 CFR 54.4(a)(2).
Included in thiscommodity 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 includethose items that perform license renewal intended functions for shelter/protection andstructural 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 andceilings 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 inthe boundary for this commodity are Primary Containment penetration seals and fire barrierpenetration seals. Primary Containment penetration seals are identified and evaluated withthe 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 performlicense renewal intended functions for structural
- support, flood barrier, shielding, HELBshielding, 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 boundaryfor this commodity are Primary Containment penetration sleeves and fire barrier penetration sleeves.
Primary Containment penetration sleeves are identified and evaluated with thePrimary 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 renewalintended functions for shelter/protection for structures which are within the scope of licenserenewal.
The roofing material consists of the roofing outer membrane.
Not included in theboundary 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 scopeof license renewal include those items that perform license renewal intended functions forshelter/protection, flood barrier, structural pressure
- barrier, radiation shielding, and HELBshielding for structures and components which are within the scope of license renewal.
Notincluded in the boundary for this commodity are seals, gaskets, and moisture barriers(caulking,
- flashing, and other sealants) used for Primary Containment pressure boundaryintegrity and seals, gaskets, and moisture barriers (caulking,
- flashing, and other sealants) used for fire protection.
Seals, gaskets, and moisture barriers (caulking,
- flashing, and otherLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-49 Section 2 -Scoping and Screening Methodology and Resultssealants) used for Primary Containment pressure boundary integrity are identified andevaluated 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 licenserenewal intended functions for structural support and shelter/protection for variousinstrumentation tubing that is within the scope of license renewal.Refer to the "Components Subject to Aging Management Review" table below for a completelist 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. TheStructural 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 for10 CFR 54.4(a)(1).
The Structural Commodity Group also meets 10 CFR 54.4(a)(3) becauseit is relied upon in the safety analyses and plant evaluations to perform a function thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48), Anticipated Transient Without Scram (10 CFR 50.62), and Station Blackout (10 CFR50.63). The Structural Commodity Group is not relied upon in any safety analyses or plantevaluations 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.
- 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).
- 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 CFR54.4(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 (10CFR 50.62). 10 CFR 54.4(a)(3)
LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-50 Section 2 -Scoping and Screening Methodology and Results5. 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 CFR54.4(a)(3)
UFSAR References 3.4.1.33.4.13.5.2.23.8.4.1.7.2 Table 3.2-15.2.3.15.2.4.25.3.3.1.4 6.1.1.1Table 6.1-28.3.1.4.3 9.4.2.29.5.8.2License Renewal Boundary DrawingsLR-M-3Table 2.4-10Structural Commodity GroupComponents Subject to Aging Management ReviewComponent Type Intended FunctionBird Screen FilterBolting (Structural)
Structural SupportCable Trays Shelter, Protection Structural SupportCompressible Joints and Seals Shelter, Protection Water retaining boundaryConduit Shelter, Protection Structural SupportDoors Flood BarrierHELB/MELB Shielding
- Shelter, Protection Shielding Structural Pressure BarrierInsulation 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 2License Renewal Application Page 2.4-51 Section 2 -Scoping and Screening Methodology and ResultsComponent Type Intended FunctionMiscellaneous Steel (Catwalks, Stairs,Handrails,
- Ladders, Platforms, etc.) Structural SupportPanels, Racks, Frames, Cabinets, and Shelter, Protection Other Enclosures Structural SupportPenetration Seals Flood BarrierHELB/MELB Shielding Pressure BoundaryShelter, Protection Shielding Structural SupportPenetration Sleeves (includes Sleeve Flood BarrierHead Plates) HELB/MELB Shielding Pressure BoundaryShelter, Protection Shielding Structural SupportRoofing Shelter, Protection Seals, Gaskets, and Moisture Barriers Flood Barrier(Caulking, Flashing and Other Sealants)
HELB/MELB Shielding Pressure BoundaryShelter, Protection Tube Track Shelter, Protection Structural SupportThe aging management review results for these components are provided in:Table 3.5.2-10Structural Commodity GroupSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-52 Section 2 -Scoping and Screening Methodology and Results2.4.11 Switchyard Structures Description The Switchyard Structures include the 345-kV switchyard, the switchyard relay house and theswitchyard maintenance building.
The Switchyard Structures support connection between theoffsite transmission network and the onsite distribution, including unit generators.
The 345-kVswitchyard 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, withreinforced concrete walls below grade supported on a reinforced concrete foundation slab onsoil. 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 slabon grade with reinforced concrete footings around the perimeter.
The Switchyard Structures are nonsafety-related.
The purpose of the Switchyard Structures isto provide physical
- support, shelter, and protection for Offsite Power System components, aswell as, serving as the electrical transmission terminals for each unit. The Offsite PowerSystem is relied upon to provide offsite power during plant shutdown and in the event of a siteemergency.
The foundations and supports for four breakers located in the Switchyard Structures are relied on to provide physical support and the switchyard relay house providesphysical support and shelter and protection for components relied upon to provide offsitepower during station blackout (SBO) and fire safe shutdown and are therefore, in scope forlicense 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 oflicense renewal are structural
- bolting, concrete, concrete
- anchors, concrete curbs andconcrete embedments, concrete foundations,
- hatches, plugs, masonry walls, and steelcomponents.
Switchyard Structures that provide structural
- support, shelter, and protection forthe Offsite Power System components are in scope for license renewal.
Other components and structures including the switchyard maintenance building and the wood lighting poles donot 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 completelist 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, firebarriers, the transmission and takeoff towers, and components and commodities which areevaluated 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. Thetransmission 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 riverscreen 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 areevaluated with their respective mechanical and electrical license renewal system orLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-53 Section 2 -Scoping and Screening Methodology and Resultscomponent 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 ofthe structure is safety-related or relied upon to remain functional during and following designbasis events. The Switchyard Structures are not in scope under 10 CFR 54.4(a)(2) becausefailure 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 FireProtection (10 CFR 50.48) and Station Blackout (10 CFR 50.63). The Switchyard Structures isnot relied upon in any safety analyses or plant evaluations to perform a function thatdemonstrates 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 CFR54.4(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 CFR54.4(a)(3)
UFSAR References 1.2.3.2.1 8.1.28.28.3Figure 8.1-1Figure 8.1-2Figure 8.1-3Appendix H, Fire Protection ReportLicense Renewal Boundary DrawingsLR-M-3LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-54 Section 2 -Scoping and Screening Methodology and ResultsTable 2.4-11Switchyard Structures Components Subject to Aging Management ReviewComponent Type Intended FunctionBolting (Structural)
Structural SupportConcrete Anchors Structural SupportConcrete Curbs Direct FlowConcrete Embedments Structural SupportConcrete:
Above-grade Exterior Structural Support(accessible areas)Concrete:
Below-grade Exterior
- Shelter, Protection (inaccessible areas) Structural SupportConcrete:
Foundation, Subfoundation Structural Support(inaccessible areas)Concrete:
Interior
- Shelter, Protection Structural SupportEquipment Supports and Foundations Structural SupportHatches/Plugs
- Shelter, Protection Structural SupportManholes, Handholes, and Duct Banks Shelter, Protection (Trough)Masonry Walls: Above-grade Exterior
- Shelter, Protection Structural SupportMasonry Walls: Interior
- Shelter, Protection Structural SupportSteel Components:
Structural Steel Structural SupportThe aging management review results for these components are provided in:Table 3.5.2-11Switchyard Structures Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-55 Section 2 -Scoping and Screening Methodology and Results2.4.12 Tank Foundations and DikesDescription Tank Foundations and Dikes consist of the cycled condensate storage tank foundations anddikes, clean condensate tank foundation, demineralized water tank foundation, well waterstorage tank foundation, and demineralizer regenerative solution tank foundation.
The Unit 1 and Unit 2 cycled condensate storage tank foundations and dikes are located onthe south-west side of the power block. The dike (also known as a berm) for each tank iscomposed of reinforced concrete with a liner system. The cycled condensate tanks aresupported by a circular reinforced concrete ring foundation pad. The remainder of the tankbottom is supported by a layer of clean sand on top of compacted structural backfill.
The dikeareas 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, andtherefore is not in scope for license renewal.
The Unit 1 and Unit 2 cycled condensate storagetanks are credited to support fire protection (fire safe shutdown),
and therefore theirfoundations perform an intended function and are in scope for license renewal.
The tank isseparated from safety-related
- systems, structures, and components such that its failure wouldnot 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 andis therefore in scope for license renewal.The well water storage tank for the domestic water system is located south-west of the powerblock. The tank is supported on a circular concrete ring foundation pad. The remainder of thetank bottom is supported by a layer of clean sand on top of compacted structural backfill.
Thetank is separated from safety-related
- systems, structures, and components such that its failurewould not impact a safety-related function.
The well water storage tank foundation does notperform 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 ofthe power block. The tank is supported on a circular concrete ring foundation pad. Theremainder 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, andcomponents 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 inscope of license renewal.The demineralizer regenerative solution tank is located south-west of the power block andconsists of a circular concrete ring foundation pad on grade. The remainder of the tank bottomis 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 impacta safety-related function.
The demineralizer regenerative storage tank foundation does notperform 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 ona circular concrete ring foundation pad. The remainder of the tank bottom is supported by alayer 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 2License Renewal Application Page 2.4-56 Section 2 -Scoping and Screening Methodology and Resultsrelated function.
The clean condensate tank foundation does not perform an intended functionand is therefore, not in scope of license renewal.The purpose of the Tank Foundation and Dikes is to provide structural
- support, shelter, andprotection for safety-related and nonsafety-related components and commodities including systems and components which support fire safe shutdown.
The purpose of the dikes aroundthe Cycled Condensate Tanks is for spill mitigation.
Included in the boundary of the Tank Foundation and Dikes and determined to be in scope arebolting, concrete
- anchors, concrete
- elements, and steel elements (valve enclosures) associated with the cycled condensate storage tanks. Other structures and components withinthe Tank Foundation and Dikes evaluation boundary do not perform a license renewalintended function and are not in scope for license renewal.Refer to "Components Subject to Aging Management Review" table for a complete list ofcomponents 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, areevaluated with the Component Supports Commodity Group. Other structural commodities, including insulation are evaluated with the Structural Commodity Group. In addition, the tanksand associated mechanical and electrical systems and components located in the vicinity ofthese tanks are evaluated with their respective mechanical and electrical license renewalsystem or component groups. Miscellaneous structures are evaluated within theMiscellaneous 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 noportions of the structure are safety-related and relied upon to remain functional during andfollowing design basis events. The Tank Foundations and Dikes is not in scope under 10 CFR54.4(a)(2) because failure of nonsafety-related portions of the structure would not preventsatisfactory accomplishment of function(s) identified for 10 CFR 54.4(a)(1).
The TankFoundations and Dikes also meets 10 CFR 54.4(a)(3) because it is relied upon in the safetyanalyses and plant evaluations to perform a function that demonstrates compliance with theCommission's regulations for Fire Protection (10 CFR 50.48). The Tank Foundations andDikes is not relied upon in any safety analyses or plant evaluations to perform a function thatdemonstrates 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 2License Renewal Application Page 2.4-57 Section 2 -Scoping and Screening Methodology and ResultsUFSAR References 1.2.2.3.10 3.1.2.4.6 Table 3.2-14.6.1.1.2.1 4.6.1.1.2.4.2.1 5.4.6.2.3 5.4.6.35.4.6.56.1.1.29.2.7.29.2.7.3License Renewal Boundary DrawingsLR-M-3Table 2.4-12Tank Foundations and DikesComponents Subject to Aging Management ReviewComponent Type Intended FunctionBolting Structural SupportConcrete Anchors Structural SupportConcrete:
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 DikesSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-58 Section 2 -Scoping and Screening Methodology and Results2.4.13 Turbine BuildingDescription The Turbine Building is divided into two units with a common operating floor. The TurbineBuilding is a steel framed and reinforced concrete structure enclosed with metal siding abovegrade. The structure is a part of the power generation complex which includes severalcontiguous buildings.
The Turbine Building is located west of the Auxiliary Building.
Theshear walls for the Reactor Building, Auxiliary
- Building, Turbine Building, Radwaste
- Building, Diesel Generator Buildings, and Off-gas Filter Building are interconnected.
These shear wallshave 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 gradefloor. 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 metalsiding. Structural steel columns support the Turbine Building crane and the roof. The two 210ton 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 isisolated from the turbine building floors above grade. The heater bay area, located on thewest side of the Turbine Building, is included within the boundary of the Turbine Building.
Theheater 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 ofthe heater bay area roof is poured concrete and the balance consists of galvanized metaldecking with insulation and built-up roofing.
Structural steel floor framing and grating isprovided around the heaters.The Turbine Building houses the turbine-generators, condensing equipment, moistureseparator-reheaters, and feedwater heaters.The Turbine Building superstructure is designed to withstand the tornado loads on theexposed structural frame so that collapse is prevented.
The turbine room siding and roofdecking 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 theother power generation complex shear walls and are Seismic Category I.The purpose of the Turbine Building is to provide structural
- support, shelter, and protection fornonsafety-related
- systems, structures, and components during normal plant operation andcertain safety-related system components during both normal operations and during andfollowing the SSE seismic event. The Turbine Building contains steam and power conversion systems components and the support systems and components necessary to support fireprotection, and station blackout.
Included in the boundary of the Turbine Building and determined to be within the scope oflicense renewal are the blowout panels, concrete
- anchors, concrete embedments, curbs,equipment supports and foundations,
- hatches, plugs, masonry walls, metal decking, metalsiding, 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 inLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-59 Section 2 -Scoping and Screening Methodology and Resultsits entirety except that architectural elements in the miscellaneous operational andmaintenance support areas that include furniture, drywall partitions and soffits, storageenclosures and suspended ceilings do not perform an intended function for license renewaland are not in scope.Refer to the "Components Subject to Aging Management Review" table below for a completelist 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 withthe Fire Protection System. Component
- supports, including their respective
- bolting, areevaluated 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 areevaluated 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 thestructure are safety-related and relied upon to remain functional during and following designbasis 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) becauseit is relied upon in the safety analyses and plant evaluations to perform a function thatdemonstrates compliance with the Commission's regulations for Fire Protection (10 CFR50.48), 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 afunction 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.
- 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).
- 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 2License Renewal Application Page 2.4-60 Section 2 -Scoping and Screening Methodology and Resultscompliance with the Commission's regulations for Fire Protection (10 CFR 50.48). 10 CFR54.4(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 CFR54.4(a)(3)
UFSAR References 1.11.2.2.2.c 2.4.12Figure 2.5-51Table 3.2-13.3.2.33.4.1.33.8.5.1.1 7.7.11.2.2 9.4.4.2.f 11.2.1.812.3.1.6.1 12.3.2.3Appendix J; J.4License Renewal Boundary DrawingsLR-M-3Table 2.4-13 Turbine BuildingComponents Subject to Aging Management ReviewComponent Type Intended FunctionBlowout Panels Pressure ReliefBolting (Structural)
Structural SupportConcrete Anchors Structural SupportConcrete Curbs Flood BarrierConcrete Embedments Structural SupportConcrete:
Above-grade Exterior Flood Barrier(accessible areas) Shelter, Protection Structural SupportConcrete:
Above-grade Exterior Flood Barrier(inaccessible areas) Shelter, Protection Structural SupportLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-61 Section 2 -Scoping and Screening Methodology and ResultsComponent TypeIntended FunctionConcrete:
Below-grade Exterior Flood Barrier(inaccessible areas) Shelter, Protection Structural SupportConcrete:
Foundation, Subfoundation Flood Barrier(inaccessible areas) Shelter, Protection Structural SupportConcrete:
Interior Flood BarrierShelter, Protection Shielding Structural SupportEquipment Supports and Foundations Structural SupportHatches/Plugs
- Shelter, Protection Shielding Structural SupportMasonry Walls: Above-grade Exterior
- Shelter, Protection Shielding Structural SupportMasonry Walls: Interior
- Shelter, Protection Shielding Structural SupportMetal Decking Shelter, Protection Structural SupportMetal Siding Pressure ReliefShelter, Protection Pipe Whip Restraints Pipe Whip Restraint Steel Components:
Structural Steel Structural SupportSteel Elements:
Liner, Liner Anchors, Water Retaining BoundaryIntegral Attachments (Sump Liner)The aging management review results for these components are provided in:Table 3.5.2-13 Turbine BuildingSummary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-62 Section 2 -Scoping and Screening Methodology and Results2.4.14 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 andsouth 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 normaland emergency plant operating conditions, and they provide power to equipment relied uponfor 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 buriedunderground with a reinforced concrete roof. These structures have a removable openingcover to allow for plant personnel access. Manholes, handholes, and valve pits serve asintermediate access point(s) for electrical, telephone or control cables and lines routed in theyard area and for access to valves for buried piping. The manholes, handholes and valve pitslocated in the yard area are nonsafety-related.
The handholes and valve pits do not performan 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 feedsfire pumps and associated equipment in the Lake Screen House are in scope for licenserenewal.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 banksare 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 theMCC supplying fire pumps and equipment located in the Lake Screen House are in scope forlicense 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 anintended function and are therefore, not in scope for license renewal.Transmission Towers:Transmission towers which include take-off towers, are metal structures supported byreinforced concrete foundations located in the yard. The transmission towers provide supportfor transmission conductors which connect LSCS to the switchyard and from the switchyard tooffsite substations.
Transmission towers provide essential power for normal plant, emergency operations, equipment relied upon for post fire safe shutdown, and for recovery from stationLaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-63 Section 2 -Scoping and Screening Methodology and Resultsblackout.
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 andprovide level support for the storage of outdoor fire hose and firefighting equipment.
Thesefoundations 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 intendedfunction and are therefore, not in scope of license renewal.Site Drainage System:The site drainage system includes drainage
- ditches, culverts and storm sewer systemconsisting of inlets and manholes.
The ditches, culverts and storm sewer drainage systemsare comprised of buried corrugated metal pipe or reinforced concrete pipe. It also contains atgrade reinforced concrete manholes or catch basins and oil interceptor pits and tanks. Thestorm water inlets are typically covered with grating to allow inflow of storm water. The oilinterceptor tanks within the oil interceptor pits are used to separate oily waste from wastewater prior to discharge.
The underground storm and waste drainage system is not reliedupon to prevent flooding at the plant. The site drainage system does not perform an intendedfunction 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 arenot uniquely tied to any structure.
These miscellaneous yard structures include roadways, sidewalks, and bollards and may include small storage structures.
The miscellaneous yardstructures also include the Independent spent fuel storage installation (ISFSI),
gas bottlestorage 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 aretherefore, not in scope for license renewal.The independent spent fuel storage installation (ISFSI) contains the spent fuel storage caskssupported on a reinforced concrete pad. The ISFSI is located in the northeast corner of theprotected area. The structure is separated from safety-related
- systems, structures, andcomponents such that its failure would not impact a safety-related function.
The ISFSI isseparately 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 ofthe 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 thehydrogen tank, nitrogen tanks and tube trailers.
The hydrogen storage area is located west ofthe power block and within the protected area. The structure is separated from safety-related LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-64 Section 2 -Scoping and Screening Methodology and Resultssystems, 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 locatedsouthwest of the power block and is approximately 400 feet tall. The meteorological towerconsists of a guy wire supported steel tower founded on a concrete foundation.
Theequipment enclosure is a commercial grade metal enclosure on a concrete foundation.
Thepurpose of the meteorological tower is to provide support,
- shelter, and protection for themeteorological instrumentation which is utilized to obtain data for both Unit 1 and Unit 2. Themeteorological 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 istherefore, not in the scope of license renewal.The purpose of the Yard Structures is to provide structural
- support, shelter, and protection fornonsafety-related components and commodities including components which supply power tosafety-related equipment during emergency plant operating conditions, and power toequipment relied upon for post fire safe shutdown or recovery from station blackout.
The yarddrainage system provides for collection and routing of ground water away from the powerblock.Included in the boundary of the Yard Structures are trenches, light poles, fire hose housefoundations,
- manholes, handholes valve pits, duct banks, transformer foundations, transmission towers, miscellaneous yard structures, meteorological tower, and the yarddrainage system. Included within the boundary of Yard Structures and determined to be inscope are bolting, concrete
- anchors, electrical manholes and duct banks, concrete foundations (system auxiliary transformer foundations and associated transmission and takeoff towerfoundations),
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 notperform 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 ofcomponents included in the boundary of the Yard Structures.
Not included in the boundary of the Yard Structures are component
- supports, tanks, tankfoundations 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, areevaluated with the Structural Commodity Group. In addition, mechanical and electrical systems and components housed in or located in the Yard Facility are evaluated with theirrespective mechanical and electrical license renewal system or component groups. Thetanks 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 2License Renewal Application Page 2.4-65 Section 2 -Scoping and Screening Methodology and Resultstowers 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 thestructures are safety-related or relied upon to remain functional during and following designbasis events. The Yard Structures is not in scope under 10 CFR 54.4(a)(2) because failure ofnonsafety-related portions of the structure would not prevent satisfactory accomplishment offunction(s) identified for 10 CFR 54.4(a)(1).
The Yard Structures also meets 10 CFR54.4(a)(3) because it is relied upon in the safety analyses and plant evaluations to perform afunction 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 uponin 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) andAnticipated 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 CFR54.4(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 CFR54.4(a)(3)
UFSAR References 1.2.3.6.1 2.4.2.42.4.43.1.2.6.2.2 Table 3.2-18.2Table 8.3-59.1.2.39.1.4.2.2 9.5.1.2.1 9.5.3.2.1 License Renewal Boundary DrawingsLR-M-3LaSalle County Station, Units 1 and 2 Page 2.4-66License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsTable 2.4-14Yard Structures Components Subject to Aging Management ReviewComponent Type Intended FunctionBolting (Structural)
Structural SupportConcrete Anchors Structural SupportConcrete:
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 SupportTransmission Towers (includes Take Off Structural SupportTowers)The aging management review results for these components are provided in:Table 3.5.2-14Yard Structures Summary of Aging Management Evaluation LaSalle County Station, Units 1 and 2License Renewal Application Page 2.4-67 This Page Intentionally Left Blank Section 2 -Scoping and Screening Methodology and Results2.5 SCOPING AND SCREENING RESULTS:
ELECTRICAL The determination of electrical systems that fall within the scope of license renewal is madethrough 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 groupsconsequently require an aging management review.As described in Subsection 2.1.6.1, the screening was performed on a commodity group basisfor the in scope electrical and I&C systems as well as the electrical and I&C component typesassociated 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 theComponent Supports Commodity Group in Section 2.4.2.2.5.1 ELECTRICAL SYSTEMSThe 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 andI&C systems and components, certain switchyard components are credited to restore offsitepower 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 andmechanical systems based on plant design documentation,
- drawings, and the Passportequipment
- 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. Thislist includes electrical components and commodities identified in NEI 95-10 Appendix B inaddition to components and commodities added per NUREG-1 800 Table 2.1-5.LaSalle County Station, Units 1 and 2 2.5-1License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsElectrical 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 2.5-2License Renewal Application Section 2 -Scoping and Screening Methodology and Results2.5.2.2 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 of10 CFR 54.21 (a)(1)(i) were applied to identify components and commodities that perform theirfunctions without moving parts or without a change in configuration or properties.
Thefollowing electrical commodities were determined to meet the screening criteria of10 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 intendedfunction:
Cable Tie WrapsTie wraps are used in cable installations as cable ties. Cable ties hold groups of cablestogether for restraint and ease of maintenance.
Cable ties are used to bundle wires andcables together to keep the wire and cable runs neat and orderly.
Cable ties are used torestrain wires and cables within raceways to facilitate cable installation.
There are no currentlicense basis requirements for LSCS that cable tie wraps remain functional during andfollowing design basis events. Cable ties are not credited for maintaining cable ampacity, ensuring maintenance of cable minimum bending radius, or maintaining cables within verticalraceways at LSCS. The seismic qualification of cable trays does not credit the use of cableties. Cable tie wraps are not credited in the LSCS design basis in terms of any 10 CFR 54.4intended function.
Therefore, cable tie wraps are not within the scope of license renewal andtherefore, are not subject to aging management review.Fuse Holders (Not Part of Active Equipment):
Metallic ClampsThe fuse holder commodity includes both the insulation portion of the fuse holder and themetallic clamp portion of the fuse holder. The insulation portion of the fuse holders wasscoped 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 ofActive Equipment):
Metallic Clamps commodity.
A systematic review was performed toLaSalle County Station, Units 1 and 2 2.5-3License Renewal Application Section 2 -Scoping and Screening Methodology and Resultsdetermine if there were metallic clamp portions of fuse holders that were in scope for LSCSlicense renewal.
The review used plant documents, controlled
- drawings, and the plantequipment 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):
MetallicClamps were either installed in active equipment, or did not perform a license renewalintended 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 agingmanagement 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.
Theydo not perform an intended function for license renewal.
Therefore, uninsulated groundconductors are not within the scope of license renewal and therefore, are not subject to agingmanagement 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 thatremained 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 thecriteria of 10 CFR 54.21 (a)(1)(ii) are electrical and I&C components and commodities includedin the Environmental Qualification (EQ) Program.
This is because electrical and I&Ccomponents and commodities included in the EQ Program have defined qualified lives and arereplaced prior to the expiration of their qualified lives. No electrical and I&C components andcommodities 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 2.5-4License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsO 2.5.2.5 Electrical Commodities Subject to Aging Management ReviewThe electrical commodities subject to aging management review are identified in Table2.5.2-1, along with the associated intended functions.
These electrical commodities arefurther described below.2.5.2.5.1 Cable Connections (Metallic Parts)The Cable Connectors (Metallic Parts) commodity includes metallic portions of cableconnections 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 of10 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 atime-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 ofelectrical penetration pigtails that could potentially be exposed to an adverse localized environment is included in the evaluation for Insulation Material for Electrical Cables andConnections, Section 2.5.2.5.4.
The shelter, protection and pressure boundary intendedfunctions 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 powerfrom the electric utility transmission system to plant buses. These circuits provide power to inscope license renewal components used for recovery from a station blackout event. HighVoltage 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 agingmanagement 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 CircuitsConductor Insulation for Inaccessible Power Cables Greater Than or Equal to 400Volts.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 2.5-5License Renewal Application Section 2 -Scoping and Screening Methodology and ResultsNumerous 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 of10 CFR 54.21 (a)(1)(ii).
Insulated cables and connections not included in the EQ Programmeet 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 leadsand connections, cables and connections internal to relays, chargers, switchgear, transformers, power supplies) are maintained along with the other subcomponents inside theenclosure and are not subject to an aging management review.2.5.2.5.5 Metal Enclosed BusThe metal enclosed buses distribute 4 kV power from the safeguard transformers and theemergency diesel generators to the 4 kV Class 1 E switchgear utilizing non-segregated buswork. The metal enclosed buses also provide crossties between units. These portions of thepower distribution system are in the scope of license renewal.
The metal enclosed busesdistribute electrical power to safety-related 4 kV switchgear during recovery from a stationblackout event. The metal enclosed buses are not in the EQ Program.
Therefore, metalenclosed bus meets the screening criterion of 10 CFR 54.21 (a)(1)(ii) and is subject to agingmanagement 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 powerfrom the utility transmission system to plant buses. These circuits provide power to in scopelicense renewal components used for recovery from a station blackout.
The Switchyard Busand Connections are not included in the EQ program.
Therefore, Switchyard Bus andConnections meet the screening criterion of 10 CFR 54.21 (a)(1)(ii) and are subject to an agingmanagement review.The Transmission Conductors and Connectors are part of the switchyard circuits that supplypower from the electric transmission system to plant buses. These circuits provide power to inscope license renewal components used for recovery from a station blackout.
TheTransmission Conductors and Connectors are not included in the EQ program.
Therefore, Transmission Conductors and Connectors meet the screening criterion of 10 CFR54.21 (a)(1)(ii) and are subject to an aging management review.LaSalle County Station, Units 1 and 2 2.5-6License Renewal Application Section 2 -Scoping and Screening Methodology and Results.Table 2.5.2-1Electrical Commodities Subject to Aging Management ReviewCommodity Intended FunctionCable 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, andTransmission Connectors The aging management review results for these commodities are provided in Table 3.6.2-1Electrical Commodities
-Summary of Aging Management Evaluation.
LaSalle County Station, Units 1 and 2License Renewal Application 2.5-7 This Page Intentionally Left Blank Section 3 -Aging Management Review Results3.0 AGING MANAGEMENT REVIEW RESULTSThis 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 theLaSalle Aging Management Review results to the NUREG-1801 results.Most of the Aging Management Review (AMR) results information in Section 3 ispresented in the following two tables:* Table 3.x.1 -where '3' indicates the LRA section number, 'x' indicates thesubsection number from NUREG-1 800, and '1' indicates that this is the first tabletype in Section 3. For example, in the Reactor Vessel, Internals, and ReactorCoolant 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 ofdiscussion, 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 thesubsection number from NUREG-1 800, and '2' indicates that this is the second tabletype in Section 3; and 'y' indicates the table number for a specific system. Forexample, for the Reactor Vessel, within the Reactor Vessel, Internals, and ReactorCoolant System subsection, this table would be 3.1.2-2 and for the Reactor VesselInternals, 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 ofdiscussion, 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 genericevaluation of existing plant programs.
It documents the technical basis for determining where existing programs are adequate without modification, and where existingprograms should be augmented for the extended period of operation.
The evaluation results documented in NUREG-1 801 indicate that many of the existing programs areadequate to manage the aging effects for particular structures or components, within thescope of license renewal, without change. NUREG-1801 also containsrecommendations 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 IThe purpose of Table 1 is to provide a summary comparison of how the facility alignswith the corresponding tables of NUREG-1800.
The table is essentially the same asLaSalle County Station, Units 1 and 2 Page 3.0-1License Renewal Application Section 3 -Aging Management Review ResultsTables 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 fromTable 2 to Table 1.The "Discussion" column is used to provide clarifying or amplifying information.
Thefollowing are examples of information that might be contained within this column:" "Further Evaluation Recommended" information or reference to where thatinformation 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 inNUREG-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 anaging 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 1row with the corresponding NUREG-1 800 table row, thereby allowing for the ease ofchecking consistency.
Table 2Table 2 provides the detailed results of the aging management reviews for thosecomponents 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.
Forexample, for LaSalle, the Engineered Safety Features System Group contains table'sspecific 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 ItemLaSalle County Station, Units 1 and 2License Renewal Application Page 3.0-2 Section 3 -Aging Management Review Results* NotesComponent Type -The first column identifies all of the component types from Section2 of the LRA that are subject to aging management review. They are listed inalphabetical order.Intended Function
-The second column contains the license renewal intendedfunctions 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 thecomponent type.Environment
-The fourth column lists the environments to which the component typesare exposed.
Service environments are indicated and a list of these environments isprovided in Table 3.0-1.Aging Effect Requiring Management
-As part of the aging management reviewprocess, the aging effects that are required to be managed in order to maintain theintended 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 managethe aging effects requiring management are listed in the sixth column of Table 2. Agingmanagement programs are described in Appendix B.NUREG-1801 Item -Each combination of component type, material, environment, agingeffect 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 identifyconsistency.
Consistency is documented by noting the appropriate NUREG-1801 itemnumber in the seventh column of Table 2. If there is no corresponding item number inNUREG-1 801, this field in column seven is left blank. Thus, a reviewer can readilyidentify the correlation between the plant-specific tables and the NUREG-1 801 tables.Table 1 Item -Each combination of component,
- material, environment, aging effectrequiring 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. Thecorresponding line item from Table 1 is listed in the eighth column of Table 2. If there isno corresponding item in NUREG-1 801, this field in column eight is left blank. The Table1 Item allows correlation of the information from the two tables.Notes -The notes provided in each Table 2 describe how the information in the tablealigns with the information in NUREG-1 801. Each Table 2 contains standard letterednotes 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 801Aging Management Table line item identified in the seventh column. In addition to thestandard lettered notes, numbered plant-specific notes provide additional clarifying information when appropriate.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.0-3 Section 3 -Aging Management Review ResultsTABLE USAGETable 1The 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 FurtherEvaluation Recommended information is taken directly from NUREG-1800, no furtheranalysis of those columns is required.
The information intended to help the reviewer themost in this table is contained within the Discussion column. Here the reviewer will begiven plant-specific information necessary to determine, in summary, how the LaSalleevaluations and programs align with NUREG-1800.
This may be in the form ofdescriptive information within the Discussion column, or the reviewer may be referred toother locations within the LRA for further information.
Table 2Table 2 contains all of the Aging Management Review information for the plant, whetheror not it aligns with NUREG-1 801. For a given row within the table, the reviewer is ableto see the intended
- function, material, environment, aging effect requiring management and aging management program combination for a particular component type within asystem. In addition, if there is a correlation between the combination in Table 2 and acombination in NUREG-1801, this will be identified by a referenced item number incolumn seven, NUREG-1 801 Item. The reviewer can refer to the item number inNUREG-1 801, if desired, to verify the correlation.
If the column is blank, nocorresponding 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 1Item. If there is a reference number in this column, the reviewer is able to use thatreference number to locate the corresponding row in Table 1 and see how the agingmanagement program for this particular combination aligns with NUREG-1801.
Table 2 provides the reviewer with a means to navigate from the components subject toAging 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 2A fatigue analysis is considered to be a time-limited aging analysis (TLAA) as defined in10 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 tobe evaluated in accordance with 10 CFR 54.21 (c)(1).Table 1 and Table 2 include an entry in the Aging Management Program columnindicating "TLAA" for each line item that has a component for which a fatigue TLAA hasbeen identified.
See LRA Section 4.3 for details regarding the LSCS fatigue designbases, fatigue TLAAs identified, and TLAA evaluations for the period of extendedoperation.
LaSalle County Station, Units 1 and 2 Page 3.0-4License Renewal Application Section 3 -Aging Management Review ResultsTable 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, orEnvironment
- moisture, or voltage, sometimes in the presence moistureof oxygen. The effect can be concentrated or Adverse localized environment applicable to a general plant area. caused by heat, radiation, oxygen, moisture, or voltageAdverse localized environment caused by significant moistureAir -Indoor, The Air -Indoor, Controlled environment is one Air -indoor, controlled orControlled in which the specified internal or external surface Uncontrolled of the component or structure is exposed to a Air -indoor, controlled orhumidity-controlled (i.e., air conditioned)
Airo-tindoorrcontroloed dorenvironment.
For electrical
- purposes, controlmust be sufficient to eliminate the cited agingeffects of contamination and oxidation withoutaffecting the resistance.
Air -Indoor, The Air -Indoor Uncontrolled environment is for AirUncontrolled 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);
outdoorequipment and surfaces are normally dry. Air -indoor, uncontrolled or Air -outdoor or Ground water/soil System temperature up to 288°C(550°F)Any environment VariousLaSalle County Station, Units 1 and 2License Renewal Application Page 3.0-5 Section 3 -Aging Management Review ResultsLaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Air -Outdoor The Air -Outdoor environment includes Air -outdooratmospheric air with ambient temperatures and a Air -indoor, uncontrolled or Air -relative humidity up to 100%. This environment outdoormay 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 orstandingCondensation, air-outdoor Soil or Concrete, or the following external environments:
air-outdoor, air-indoor uncontrolled, Any environment VariousAir with Reactor The Air with Reactor Coolant Leakage Air with reactor coolant leakageCoolant Leakage environment is applicable to closure bolting only Airwhich is located in the vicinity of the RPV. TheAir with reactor coolant or steam leakage Air with steam or water leakageenvironment is a high temperature leakage System temperature up to 2880Cenvironment.
(5500FAir/Gas-Dry The Air/Gas-Dry environment includes air with a Air -dryvery limited percentage of moisture present thathas been treated to reduce the dewpoint wellbelow the system operating temperature.
Thisincludes air within air-conditioned spaces and italso includes commercial grade gases (such asnitrogen, freon, etc.) that are provided as a highquality product with little if any externalcontaminants (bottled gas).This environment does not include air withinpiping systems downstream of dryers becausethese dryers require a program to assure theyremain functional.
For these systems, theCondensation environment is used.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.0-6 Section 3 -Aging Management Review ResultsLaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Closed Cycle Closed Cycle Cooling Water includes treated Closed-cycle cooling waterCooling Water water subject to the Closed Treated WaterSystems program, which is Aging Management Program XI.M21A in NUREG-1801.
The ClosedTreated Water Systems program relies onmaintenance of system corrosion inhibitor concentrations within specified limits of ElectricPower Research Institute TR-107396 andTechnical Report 1007820 to minimize corrosion.
Demineralized water is treated with corrosion inhibitors, pH control agents, or biocides, asneeded.Closed Cycle The Closed Cycle Cooling Water >140°F Closed-cycle cooling waterCooling Water environment is the same as the Closed Cycle>140°F Cooling Water environment, except the Closed Closed-cycle cooling water >60°CCycle Cooling Water >140°F environment is (>1400F)used for components with an operating temperature
>140°F that are constructed ofstainless steel.Concrete The Concrete environment is one where Concretecomponents are embedded in concrete.
This Soil or concreteenvironment is considered aggressive if theconcrete pH <11.5 or chlorides concentration
>500 ppm.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.0-7 Section 3 -Aging Management Review ResultsLaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Condensation The Condensation environment is an air Condensation environment containing warm or moist air wherecondensation 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, moistfor most common materials.
Although air condensation, raw water,condensation may occur, it is not expected to be ated watersignificant enough to result in ponding and treated waterpooling 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 airdrawn inside ventilation systems and air spaceswithin tanks. Certain components reside insidelarger components such that their externalsurfaces are exposed to the internal environment of the larger component (e.g., tubes in aircoolers).
For these situations, Condensation isdesignated as the external environment.
The Condensation environment is also used forcertain insulated components.
Because of air in-leakage through minor gaps in insulation, condensation can occur underneath theinsulation on components when the operating temperature of the component is below the dewpoint of the air on the external surfaces of theinsulation.
Diesel Exhaust The Diesel Exhaust environment represents the Diesel Exhaustexhaust from diesel engines.
It is considered tohave 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 inenvironments that promote age-related NUREG-1801 degradation.
Concrete which is totally enclosed and contained within the inner, outer, sleeve, and cover steelplates of the Reactor Shield is an example ofwhere the "encased in steel" environment isapplied.
The concrete which is encased in steelis protected from other environments thatpromote age-related degradation.
SLaSalle County Station, Units 1 and 2License Renewal Application Page 3.0-8 Section 3 -Aging Management Review ResultsLaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Fuel Oil The Fuel Oil environment includes fuel oil for the Fuel oilemergency diesel generators, diesel-driven auxiliary feedwater pumps, diesel-driven firepumps, etc. Water contamination of fuel oil isassumed.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.SoilAny environment VariousLubricating Oil Lubricating oils are low to medium viscosity Lubricating oilhydrocarbons used for bearing, gear, and enginelubrication; also functionally encompasses hydraulic oil (non water based). Watercontamination of lubricating oil is assumed.Raw Water The cooling lake and river water to the cooling Raw waterlake, as well as ground water from wells, provide Raw water, waste waterthe sources of raw water utilized by LSCS. Rawwater 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, moistto any significant extent. This can include water air, condensation, raw water,for use in open-cycle cooling water and fire treated waterprotection systems.
Potable water, water that isused for drinking or other personal use, is Any environment considered raw water. Raw water in plantsystems may have been rough filtered to removelarge particles and may contain a biocide additivefor control of micro- and macro-organisms.
Reactor Coolant The Reactor Coolant environment is Reactor coolantdemineralized water used within the reactorcoolant system to transfer heat from the fuelinside the reactor vessel core. The Reactor Reactor coolant >2500C (>4820F)Coolant environment also includes Steam. The and neutron fluxtemperature of the Reactor Coolant environment Reactor coolant and neutron fluxis assumed to be >482 'F. The Reactor Coolantenvironment has been selected for the following systems for consistency with the NUREG-1 801terminology:
Reactor Vessel, Reactor VesselInternals, and Reactor Coolant PressureBoundary System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.0-9 Section 3 -Aging Management Review ResultsLaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Reactor Coolant The Reactor Coolant and Neutron Flux Reactor coolantand Neutron Flux environment is used for components within the Reactor coolant >2500C (>4820F)reactor vessel and reactor vessel internals systems that are in contact with reactor coolantand are exposed to neutron fluence projected to Reactor coolant and neutron fluxexceed 1.0 x 1017 n/cm2 (E >0.1 MeV) within 60years. The temperature of the Reactor Coolantand Neutron Flux environment is alwaysassumed to be >482°F.Sodium The Sodium Pentaborate Solution environment is Sodium Pentaborate solutionPentaborate treated water that contains sodium pentaborate.
Solution This is confined to the Standby Liquid Controlsystem at LaSalle which is contained within alimited area of the secondary containment.
Soil The Soil environment is the external environment Soilfor components buried in the soil, and it includes Soil or concreteground water in the soil.Steam The Steam environment is the internal Steamenvironment associated with dry steam, such as Steam or Treated watermain steam up to the main turbine.
The WaterChemistry Program is used for managing aging Reactor coolanteffects in dry steam environments, but the One-Time Inspection Program is not required byNUREG-1 801.Wet steam environments for LSCS are typically described as either Treated Water or ReactorCoolant, depending upon location, but may usethe NUREG-1 801 steam environment forcumulative fatigue damage or loss of materialaging effects.Treated Water Treated water is demineralized water or Treated waterchemically purified water and is the base water Treated water or Treated boratedfor all clean systems.
Depending on the system, watertreated water may require further processing.
Treated water may be deaerated and include Treated water <60C (<140 F)corrosion inhibitors,
- biocides, or somecombination of these treatments.
The treated Steam or Treated waterwater environment includes all wet steam Air -indoor, uncontrolled orenvironments.
Treated waterAir -indoor, uncontrolled or Air -outdoor'Any environment SLaSalle County Station, Units 1 and 2License Renewal Application Page 3.0-10 Section 3 -Aging Management Review ResultsLaSalle AMR Description NUREG-1801 Environments Environment Used For AMR Comparison Treated Water The Treated Water >1400F environment is the Treated water >600C (>1400F)>140°F same as the Treated Water environment, except Treated waterthe Treated Water >140°F environment is usedfor systems operating at temperatures
>140°Fthat are constructed of stainless steel. Formaterials other than stainless steel, the TreatedWater environment is used. The Treated Water>140°F environment includes wet steam. Drysteam, such as main steam, is addressed as itsown environment.
Waste Water Waste Water includes radioactive, potentially Waste waterradioactive, or non-radioactive waters that arecollected from equipment and floor drains, vent Raw water, Waste watersystem drains, and waters processed by theradwaste system. Waste water may containcontaminants, including oil and boric acid,depending on location, as well as originally treated water that is not monitored by achemistry program.Water -Flowing The Water -Flowing environment is water that is Water -flowingrefreshed, thus having larger impact on leaching; Watthis can be raw water, groundwater, groundwater er- flowing or standingintrusion, or flowing water under a foundation.
Air -indoor, uncontrolled or Air -outdoor or Water -flowing orstandingAny environment Water -Standing The Water -Standing environment is water that Water -flowing or standingis stagnant and unrefreshed, thus possibly Air -indoor, uncontrolled or Air -resulting in increased ionic strength of solution Aridoor uncontrolled orup to saturation.
This can be raw water or otdo a wgroundwater.
- 1. This environmental alignment is only utilized for TLAA related line items.Differences between the NUREG-1 801 environment and the LSCS AMRenvironment do not affect aging management of the cumulative fatigue damageaging effect for the applicable components.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.0-11 This Page Intentionally Left Blank Section 3 -Aging Management Review Results3.1 AGING MANAGEMENT OF REACTOR VESSEL, INTERNALS.
AND REACTORCOOLANT SYSTEM3.
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, asbeing subject to aging management review. The systems, or portions of systems, whichare 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 RESULTSThe following tables summarize the results of the aging management review for theReactor Vessel, Internals, and Reactor Coolant System:Table 3.1.2-1 Reactor Coolant Pressure Boundary System -Summary of AgingManagement 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 AgingManagement Programs3.1.2.1.1 Reactor Coolant Pressure Boundary SystemMaterials The materials of construction for the Reactor Coolant Pressure Boundary Systemcomponents 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 IronLaSalle County Station, Units 1 and 2 Page 3.1-1License 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 BoltingEnvironments The Reactor Coolant Pressure Boundary System components are exposed to thefollowing 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 WaterAging Effects Requiring Management The following aging effects associated with the Reactor Coolant Pressure BoundarySystem components require management:
- Cracking* Cumulative Fatigue Damage* Loss of Fracture Toughness
- Loss of Material* Loss of Preload* Wall ThinningAging Management ProgramsThe following aging management programs manage the aging effects for the ReactorCoolant 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 2License 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 VesselMaterials 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 SteelEnvironments 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 WaterAging Effects Requiring Management The following aging effects associated with the Reactor Vessel components requiremanagement:
- CrackingLaSalle County Station, Units 1 and 2 Page 3.1-3License Renewal Application Section 3 -Aging Management Review Results* Cumulative Fatigue Damage* Loss of Fracture Toughness
- Loss of Material* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the ReactorVessel 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 Penetrations (B.2.1.8)
- BWR Stress Corrosion Cracking (B.2.1.7)
" 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 alloyLaSalle County Station, Units 1 and 2 Page 3.1-4License Renewal Application Section 3 -Aging Management Review ResultsEnvironments The Reactor Vessel Internals components are exposed to the following environments:
- Air/Gas -Dry" Reactor Coolant* Reactor Coolant and Neutron FluxAging 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 PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the ReactorVessel Internals components:
- BWR Vessel Internals (B.2.1.9)
- TLAA* Water Chemistry (B.2.1.2)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-5 Section 3 -Aging Management Review Results3.1.2.2 AMR Results for Which Further Evaluation is Recommended by the GALLReportNUREG-1801 provides the basis for identifying those programs that warrant furtherevaluation by the reviewer in the license renewal application.
For the ReactorVessel, Internals, and Reactor Coolant System, those programs are addressed inthe following subsections.
3.1.2.2.1 Cumulative Fatigue DamageFatigue is a time-limited aging analysis (TLAA) as defined in 10 CFR 54.3. TLAAsare 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, andReactor 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 thesteel PWR steam generator upper and lower shell and transition cone exposedto secondary feedwater and steam. The existing program relies on control ofwater chemistry to mitigate corrosion and Inservice Inspection (ISI) to detectloss of material.
The extent and schedule of the existing steam generator inspections are designed to ensure that flaws cannot attain a depth sufficient tothreaten the integrity of the welds. However, according to NRC Information Notice (IN) 90-04, the program may not be sufficient to detect pitting andcrevice corrosion, if general and pitting corrosion of the shell is known to exist.The GALL Report recommends augmented inspection to manage this agingeffect. Furthermore, the GALL Report clarifies that this issue is limited toWestinghouse Model 44 and 51 Steam Generators, where a high-stress regionexists at the shell to transition cone weld. Acceptance criteria are described inBranch 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 thesteel PWR steam generator shell assembly exposed to secondary feedwater and steam. The existing program relies on control of secondary waterchemistry to mitigate corrosion.
- However, some applicants have replaced onlythe bottom part of their recirculating steam generators, generating a cut in themiddle of the transition cone, and, consequently, a new transition cone closureweld. The GALL Report recommends volumetric examinations performed inaccordance with the requirements of ASME Code Section X1 for upper shell-toand lower shell-to transition cones with gross structural discontinuities formanaging loss of material due to general,
- pitting, and crevice corrosion in thewelds 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 coneLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-6 Section 3 -Aging Management Review Resultswelds containing geometric discontinuities.
Control of water chemistry doesnot preclude loss of material due to pitting and crevice corrosion at locations ofstagnant flow conditions.
The new transition area weld is a field-weld asopposed to having been made in a controlled manufacturing
- facility, and thesurface conditions of the transition weld may result in flow conditions moreconducive to initiation of general,
- pitting, and crevice corrosion than those ofthe upper and lower transition cone welds. Crediting of the ISI program for thenew SG transition cone weld may not be an effective basis for managing lossof material in this weld, as the ISI criteria would only perform a VT-2 visualleakage examination of the weld as part of the system leakage test performed pursuant to ASME Section X1 requirements.
In addition, ASME Section Xldoes not require licensees to remove insulation when performing visualexamination on non-borated treated water systems.
Therefore, theeffectiveness of the chemistry control program should be verified to ensure thatloss 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 todetermine whether an aging effect is not occurring or an aging effect isprogressing very slowly, such that the component's intended function will bemaintained during the period of extended operation.
Furthermore, the GALLReport clarifies that this issue is limited to replacement recirculating steamgenerators 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 ofextended operation for all ferritic materials that have a neutron fluence greaterthan 1017 n/cm2 (E >1 MeV) at the end of the license renewal term. Certainaspects of neutron irradiation embrittlement are TLAAs as defined in 10 CFR54.3. TLAAs are required to be evaluated in accordance with 10 CFR54.21(c)(1).
This TLAA is addressed separately in Section 4.2, "ReactorVessel Neutron Embrittlement Analysis,"
of this SRP-LR.The evaluation of neutron irradiation embrittlement for all ferritic reactor vesselcomponents that have a neutron fluence greater than 1 x 10 17 n/cm2 (E>1 MeV) atthe end of the license renewal term is performed as a TLAA as discussed inSection 4.2.2. Loss of fracture toughness due to neutron irradiation embrittlement could occurin BWR and PWR reactor vessel beltline shell, nozzle, and welds exposed toreactor coolant and neutron flux. A reactor vessel materials surveillance program monitors neutron irradiation embrittlement of the reactor vessel. Thereactor vessel surveillance program is plant-specific, depending on matterssuch 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 2License Renewal Application Page 3.1-7 Section 3 -Aging Management Review Resultsschedule for approval prior to implementation.
Untested capsules placed instorage 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 beimplemented to manage the loss of fracture toughness of the reactor vesselbeltline components and welds exposed to a reactor coolant and neutron fluxenvironment.
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 thedevelopment of pressure-temperature limit curves. Embrittlement evaluations areperformed in accordance with Regulatory Guide 1.99, Rev. 2. The schedule forremoving surveillance capsules is in accordance the timetable specified inBWRVIP-86-A for the current license term and in accordance with BWRVIP-1 16 forthe period of extended operation.
- 3. Ductility
-Reduction in Fracture Toughness is a plant-specific TLAA forBabcock and Wilcox (B&W) reactor internals to be evaluated for the period ofextended operation in accordance with the staff's safety evaluation concerning "Demonstration of the Management of Aging Effects for the Reactor VesselInternals,"
Babcock and Wilcox Owners Group report number BAW-2248, which is included in BAW-2248A, March 2000. Plant-specific TLAAs areaddressed 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 StressCorrosion Cracking1. Cracking due to stress corrosion cracking (SCC) and intergranular stresscorrosion cracking (IGSCC) could occur in the stainless steel and nickel alloyBWR top head enclosure vessel flange leak detection lines. The GALL Reportrecommends that a plant-specific AMP be evaluated because existingprograms may not be capable of mitigating or detecting cracking due to SCCand IGSCC. Acceptance criteria are described in Branch Technical PositionRLSB- 1 (Appendix A. 1 of this SRP-LR).Item Number 3.1.1-16 is not used. The top head enclosure vessel flange leakdetection line is carbon steel piping and is therefore not susceptible to stresscorrosion 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 programrelies on control of reactor water chemistry to mitigate SCC and on ASMESection X1 ISI to detect cracking.
- However, the existing program should beaugmented to detect cracking due to SCC and IGSCC. The GALL Reportrecommends an augmented program to include temperature and radioactivity LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-8 Section 3 -Aging Management Review Resultsmonitoring of the shell-side water and eddy current testing of tubes to ensurethat the component's intended function will be maintained during the period ofextended 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 includean isolation condenser.
3.1.2.2.5 Crack Growth due to Cyclic LoadingCrack growth due to cyclic loading could occur in reactor vessel shell forgings cladwith stainless steel using a high-heat-input welding process.
Growth ofintergranular separations (underclad cracks) in the heat-affected zone underaustenitic stainless steel cladding is a TLAA to be evaluated for the period ofextended operation for all the SA-508-CI-2 forgings where the cladding wasdeposited with a high heat input welding process.
The methodology for evaluating the underclad flaw should be consistent with the flaw evaluation procedure andcriterion in the ASME Section X1 Code, 2004 edition'.
See the SRP-LR, Section4.7, "Other Plant-Specific Time-Limited Aging Analysis,
" for generic guidance formeeting 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 Cracking1. Cracking due to SCC could occur in the PWR stainless steel reactor vesselflange leak detection lines and bottom-mounted instrument guide tubesexposed to reactor coolant.
The GALL Report recommends further evaluation to ensure that these aging effects are adequately managed.
The GALL Reportrecommends that a plant-specific AMP be evaluated to ensure that this agingeffect is adequately managed.
Acceptance criteria are described in BranchTechnical 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 pipingelements exposed to reactor coolant.
The existing program relies on control ofwater chemistry to mitigate SCC; however, SCC could occur for CASScomponents that do not meet the NUREG-0313 guidelines with regard to ferriteand carbon content.
The GALL Report recommends further evaluation of aplant-specific program for these components to ensure that this aging effect isadequately 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 2License Renewal Application Page 3.1-9 Section 3 -Aging Management Review Results3.1.2.2.7 Cracking due to Cyclic LoadingCracking due to cyclic loading could occur in steel and stainless steel BWRisolation condenser components exposed to reactor coolant.
The existing programrelies on ASME Section X1 ISI. However, the existing program should beaugmented to detect cracking due to cyclic loading.
The GALL Reportrecommends an augmented program to include temperature and radioactivity monitoring of the shell-side water and eddy current testing of tubes to ensure thatthe component's intended function will be maintained during the period of extendedoperation.
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 includean isolation condenser.
3.1.2.2.8 Loss of Material due to ErosionLoss of material due to erosion could occur in steel steam generator feedwater impingement plates and supports exposed to secondary feedwater.
The GALLReport recommends further evaluation of a plant-specific AMP to ensure that thisaging effect is adequately managed.
Acceptance criteria are described in BranchTechnical 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 CoolantSystem is addressed in Item Number 3.1.1-110.
3.1.2.2.9 Cracking due to Stress Corrosion Cracking and Irradiation-Assisted StressCorrosion CrackingCracking due to SCC and irradiation-assisted stress corrosion cracking (IASCC)could occur in inaccessible locations for stainless steel and nickel-alloy Primaryand Expansion PWR reactor vessel internal components.
If aging effects areidentified in accessible locations, the GALL Report recommends further evaluation of the aging effects in inaccessible locations on a plant-specific basis to ensure thatthis aging effect is adequately managed.
Acceptance criteria are described inBranch 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 StressRelaxation, or Loss of Material due to WearLoss of fracture toughness due to neutron irradiation embrittlement, change indimension due to void swelling, loss of preload due to stress relaxation, or loss ofmaterial due to wear could occur in inaccessible locations for stainless steel andnickel-alloy Primary and Expansion PWR reactor vessel internal components.
Ifaging effects are identified in accessible locations, the GALL Report recommends LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-10 Section 3 -Aging Management Review Resultsfurther evaluation of the aging effects in inaccessible locations on a plant-specific basis to ensure that this aging effect is adequately managed.
Acceptance criteriaare 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 Cracking1. Foreign operating experience in steam generators with a similar design to thatof Westinghouse Model 51 has identified extensive cracking due to primarywater stress corrosion cracking (PWSCC) in steam generator (SG) divider plateassemblies fabricated of Alloy 600 and/or the associated Alloy 600 weldmaterials, 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 theaging effect of cracking due to PWSCC in SG divider plate assemblies.
This isof particular concern for steam generators where the tube-tubesheet welds areconsidered structural welds and/or where the divider plate assemblycontributes to the mechanical integrity of the tubesheet.
Although these SG divider plate cracks may not have a significant safetyimpact in and of themselves, these cracks could impact adjacent items, suchas the tubesheet and the channel head, if they propagate to the boundary withthese items. For the tubesheet, PWSCC cracks in the divider plate couldpropagate to the tubesheet cladding with possible consequences to theintegrity of the tube/tubesheet welds. For the channel head, the PWSCCcracks 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 mitigatecracking due to PWSCC. The GALL Report recommends that a plant-specific AMP be evaluated, along with the primary water chemistry
- program, becausethe existing primary water chemistry program may not be capable of mitigating cracking due to PWSCC. Acceptance criteria are described in BranchTechnical 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 aredefinition of the pressure boundary in which the tube-to-tubesheet weld is nolonger included, the effectiveness of the primary water chemistry programshould be verified to ensure cracking is not occurring:
For plants with Alloy 600 steam generator tubes that have not beenthermally 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 theLaSalle County Station, Units 1 and 2 Page 3.1-11License Renewal Application Section 3 -Aging Management Review Resultspressure boundary and no plant specific aging management program isrequired; For plants with Alloy 600 steam generator tubes that have not beenthermally treated and for which there is no permanently approvedalternate repair criteria such as C*, F* or W*, a plant-specific AMP isrequired; For plants with Alloy 600TT steam generator tubes and for which analternate repair criteria such as H* has been permanently
- approved, theweld is no longer part of the pressure boundary and no plant specificaging management program is required; For plants with Alloy 600TT steam generator tubes and for which there isno alternate repair criteria such as H* permanently
- approved, a plant-specific AMP is required; For plants with Alloy 690TT steam generator tubes with Alloy 690tubesheet
- cladding, the water chemistry is sufficient, and no further actionor plant-specific aging management program is required; For plants with Alloy 690TT steam generator tubes and with Alloy 600tubesheet
- cladding, either a plant-specific program or a rationale for whysuch a program is not needed is required.
The existing program relies on control of reactor water chemistry to mitigatecracking due to PWSCC. The GALL Report recommends that a plant-specific AMP be evaluated, along with the primary water chemistry
- program, becausethe existing primary water chemistry program may not be capable of mitigating cracking due to PWSCC. Acceptance criteria are described in BranchTechnical 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 FatigueEPRI 1016596, Materials Reliability Program:
Pressurized Water Reactor Internals Inspection and Evaluation Guidelines (MRP-227-Rev.
- 0) identifies cracking due tofatigue as an aging effect that can occur for the lower flange weld in the coresupport barrel assembly, fuel alignment plate in the upper internals
- assembly, andcore support plate lower support structure in PWR internals designed byCombustion Engineering.
The GALL Report recommends that inspection forcracking in this component be performed if acceptable fatigue life cannot bedemonstrated by TLAA through the period of extended operation as defined in 10CFR 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 FatigueCracking due to stress corrosion cracking and fatigue could occur in nickel alloycontrol rod guide tube assemblies, guide tube support pins exposed to reactorLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-12 Section 3 -Aging Management Review Resultscoolant, and neutron flux. The GALL Report, AMR Item IV.B2.RP-355, recommends further evaluation of a plant-specific AMP to ensure this aging effectis 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 WearLoss of material due to wear could occur in nickel alloy control rod guide tubeassemblies, guide tube support pins and in Zircaloy-4 incore instrumentation lowerthimble 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 aplant-specific AMP to ensure this aging effect is adequately managed.
Acceptance criteria are described in Branch Technical Position RLSB- I (Appendix A. 1 of thisSRP-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. 1.6and Appendix B, Section B.1.4.LaSalle County Station, Units 1 and 2 Page 3.1-13License Renewal Application Section 3 -Aging Management Review Results3.1.2.3 Time-Limited Aging AnalysisThe time-limited aging analyses identified below are associated with the ReactorVessel, 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 PreloadAnalysis* 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 Analyses0 Section 4.7.2, Main Steam Line Flow Restrictors Erosion Analysis3.
1.3 CONCLUSION
The Reactor Vessel, Internals, and Reactor Coolant System piping fittings, andcomponents that are subject to aging management review have been identified inaccordance with the requirements of 10 CFR 54.4. The aging management programs selected to manage aging effects for the Reactor Vessel, Internals, andReactor Coolant System components are identified in the summaries in Section3.1.2.1 above.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-14 Section 3 -Aging Management Review ResultsA description of these aging management programs is provided in Appendix B,along with the demonstration that the identified aging effects will be managed forthe period of extended operation.
Therefore, based on the conclusions provided in Appendix B, the effects of agingassociated with the Reactor Vessel, Internals, and Reactor Coolant Systemcomponents 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 2License Renewal Application Page 3.1-15 This Page Intentionally Left Blank O O Section 3 -Aging Managerne eew ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 issteel 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 4.3reactor coolant leakage "Metal Fatigue,"
foracceptable methods tocomply with 10 CFR54.21 (c)(1))3.1.1-2 PWR only3.1.1-3 Stainless steel or nickel Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation isalloy 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 4.3coolant and neutron flux "Metal Fatigue,"
foracceptable methods tocomply with 10 CFR54.21 (c)(1))3.1.1-4 Steel pressure vessel Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation issupport 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,"
foracceptable methods tocomply with 10 CFR54.21 (c)(1))LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-16 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-5 PWR only3.1.1-6 Steel (with or without Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation isnickel-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 1alloy reactor coolant components pressure boundary environmental effects oncomponents:
piping, fatigue are to bepiping components, and addressed.
(See SRP,piping elements exposed Sec 4.3 "Metal Fatigue,"
to reactor coolant for acceptable methodsto comply with 10 CFR54.21 (c)(1))3.1.1-7 Steel (with or without Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation isnickel-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 1alloy reactor vessel components components:
flanges; environmental effects onnozzles; penetrations; fatigue are to besafe ends; thermal addressed.
(See SRP,sleeves; vessel shells, Sec 4.3 "Metal Fatigue,"
heads and welds for acceptable methodsexposed to reactor to comply with 10 CFRcoolant 54.21(c)(1))
3.1.1-8 PWR onlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-170 0 0Section 3-Aging Manageme
- iew ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-9 PWR only3.1.1-10 PWR only3.1.1-11 Steel or stainless steel Cumulative fatigue Fatigue is a TLAA Yes, TLAA Fatigue is a TLAA; further evaluation ispump 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 limitsthermal cycles for allowable cycles (lessthan 7000 cycles) ofthermal stress range.(SRP Sec 4.3 "MetalFatigue,"
for acceptable methods to comply with10 CFR 54.21 (c)(1))3.1.1-12 PWR only3.1.1-13 Steel (with or without Loss of fracture TLAA is to be evaluated Yes, TLAA Consistent with NUREG-1 801. TLAA willstainless steel cladding) toughness due to in accordance with be used to manage loss of fracturereactor vessel beltline neutron irradiation Appendix G of 10 CFR toughness of carbon or low alloy steel withshell, 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 thatcoolant and neutron flux choose to demonstrate are exposed to reactor coolant and neutronthat the materials of the flux.nozzles are notcontrolling for the TLAA See subsection 3.1.2.2.3.1.
evaluations LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-18 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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.
Thecladding) 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 ofand welds; safety embrittlement program fracture toughness of the carbon or lowinjection nozzles alloy steel with stainless steel claddingreactor vessel shell, nozzle, and weldswithin the beltline that are exposed toreactor coolant and neutron flux.See subsection 3.1.2.2.3.2.
3.1.1-15 PWR only3.1.1-16 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 alloyvessel flange leak cracking, to be evaluated because top head enclosure vessel flange leakdetection line intergranular stress existing programs may detection piping components in the Reactorcorrosion cracking not be capable of Vessel, Internals, and Reactor Coolantmitigating or detecting System. The top head enclosure vesselcrack initiation and flange leak detection line is carbon steelgrowth due to SCC in the piping that is not susceptible to stressvesselflange 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 2License Renewal Application Page 3.1-19 0 O Section 3 -Aging Managementeview ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 includeexposed 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, 'WaterChemistry" for BWRwater, and a plant-specific verification program3.1.1-18 PWR only3.1.1-19 PWR only3.1.1-20 PWR only3.1.1-21 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 includecomponents 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 beaugmented by a plant-specific verification programLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-20 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-22 PWR only3.1.1-23 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 only3.1.1-26 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 onlyLaSalle County Station, Units 1 and 2License Renewal Application 0Page 3.1-21 0 0 Section 3 -Aging Managementeview ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 thehole 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 Waterirradiation-assisted Chemistry,"
and for Chemistry (B.2.1.2) program to managestress corrosion BWRs with a crevice in cracking of the nickel alloy core shroud andcracking the access hole covers, core plate access hole cover (weldedaugmented inspection covers) exposed to reactor coolant andusing UT or other neutron flux in the Reactor Vessel Internals.
acceptable techniques An exception applies to the NUREG-1 801recommendations 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 withalloy penetration:
drain stress corrosion Section XI Inservice exceptions.
The ASME Section XIline 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 Watercorrosion
- cracking, Chapter XI.M2, 'Water Chemistry (B.2.1.2) program will be used tocyclic loading Chemistry" manage cracking of stainless steel, nickelalloy, and carbon and low alloy steel withstainless steel or nickel alloy claddingnozzles, penetrations, and vessel shellcomponents exposed to reactor coolantand reactor coolant and neutron flux in theReactor Vessel. The reactor vessel drainline is carbon steel and is therefore addressed in Item Number 3.1.1-31.
An exception applies to the NUREG-1 801recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-22 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 thecomponents 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 WaterChemistry" Chemistry (B.2.1.2) program to manageloss of material of the carbon steel RPVflange leak detection line, carbon steelClass 1 piping, fittings and branchconnections
< 4-inch NPS, and carbonsteel piping, piping components and pipingelements exposed to reactor coolant in theReactor Coolant Pressure BoundarySystem. The LaSalle BWR design doesnot 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 only3.1.1-33 PWR only3.1.1-34 PWR only3.1.1-35 PWR onlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-23 Section 3-Aging Managementeiew ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-36 PWR only3.1.1-37 PWR only3.1.1-38 Cast austenitic stainless Loss of fracture Chapter XIM1, "ASME No Consistent with NUREG-1801.
The ASMEsteel 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 ofexposed 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 tosusceptibility to thermal reactor coolant >250 deg-C (>482 deg-F) inaging is not necessary.
the Reactor Coolant Pressure BoundarySystem.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-24 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 withsteel with stainless steel stress corrosion Section XI Inservice exceptions.
The ASME Section XIcladding 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, Waterconnections
< NPS 4 corrosion cracking Class 1 components, Chemistry (B.2.1.2)
- program, and One-timeexposed 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 usedmechanical, and XI.M35, "One-Time to manage cracking of the carbon steel andvibratory loading Inspection of ASME stainless steel Class 1 piping, fittings, andCode Class 1 Small-bore branch connections
< NPS 4 exposed toPiping" reactor coolant in the Reactor CoolantPressure Boundary System.An exception applies to the NUREG-1 801recommendations for Water Chemistry (B.2.1.2) program implementation.
3.1.1-40 PWR only3.1.1-40x PWR only3.1.1-41 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 accesscovers) exposed to intergranular stress IWB, IWC, and IWD" for hole covers are a welded design and arereactor coolant corrosion
- cracking, Class 1 components, and addressed in Item Number 3.1.1-29.
irradiation-assisted Chapter XI.M2, stress corrosion Chemistry" crackingLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-25 0 0 Section 3-Aging Manageme vniew ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-42 PWR only3.1.1-43 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 thevessel 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 WaterChapter XI.M2, 'Water Chemistry (B.2.1.2) program to manageChemistry" loss of material of stainless steel, nickelalloy, and X-750 alloy reactor vesselinternals components exposed to reactorcoolant and reactor coolant and neutronflux 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 only3.1.1-45 PWR only3.1.1-46 PWR only3.1.1-47 PWR onlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-26 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-48 PWR only3.1.1-49 PWR only3.1.1-50 Cast austenitic stainless Loss of fracture Chapter XI.M12, No Not Applicable.
steel Class 1 piping, toughness due to "Thermal Agingpiping component, and thermal aging Embrittlement of Cast The LaSalle BWR design does not includepiping elements and embrittlement Austenitic Stainless Steel piping, piping components, and pipingcontrol rod drive pressure (CASS)" pipints or compodt adr pipinghousings exposed to elements or control rod drive pressurereactor coolant >250 deg- housings exposed to reactor coolant >250C cooldantF) deg-C (>482 deg-F) in Reactor Vessel,C(>482 eg-) Internals, and Reactor Coolant System.The CRD housings and flanges arestainless steel.3.1.1-51a PWR only3.1.1-51b PWR only3.1.1-52a PWR only3.1.1-52b PWR onlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-27 Section 3 -Aging Managemenreiew ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-52c PWR only3.1.1-53a PWR only3.1.1-53b PWR only3.1.1-53c PWR only3.1.1-54 PWR only3.1.1-55a PWR only3.1.1-55b PWR only3.1.1-55c PWR only3.1.1-56a PWR onlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-28 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-56b PWR only3.1.1-56c PWR only3.1.1-57 There is no Item Number 3.1.1-57 listed in NUREG-1 800 or subsequent ISGs.3.1.1-58a PWR only3.1.1-58b PWR only3.1.1-59a PWR only3.1.1-59b PWR only3.1.1-59c PWR onlyLaSalle County Station, Units 1 and 2License Renewal Application 0Page 3.1-29 Section 3 -Aging Managementeview ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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) programelements exposed to corrosion will be used to manage wall thinning ofreactor coolant carbon steel piping, piping components, and piping elements exposed to reactorcoolant in the Reactor Coolant PressureBoundary System.3.1.1-61 PWR only3.1.1-62 PWR only3.1.1-63 Steel or stainless steel Loss of material due Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Boltingclosure bolting exposed to general (steel Integrity" Integrity (B.2.1.11) program will be used toto air with reactor coolant only), pitting, and manage loss of material of carbon and lowleakage crevice corrosion or alloy steel and high strength low alloy steelwear closure bolting exposed to air with reactorcoolant leakage in the Reactor Vessel andReactor Coolant Pressure BoundarySystem.3.1.1-64 PWR only3.1.1-65 PWR onlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-30 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-66 PWR only3.1.1-67 Steel or stainless steel Loss of preload due Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Boltingclosure bolting exposed to thermal effects, Integrity" Integrity (B.2.1.11) program will be used toto air -indoor with gasket creep, and manage loss of preload of carbon and lowpotential for reactor self-loosening alloy steel, high strength low alloy steel,coolant leakage and stainless steel closure bolting exposedto air -indoor uncontrolled and air with thepotential for reactor coolant leakage in theReactor Vessel and Reactor CoolantPressure Boundary System.3.1.1-68 PWR only3.1.1-69 PWR only3.1.1-70 PWR only3.1.1-71 PWR only3.1.1-72 PWR onlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-31 0Section 3 -Aging Management~eview ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-73 PWR only3.1.1-74 PWR only3.1.1-75 PWR only3.1.1-76 PWR only3.1.1-77 PWR only3.1.1-78 PWR only3.1.1-79 Stainless steel; steel with Loss of material due Chapter XI.M2, 'Water No Consistent with NUREG-1 801 withnickel-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 managecoolant pressure loss of material of stainless steel reactorboundary components coolant pressure boundary components exposed to reactor exposed to reactor coolant in the Reactorcoolant 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 2License Renewal Application Page 3.1-32 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-80 PWR only3.1.1-81 PWR only3.1.1-82 PWR only3.1.1-83 PWR only3.1.1-84 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 managespare) exposed to reactor loss of material of carbon steel and lowcoolant alloy steel top head nozzles and otherreactor vessel nozzles, safe ends, andwelds exposed to reactor coolant, steam,and reactor coolant and neutron flux in theReactor Vessel.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-33 0 O Section 3 -Aging Managementeview ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 withalloy, 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 managevessel flanges,
- nozzles, loss of material of stainless steel, nickel-penetrations, safe ends, alloy, and carbon or low alloy steel withvessel shells, heads and stainless steel or nickel cladding reactorwelds exposed to reactor vessel flanges,
- nozzles, penetrations, safecoolant ends, thermal sleeves, internalattachments, vessel shells, heads andwelds exposed to reactor coolant andreactor coolant and neutron flux in theReactor Vessel.An exception applies to the NUREG-1 801recommendations for Water Chemistry (B.2.1.2) program implementation.
3.1.1-86 PWR only3.1.1-87 PWR only3.1.1-88 PWR only3.1.1-89 PWR onlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-34 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.1.1-90 PWR only3.1.1-91 High-strength low alloy Cracking due to Chapter XI.M3, "Reactor No Consistent with NUREG-1801 withsteel closure head stud stress corrosion Head Closure Stud exceptions.
The Reactor Head Closureassembly exposed to air cracking; loss of Bolting" Stud Bolting (B.2.1.3) program will be usedwith potential for reactor material due to to manage cracking and loss of material ofcoolant leakage general,
- pitting, and high strength low alloy steel closure headcrevice corrosion, or stud bolting assemblies exposed to air withwear (BWR) potential for reactor coolant leakage in theReactor Vessel.Exceptions apply to the NUREG-1 801recommendations for Reactor HeadClosure Stud Bolting (B.2.1.3) programimplementation.
3.1.1-92 PWR only3.1.1-93 PWR onlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-35 Section 3 -Aging Managementeview ResultsTable 3.1.1Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemComponent
[Aging Aging Management Further Discussion IEffect/Mechanism Programs Evaluation
____________________I
_________________
____________________Recommended
__________________________
Stainless steel and nickelalloy vessel shellattachment weldsexposed to reactorcoolantCracking due tostress corrosion
- cracking, intergranular stresscorrosion crackingChapter XI.M4, "BWRVessel ID Attachment Welds," and ChapterXI.M2, "Water Chemistry" NoConsistent with NUREG-1801 withexceptions.
The BWR Vessel IDAttachment Welds (B.2.1.4) program andWater Chemistry (B.2.1.2) program will beused to manage cracking of nickel alloy andstainless steel vessel shell internalattachment welds exposed to reactorcoolant and reactor coolant and neutronflux 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 BWRstainless steel cladding) loading Feedwater Nozzle" Feedwater Nozzle (B.2.1.5) program will befeedwater nozzles used to manage cracking of the low alloyexposed to reactor steel feedwater nozzles exposed to reactorcoolant 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 BWRstainless steel cladding) loading Control Rod Drive Return Control Rod Drive Return Line Nozzlecontrol rod drive return Line Nozzle" (B.2.1.6) program will be used to manageline nozzles exposed to cracking of the carbon or low alloy steelreactor coolant with stainless steel cladding control roddrive return line nozzles exposed to reactorcoolant in the Reactor Vessel.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-36 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 withalloy 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 Waterelements greater than or intergranular stress XI.M2, 'Water Chemistry" Chemistry (B.2.1.2) program will be used toequal to 4 NPS; nozzle corrosion cracking manage cracking of stainless steel andsafe ends and associated nickel alloy piping, piping components, andwelds piping elements, nozzle safe-ends andassociated welds greater than or equal to4-inch NPS that are exposed to reactorcoolant and reactor coolant and neutronflux in the Reactor Vessel and ReactorCoolant Pressure Boundary System.The ASME Section Xl Inservice Inspection, Subsections IWB, IWC, and IWD (B.2.1.1) program has been substituted for the BWRStress Corrosion (B.2.1.7) program and willbe used with the Water Chemistry (B.2.1.2) program to manage cracking of stainless steel valve bodies and pump casings in theReactor Coolant Pressure BoundarySystem.An exception applies to the NUREG-1 801recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-37 9 0 Section 3-Aging Managemen iew ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 withalloy 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 manageexposed to reactor corrosion
- cracking, cracking of stainless steel and nickel alloycoolant cyclic loading instrumentation, standby liquid control, andCRD and Incore Monitor vesselpenetrations exposed to reactor coolantand reactor coolant and neutron flux in theReactor Vessel.An exception applies to the NUREG-1 801recommendations 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 BWRsteel; PH martensitic toughness due to Vessel Internals" Vessel Internals (B.2.1.9) program will bestainless steel; thermal aging and used to manage loss of fracture toughness martensitic stainless neutron irradiation of cast austenitic stainless steel and X-750steel; X-750 alloy reactor embrittlement alloy reactor internal components exposedinternal components to reactor coolant and reactor coolant andexposed to reactor neutron flux in the Reactor Vessel Internals.
coolant and neutron flux PH martensitic stainless steels andmartensitic stainless steels are not usedwithin 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 BWRvessel internals to wear Vessel Internals" Vessel Internals (B.2.1.9) program will becomponents (jet pump used to manage loss of material ofwedge surface) exposed stainless steel jet pump assembly wedgeto reactor coolant surfaces exposed to reactor coolant andneutron flux in the Reactor Vessel Internals.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-38 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 BWRdryers exposed to reactor induced vibration Vessel Internals" for Vessel Internals (B.2.1.9) program will becoolant steam dryer used to manage cracking of stainless steelsteam dryers exposed to reactor coolant inthe Reactor Vessel Internals.
3.1.1-102 Stainless steel fuel Cracking due to Chapter XI.M9, "BWR No Consistent with NUREG-1801 withsupports 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 manageexposed to reactor corrosion cracking cracking of stainless steel fuel supports, coolant control rod drive housings, and steamdryers exposed to reactor coolant andreactor coolant and neutron flux in theReactor 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 2License Renewal Application Page 3.1-39 Section 3 -Aging Managemeneew ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 withalloy 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 manageneutron flux corrosion
- cracking, cracking of stainless steel and nickel alloyirradiation-assisted reactor internal components and thermalstress corrosion sleeves exposed to reactor coolant andcracking reactor coolant and neutron flux in theReactor Vessel and Reactor VesselInternals.
An exception applies to the NUREG-1 801recommendations 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 withvessel 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 manageneutron flux Chemistry" cracking of X-750 alloy reactor internalcomponents exposed to reactor coolantand neutron flux in the Reactor VesselInternals.
An exception applies to the NUREG-1 801recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-40 Section 3 -Aging Management Review ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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, pipingconcrete 318 or ACI 349 (low components, and piping elements exposedwater-to-cement ratio, to concrete in the Reactor Vessel, Internals, low permeability, and and Reactor Coolant System.adequate airentrainment) as cited inNUREG-1557, and 2)plant OE indicates nodegradation of theconcrete3.1.1-106 Nickel alloy piping, piping None None NA -No AEM or Consistent with NUREG-1 801.components and piping AMPelement exposed to air -indoor, uncontrolled, orair with borated waterleakage3.1.1-107 Stainless steel piping, None None NA -No AEM or Consistent with NUREG-1801.
piping components and AMPpiping element exposedto gas, concrete, air withborated 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 2License Renewal Application Page 3.1-41 Section 3 -Aging Managemen view ResultsTable 3.1.1 Summary of Aging Management Evaluations for the Reactor Vessel, Internals, and Reactor Coolant SystemItem 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 reactorreactor coolant coolant that have been identified assusceptible to wall thinning due to erosionin the Reactor Vessel, Internals, andReactor Coolant System.Piping, piping components, and pipingelements in the Reactor Vessel, Internals, and Reactor Coolant System exposed toreactor coolant that are susceptible to wallthinning 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 2License Renewal Application Page 3.1-42 Section 3 -Aging Management Review ResultsTable 3.1.2-1Reactor Coolant Pressure Boundary SystemSummary of Aging Management Evaluation Table 3.1.2-1 Reactor Coolant Pressure Boundary SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Accumulator Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 AUncontrolled (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, 3Alloy Steel Uncontrolled (External)
DamageBolting Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 ALoss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 AAir with Reactor Cumulative Fatigue TLAA IV.C1 .RP-44 3.1.1-11 A, 3Coolant Leakage Damage(External)
Loss of Material Bolting Integrity (B.2.1.11)
IV.C1 .RP-42 3.1.1-63 ALoss of Preload Bolting Integrity (B.2.1.11)
IV.C1 .RP-43 3.1.1-67 AHigh Strength Air with Reactor Cracking Bolting Integrity (B.2.1.11)
V.E.E-03 3.2.1-12 ALow Alloy Steel Coolant Leakage Cumulative Fatigue TLAA IV.Cl RP-44 3.1.1-11 A, 3Bolting with Yield (External)
DamageStrength of 150ksi or Greater Loss of Material Bolting Integrity (B.2.1.11)
IV.C1.RP-42 3.1.1-63 ALoss of Preload Bolting Integrity (B.2.1.11)
IV.C1.RP-43 3.1.1-67 ALaSalle County~fton, Units 1 and 2License Rene W lication.Page 3.1-43 Section 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Bolting Mechanical Closure Stainless Steel Air -Indoor Cumulative Fatigue TLAA IV.C1.RP-44 3.1.1-11 A, 3Bolting Uncontrolled (External)
DamageLoss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 ALoss of Preload Bolting Integrity (B.2.1.11)
IV.C1.RP-43 3.1.1-67 AClass 1 Piping, Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 AFittings 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 AASME Code Class 1Small-Bore Piping(B.2.1.23)
Water Chemistry (B.2.1.2)
IV.C1 .RP-230 3.1.1-39 BCumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3DamageLoss 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 DWall Thinning Flow-Accelerated IV.C1.R-23 3.1.1-60 ACorrosion (B.2.1.10)
Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AUncontrolled (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 AASME Code Class 1Small-Bore Piping(B.2.1.23)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-44 Section 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Class I Piping, Pressure Boundary Stainless Steel Reactor Coolant Cracking Water Chemistry (B.2.1.2)
IV.C1.RP-230 3.1.1-39 BFittings and Branch (Internal)
Cumulative Fatigue TAA IV.C1.R-220 3.1.1-6 A, 3Connections
< Cum ageNPS 4" DamageLoss 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 BFlow 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 BThrottle Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AUncontrolled (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 BFlow Device (Main Throttle Cast Austenitic Steam Cracking One-Time Inspection VIII.B2.SP-98 3.4.1-11 ASteam Line Flow Stainless Steel (B.2.1.21)
Restrictors)
(CASS) Water Chemistry (B.2.1.2)
VIII.B2.SP-98 3.4.1-11 BLoss of Material TLAA H, 5One-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 BHeat 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 JLaSalle Countly on, Units 1 and 2License Rene~ W licationO Page 3.1-45 0Section 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AWater (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 CWater (Internal)
Systems (B.2.1.13)
Hoses Leakage Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AUncontrolled (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 Acomponents, and Uncontrolled (External) piping elementsLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-46 Section 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemF Management Piping, pipingcomponents, andpiping elementsLeakage Boundary Aluminum Alloy Lubricating Oil (Internal)
Loss of MaterialLubricating Oil Analysis(B.2.1.26)
VII.H2.AP-162 3.3.1-99A+ i iOne-Time Inspection (B.2.1.21)
VII.H2.AP-162 3.3.1-99ACarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
V.E.E-443.2.1-40ALubricating 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 BWall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 ACorrosion (B.2.1.10)
-Waste Water (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII. E5.AP-281 3.3.1-91ACopper Alloy with Air -Indoor None None V.F.EP-10 3.2.1-57 A15% 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 AUncontrolled (External)
Lubricating Oil (Internal)
None None VII.J.AP-15 3.3.1-117 AStainless SteelAir -IndoorUncontrolled (External)
NoneNoneIV.E.RP-04 3.1.1-107 LaSalle Units 1 and 2License Rene1 plication Page 3.1-47 iSection 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsLeakage Boundary Stainless Steel Lubricating Oil (Internal)
Loss of MaterialLubricating Oil Analysis(B.2.1.26)
V.D1 .EP-803.2.1-50AOne-Time Inspection (B.2.1.21)
V.D1 .EP-803.2.1-50ATreated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17AWater Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17BPressure Boundary I Carbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
V.E.E-443.2.1-40AReactor Coolant Cumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3(Internal)
DamageLoss 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 DWall Thinning Flow-Accelerated IV.C1.R-23 3.1.1-60 ACorrosion (B.2.1.10)
Steam (Internal)
Cumulative Fatigue TLAA VIII.B2.S-08 3.4.1-1 A, 3DamageLoss 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 BWall Thinning Flow-Accelerated V.D2.E-07 3.2.1-11 ACorrosion (B.2.1.10)
Treated Water (Internal)
Cumulative FatigueDamageTLAAV.D2.E-10 3.2.1-1A, 3Loss 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 BWall ThinningFlow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11ALaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-48 Section 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsPressure Boundary Stainless Steel Air -IndoorUncontrolled (External)
NoneNoneIV.E.RP-04 3.1.1-107 ALubricating 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 BCumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3DamageLoss 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 BTreated Water (Internal)
Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 3DamageLoss 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 BTreated Water > 140 F(Internal)
CrackingBWR Stress Corrosion Cracking (B.2.1.7)
V.D2.E-37 3.2.1-54AWater Chemistry (B.2.1.2)
V.D2.E-37 3.2.1-54BCumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 3Damage ILoss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17A+ i i _Water Chemistry (B.2.1 .2'sV.D2.EP-73 3.2.1-17B..... ...........
(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 2License ReneWV plication 0 Page 3.1-49 Section 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 DCumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3DamageLoss of Fracture ASME Section Xl Inservice IV.C1.R-08 3.1.1-38 AToughness 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 BRPV Flange Leak Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 ADetection 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)
DamageLoss 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 DTanks (EHC Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 AReservoir)
Uncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-50 Section 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Tanks (EHC Leakage Boundary Carbon Steel Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis V.D2.EP-77 3.2.1-49 CReservoir)
(B.2.1.26)
One-Time Inspection V.D2.EP-77 3.2.1-49 C(B.2.1.21)
Valve BodyLeakage Boundary Aluminum AlloyAir -IndoorUncontrolled (External)
NoneNoneV.F.EP-33.2.1-56ALubricating Oil (Internal)
Loss of MaterialLubricating Oil Analysis(B.2.1.26)
VII.H2.AP-162 3.3.1-99AOne-Time Inspection (B.2.1.21)
VII.H2.AP-162 3.3.1-99AI I I + I ICarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Comoonents (B.2.1.24)
V.E.E-443.2.1-40ALubricating 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 MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16A+ I IWater Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16BWall ThinningFlow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11ACopper Alloy with Air -Indoor None None V.F.EP-10 3.2.1-57 A15% 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) iStainless SteelAir -IndoorUncontrolled (External)
NoneNoneIV.E.RP-04 3.1.1-107 ALubricating Oil (Internal)
Loss of MaterialLubricating Oil Analysis(B.2.1.26)
V.D1 .EP-803.2.1-50ALaSalle Countyaiion, Units 1 and 2License Rene W lication_M_ d Page 3.1-51 SSection 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve BodyLeakage Boundary Stainless SteelLubricating Oil (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D1 .EP-803.2.1-50AF 4 4 4Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17AWater Chemistry (B.2.1.2)
V.D2.EP-73 i i3.2.1-17B+ 4 F + -- 3.2.-17 BPressure Boundary Carbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
V.E.E-443.2.1-40AReactor Coolant Cumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3(Internal)
DamageLoss 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 DWall Thinning Flow-Accelerated IV.C1.R-23 3.1.1-60 ACorrosion (B.2.1.10)
Steam (Internal)
Cumulative Fatigue TLAA VIII.B2.S-08 3.4.1-1 A, 3DamageLoss 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 BWall Thinning Flow-Accelerated V.D2.E-07 3.2.1-11 ACorrosion (B.2.1.10)
Treated Water (Internal:
Cumulative FatigueDamaaeTLAAV.D2.E-10 3.2.1-1A, 3Loss 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 BWall ThinningFlow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11ACast Austenitic Air -IndoorNoneNoneIV.E.RP-04 3.1.1-107 AStainless Steel Uncontrolled (External)
(CASS)LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-52 Section 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve BodyPressure BoundaryCast Austenitic Stainless Steel(CASS)Reactor Coolant(Internal)
CrackingASME Section Xl Inservice Inspection, Subsections IWB, IWC, and IWD(B.2.1.1)
IV.C1 .R-203.1.1-97E, 24 .1.Water Chemistry (B.2.1.2)
IV.C1.R-20 3.1.1-97BCumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3DamageLoss of Fracture ASME Section XI Inservice IV.C1.R-08 3.1.1-38 AToughness Inspection, Subsections IWB, IWC, and IWD(B.2.1.1)
ILoss of MaterialOne-Time Inspection (B.2.1.21)
IV.C1 .RP-1583.1.1-79AWater Chemistry (B.2.1.2)
IV.C1.RP-158 3.1.1-79BStainless SteelAir -IndoorUncontrolled (External)
NoneNoneIV.E.RP-04 3.1.1-107 ALubricating 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 BCumulative Fatigue TLAA IV.C1.R-220 3.1.1-6 A, 3DamageLoss 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 BTreated Water (Internal)
Cumulative FatigueDamaqeTLAAVII.E3.A-62 3.3.1-2A, 3LaSalle County on, Units 1 and 2License Rene .W licationPage 3.1-53 Section 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-54 Section 3 -Aging Management Review ResultsTable 3.1.2-1 Reactor Coolant Pressure Boundary System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 andenvironment 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 CF8CASS 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 inSection 4.7.LaSalle Countyiltion, Units 1 and 2 Page 3.1-55License Rene lication Section 3 -Aging Management Review ResultsTable 3.1.2-2Reactor VesselSummary of Aging Management Evaluation Table 3.1.2-2 Reactor VesselComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Bolting (Closure Mechanical Closure High Strength Air with Reactor Cracking Reactor Head Closure IV.A1.RP-51 3.1.1-91 BStuds -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, 2Strength of 150 Damage FtuTIV .R231-1,ksi or GreaterLoss of Material Reactor Head Closure IV.A1.RP-165 3.1.1-91 BStud 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, 2Spray, CRD Alloy Steel Coolant Leakage DamageHousing, Head Bolting (External)
Loss of Material Bolting Integrity (B.2.1.11)
IV.C1.RP-42 3.1.1-63 AVent, SpareNozzle) Loss of Preload Bolting Integrity (B.2.1.11)
IV.C1 .RP-43 3.1.1-67 AN-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 CCladding (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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-56 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BCladdingN-1 Nozzle Safe Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 AEnds 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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BStainless Steel Air -Indoor None None IV.E.RP-04 3.1.1-107 AUncontrolled (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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN-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 CCladding (Internal)
Inspection, Subsections IWB, IWC, and IWDI__I (B.2.1.1)
LaSalle Countvgton, Units 1 and 2License Rene V P lication0 Page 3.1-57 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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, 2Stainless Steel DamageCladdingLoss 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 BN-2 Nozzle Safe Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 AEnds 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 BCumulative Fatigue TLAA IV.AI.R-04 3.1.1-7 A, 2DamageLoss 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 BStainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AUncontrolled (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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN-2 Nozzle Direct Flow Stainless Steel Reactor Coolant Cracking BWR Vessel Internals IV.B1 .R-100 3.1.1-103 CThermal Sleeve (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 DLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-58 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N-2 Nozzle Direct Flow Stainless Steel Reactor Coolant Loss of Material One-Time Inspection IV.Al .RP-157 3.1.1-85 AThermal Sleeve (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 BN-3 Nozzle (Steam Pressure Boundary Low Alloy Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1Outlet) Uncontrolled (External)
Steam (Internal)
Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN-3 Nozzle Safe Pressure Boundary Carbon Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1Ends and Welds Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2(Internal)
DamageLoss 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 DN-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, 2DamageLoss 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 DN-4 Nozzle Safe Pressure Boundary Carbon Steel Air -Indoor None None V.E.E-44 3.2.1-40 I, 1Ends and Welds Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2(Internal)
DamageLoss of Material One-Time Inspection IV.A1 .RP-50 3.1.1-84 CI_ (B.2.1.21)
LaSalle Count Units 1 and 2License Rene plication Page 3.1-59 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 DEnds and Welds (Internal)
Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 I,'1Alloy Steel with Uncontrolled (External)
Stainless Steel Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2Cladding (Internal)
DamageLoss 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 BNickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 AUncontrolled (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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN-4 Nozzle Direct Flow Stainless Steel Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 CThermal Sleeve (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1.R-100 3.1.1-103 DLoss 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 BN-5 Nozzle (Low Pressure Boundary Carbon or Low Air- Indoor None None V.E.E-44 3.2.1-40 I,1Pressure Core Alloy Steel with Uncontrolled (External)
Spray) Stainless SteelI Cladding I I I I ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-60 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N-5 Nozzle (Low Pressure Boundary Carbon or Low Reactor Coolant Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 CPressure Core Alloy Steel with (Internal)
Inspection, Subsections Spray) Stainless Steel IWB, IWC, and IWDCladding (B.2.1.1)
Water Chemistry (B.2.1.2)
IV.A1.RP-371 3.1.1-30 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN-5 Nozzle Safe Pressure Boundary Carbon Steel Air -Indoor None None V.E.E-44 3.2.1-40 1, 1End Extension Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2(Internal)
DamageLoss 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 DN-5 Nozzle Safe Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 AEnds 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 BCumulative Fatigue TLAA IVA1 .R-04 3.1.1-7 A, 2DamageLoss 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 BN-5 Nozzle Direct Flow Stainless Steel Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 CThermal Sleeve (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1.R-100 3.1.1-103 DLoss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 AI____ ___ (B.2.1.21)
I I ILaSalle Count lYIon, Units 1 and 2License Renewplication Page 3.1-61 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BThermal SleeveN-5 Thermal Direct Flow Nickel Alloy Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 CSleeve Extension (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 DLoss 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 BN-6 Nozzle (RHR / Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 I, 1LPCI) Alloy Steel with Uncontrolled (External)
Stainless Steel Reactor Coolant and Cracking ASME Section Xl Inservice IV.A1.RP-371 3.1.1-30 CCladding 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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss of Fracture Reactor Vessel IV.A1.RP-227 3.1.1-14 AToughness Surveillance (B.2.1.20)
TLAA IV.A1.R-67 3.1.1-13 A, 3Loss 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 BN-6 Nozzle Safe Pressure Boundary Carbon Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1End Extensions Uncontrolled (External)
Reactor Coolant and Cumulative Fatigue TLAA IV.A1 .R-04 3.1.1-7 A, 2Neutron Flux (Internal)
DamageLoss 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 DLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-62 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N-6 Nozzle Safe Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 AEnds and Welds Uncontrolled (External)
Reactor Coolant and Cracking BWR Stress Corrosion IV.Al .R-68 3.1.1-97 ANeutron Flux (Internal)
Cracking (B.2.1.7)
Water Chemistry (B.2.1.2)
IV.A1 .R-68 3.1.1-97 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN-6 Nozzle Pressure Boundary Nickel Alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 CThermal Sleeve Neutron Flux (B.2.1.9)
Extension (Unit 2 Water Chemistry (B.2.1.2)
IV.B1.R-100 3.1.1-103 DOnly)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 BN-6 Thermal Direct Flow Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-100 3.1.1-103 CSleeve Neutron Flux (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 DLoss 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 BN-7 Nozzle (Top Pressure Boundary Low Alloy Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1Head Spray / RCIC Uncontrolled (External)
-Flanged)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2(Internal)
DamageLoss 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 BLaSalle Countyl~ion, Units 1 and 2License ReneW plication Page 3.1-63 0Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N-7 Nozzle Flange Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AUncontrolled (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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN-7 Nozzle Welds Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 AUncontrolled (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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN-8 Nozzle (Top Pressure Boundary LowAlloy Steel Air- Indoor None None V.E.E-44 3.2.1-40 I,'1Head Vent -Uncontrolled (External)
Flanged)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2(Internal)
DamageLoss 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 BN-8 Nozzle Flange Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AI_ __ Uncontrolled (External)
_LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-64 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BCumulative Fatigue TLAA IV.A1 .R-04 3.1.1-7 A, 2DamageLoss 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 BN-8 Nozzle Welds Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 AUncontrolled (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 BCumulative Fatigue TLAA IV.AI.R-04 3.1.1-7 A, 2DamageLoss 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 BN-9 Nozzle (Jet Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 1, 1Pump Alloy Steel with Uncontrolled (External)
_Instrumentation)
Stainless Steel Reactor Coolant Cracking
,SME Section XI Inservice IV.A1.RP-371 3.1.1-30 CCladding (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 DCumulative Fatigue TLAA IV.Al .R-04 3.1.1-7 A, 2DamageLoss 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 BLaSalle County, on, Units 1 and 2License Rene~W licationPage 3.1-65 0SSection 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N-9 Nozzle Safe Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 AEnd 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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BStainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AUncontrolled (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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN10 Nozzle (CRD Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 I,1Hydraulic 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 ACapped) Cladding (Internal)
Return Line Nozzle(B.2.1.6)
ASME Section Xl Inservice IV.A1.RP-371 3.1.1-30 CInspection, Subsections IWB, IWC, and IWD(B.2.1.1)
Water Chemistry (8.2.1.2)
IV.Al .RP-371 3.1.1-30 DLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-66 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N10 Nozzle (CRD Pressure Boundary Carbon or Low Reactor Coolant Cumulative Fatigue TLAA IV.AI.R-04 3.1.1-7 A, 2Hydraulic System Alloy Steel with (Internal)
DamageReturn Line -Stainless Steel Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 ACapped) Cladding (B.2.1.21)
Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 BN10 Nozzle Cap Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 Aand 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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BNl1 Nozzle (Core Pressure Boundary Nickel Alloy Air- Indoor None None IV.E.RP-03 3.1.1-106 ADifferential Uncontrolled (External)
Pressure and Reactor Coolant Cracking BWR Penetrations IV.Al.RP-369 3.1.1-98 ALiquid Control)
(Internal)
(B.2.1.8)
Water Chemistry (B.2.1.2)
IV.A1.RP-369 3.1.1-98 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN11 Nozzle Welds Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 AI_ Uncontrolled (External)
LaSalle Countv11110on, Units 1 and 2License ReneW lication.Page 3.1-67 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 DCumulative Fatigue TLAA IV.Al.R-04 3.1.1-7 A, 2DamageLoss 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 BN12 Nozzle (Water Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 ALevel Uncontrolled (External)
Instrumentation
-Reactor Coolant and Cracking BWR Penetrations IV.Al.RP-369 3.1.1-98 A366" Elevation)
Neutron Flux (Internal)
(B.2.1.8)
Water Chemistry (B.2.1.2)
IV.A1 .RP-369 3.1.1-98 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN12 Nozzle Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 AExtension and Uncontrolled (External)
Welds Reactor Coolant and Cracking
,SME Section Xl Inservice IV.A1.RP-371 3.1.1-30 CNeutron 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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-68 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N12 Nozzle Pressure Boundary Nickel Alloy Reactor Coolant and Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 AExtension and Neutron Flux (Internal)
(B.2.1.21)
Welds Water Chemistry (B.2.1.2)
IV.Al .RP-157 3.1.1-85 BStainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AUncontrolled (External)
Reactor Coolant and Cracking ASME Section XI Inservice IV.Al .RP-371 3.1.1-30 CNeutron 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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN13 Nozzle (Water Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 ALevel Uncontrolled (External)
Instrumentation
-Reactor Coolant Cracking BWR Penetrations IV.Al.RP-369 3.1.1-98 A517" Elevation)
(Internal)
(B.2.1.8)
Water Chemistry (B.2.1.2)
IV.Al .RP-369 3.1.1-98 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN13 Nozzle Pressure Boundary Stainless Steel Air -Indoor None None IV.E.RP-04 3.1.1-107 AExtension Uncontrolled (External)
LaSalle Countygftion, Units 1 and 2License ReneW plication
.Page 3.1-69 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N13 Nozzle Pressure Boundary Stainless Steel Reactor Coolant Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 CExtension (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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN13 Nozzle Welds Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 AUncontrolled (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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BStainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AUncontrolled (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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A(B.2.1.21)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-70 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 ALevel Uncontrolled (External)
Instrumentation
-Reactor Coolant Cracking BWR Penetrations IV.A1.RP-369 3.1.1-98 A599" Elevation)
(Internal)
(B.2.1.8)
Water Chemistry (B.2.1.2)
IV.A1.RP-369 3.1.1-98 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN14 Nozzle Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AExtension 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 DCumulative Fatigue TLAA IV.AI.R-04 3.1.1-7 A, 2DamageLoss 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 BN14 Nozzle Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 AExtension 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 DLaSalle Countlifion, Units 1 and 2License ReneW plication Page 3.1-71 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N14 Nozzle Pressure Boundary Nickel Alloy Reactor Coolant Cumulative Fatigue TLAA IV.Al .R-04 3.1.1-7 A, 2Extension Welds (Internal)
DamageLoss 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 BN15 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)
DamageLoss 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 DCarbon or Low Air- Indoor None None V.E.E-44 3.2.1-40 1, 1Alloy Steel with Uncontrolled (External)
Nickel Alloy Reactor Coolant Cracking ASME Section XI Inservice IV.A1.RP-371 3.1.1-30 CCladding (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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN16 Nozzle (High Pressure Boundary Carbon or Low Air -Indoor None None V.E.E-44 3.2.1-40 1, 1Pressure Core Alloy Steel with Uncontrolled (External)
Spray) Stainless SteelCladdingLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-72 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N16 Nozzle (High Pressure Boundary Carbon or Low Reactor Coolant Cracking
,SME Section XI Inservice IV.Al.RP-371 3.1.1-30 CPressure Core Alloy Steel with (Internal)
Inspection, Subsections Spray) Stainless Steel IWB, IWC, and IWDCladding (B.2.1.1)
Water Chemistry (B.2.1.2)
IV.A1 .RP-371 3.1.1-30 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN16 Nozzle Safe Pressure Boundary Carbon Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1End Extensions Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2(internal)
DamageLoss 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 DN16 Nozzle Safe Pressure Boundary Nickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 AEnds 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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN16 Thermal Direct Flow Stainless Steel Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 CSleeve (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1.R-100 3.1.1-103 DLoss of Material One-Time Inspection IV.Al.RP-157 3.1.1-85 AI__ _(B.2.1.21)
ILaSalle Count.giion, Units 1 and 2License ReneW plication 0Page 3.1-73 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BSleeveN16 Thermal Direct Flow Nickel Alloy Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-100 3.1.1-103 CSleeve Extension (B.2.1.9)
(Unit 2 Only) Water Chemistry (B.2.1.2)
IV.B1.R-100 3.1.1-103 DLoss 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 BN17 Nozzle (Seal Pressure Boundary Carbon Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1Leak Detection)
Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1 .R-04 3.1.1-7 A, 2(Internal)
DamageLoss 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 DNickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 AUncontrolled (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 DCumulative Fatigue TLAA IV.A1 .R-04 3.1.1-7 A, 2DamageLoss 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 BN18 (Top Head Pressure Boundary Low Alloy Steel Air- Indoor None None V.E.E-44 3.2.1-40 1, 1Spare -Flanged)
Uncontrolled (External)
Reactor Coolant Cumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2_ _ _ (Internal)
DamageLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-74 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement N18 (Top Head Pressure Boundary Low Alloy Steel Reactor Coolant Loss of Material One-Time Inspection IV.AI.RP-50 3.1.1-84 CSpare -Flanged)
(Internal)
(B.2.1.21)
Water Chemistry (B.2.1.2)
IV.A1.RP-50 3.1.1-84 DNickel Alloy Air -Indoor None None IV.E.RP-03 3.1.1-106 AUncontrolled (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 BCumulative Fatigue TLAA IV.Al .R-04 3.1.1-7 A, 2DamageLoss 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 BN18 Nozzle Flange Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 AUncontrolled (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 BCumulative Fatigue TLAA IV.AI.R-04 3.1.1-7 A, 2DamageLoss 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 BN19 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 BCumulative Fatigue TLAA IV.Al .R-04 3.1.1-7 A, 2DamageLaSalle Units 1 and 2License Rene p lication.1111 A Page 3.1-75 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BN19 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 BCumulative Fatigue TLAA IV.Al.R-04 3.1.1-7 A, 2DamageLoss 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 BN19 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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BN20 Incore Monitor Pressure Boundary Stainless Steel Air- Indoor None None IV.E.RP-04 3.1.1-107 ANozzles (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 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A(B.2.1.21)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-76 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BNozzles (Housingand 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 CCladding (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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BReactor 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 CCladding 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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss of Fracture Reactor Vessel IV.A1.RP-227 3.1.1-14 AToughness Surveillance (B.2.1.20)
TLAA IV.A1.R-62 3.1.1-13 A, 3Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 A____ (B.2.1.21)
LaSalle Countv~ton, Units 1 and 2License Rene lication.Page 3.1-77 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 SteelCladdingReactor 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 CCladding (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 DCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BReactor Vessel Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 AExternal 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 CSupport)
(External)
(B.2.1.21)
Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16 DStructural Support Carbon Steel Air- Indoor Cumulative Fatigue TLAA IV.A1.R-70 3.1.1-4 A, 2Uncontrolled (External)
DamageLoss of Material External Surfaces V.E.E-44 3.2.1-40 AMonitoring of Mechanical I_ I_ Components (B.2.1.24)_
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-78 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Reactor Vessel Structural Support Carbon Steel Air- Indoor Cumulative Fatigue TLAA IV.A1.R-70 3.1.1-4 A, 2External Uncontrolled (External)
DamageAttachments 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 AInternal maintain core Attachment WeldsAttachments configuration and (B.2.1.4) flow distribution Water Chemistry (B.2.1.2)
IV.A1 .R-64 3.1.1-94 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BStainless Steel Reactor Coolant Cracking BWR Vessel ID IV.A1.R-64 3.1.1-94 AAttachment Welds(B.2.1.4)
Water Chemistry (B.2.1.2)
IV.A1.R-64 3.1.1-94 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLoss 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 BReactor Coolant and Cracking BWR Vessel ID IV.A1.R-64 3.1.1-94 ANeutron Flux Attachment Welds(B.2.1.4)
Water Chemistry (B.2.1.2)
IV.A1.R-64 3.1.1-94 BCumulative Fatigue TLAA IV.A1.R-04 3.1.1-7 A, 2DamageLaSalle Countvjlon, Units 1 and 2License Rene Iplication
.Page 3.1-79 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Reactor Vessel Structural Support to Stainless Steel Reactor Coolant and Loss of Material One-Time Inspection IV.A1.RP-157 3.1.1-85 AInternal maintain core Neutron Flux (B.2.1.21)
Attachments configuration andflow distribution Water Chemistry (B.2.1.2)
IV.A1.RP-157 3.1.1-85 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-80 Section 3 -Aging Management Review ResultsTable 3.1.2-2 Reactor Vessel (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 andare at a higher temperature than the air-indoor (uncontrolled) environment.
During plant shutdown the containment atmosphere is normally below thedewpoint temperature.
Therefore, wetting due to condensation and moisture accumulation will not occur during power operation or plant shutdown andloss 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 thiscomponent is evaluated in Section 4.2.LaSalle Countvjion, Units 1 and 2License ReneW plication O Page 3.1-81 Section 3 -Aging Management Review ResultsTable 3.1.2-3Reactor 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 NotesType Function Requiring Programs ItemManagement 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 WaterCore 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, 1Lower) DamageLoss 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 BCore 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, 1Support Cylinder, DamageShroud Support Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2Plate, Shroud (B.2.1.9)
Support Legs andGussets)
Water Chemistry (B.2.1.2)
IV.B1.RP-26 3.1.1-43 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-82 Section 3 -Aging Management Review ResultsTable 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Core Shroud and Direct Flow Nickel Alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-94 3.1.1-29 E, 2Core 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 BLoss 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 BStainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-97 3.1.1-103 ANeutron Flux (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1.R-97 3.1.1-103 BLoss 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 BCore Shroud and Structural Support to Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-93 3.1.1-103 ACore 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 BBolts flow distribution Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1DamageLoss 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 BStainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-93 3.1.1-103 ABolting Neutron Flux (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .R-93 3.1.1-103 BLoss 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 BLoss of Preload TLAA H, 3LaSalle County ion, Units 1 and 2License ReneW plication
.Page 3.1-83 Section 3 -Aging Management Review ResultsTable 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Core Shroud and Direct Flow Cast Austenitic Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-93 3.1.1-103 ACore 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 BLoss of Fracture BWR Vessel Internals IV.B1.RP-219 3.1.1-99 CToughness (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 BStainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-97 3.1.1-103 ANeutron Flux (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .R-97 3.1.1-103 BCumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1DamageLoss 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 BX-750 alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1.RP-381 3.1.1-104 ANeutron Flux (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .RP-381 3.1.1-104 BLoss of Fracture BWR Vessel Internals IV.B1 .RP-200 3.1.1-99 AToughness (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 BCore Spray Lines Direct Flow Cast Austenitic Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-99 3.1.1-103 Aand 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 8Rings, SprayNozzlesLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-84 Section 3 -Aging Management Review ResultsTable 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Core Spray Lines Direct Flow Cast Austenitic Reactor Coolant and Loss of Fracture BWR Vessel Internals IV.B1 .RP-219 3.1.1-99 Cand 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, SprayNozzles Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 BStainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-99 3.1.1-103 ANeutron Flux (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .R-99 3.1.1-103 BCumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1DamageLoss 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 BFuel Supports and Structural Support to Cast Austenitic Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-104 3.1.1-102 AControl 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 BOrificed Fuel flow distribution Support Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1DamageLoss of Fracture BWR Vessel Internals IV.B1 .RP-220 3.1.1-99 AToughness (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 BThrottle Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-104 3.1.1-102 ANeutron Flux (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .R-104 3.1.1-102 BLaSalle Countvdtion, Units I and 2License ReneW plication
- Page 3.1-85 0Section 3 -Aging Management Review ResultsTable 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Fuel Supports and Throttle Stainless Steel Reactor Coolant and Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2Control 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 BSupportInstrumentation:
Structural Support to Stainless Steel Air/Gas -Dry (Internal)
None None IV.E.RP-07 3.1.1-107 CIntermediate maintain core Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-105 3.1.1-103 ARange 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 BMonitor (SRM) Dry Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1Tubes, Incore DamageNeutron FluxMonitor Guide Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2Tubes (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 BJet Pump Direct Flow Cast Austenitic Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-100 3.1.1-103 AAssemblies:
Stainless Steel Neutron Flux (B.2.1.9)
Castings (CASS) Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 BLoss of Fracture BWR Vessel Internals IV.B1.RP-219 3.1.1-99 AToughness (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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-86 Section 3 -Aging Management Review ResultsTable 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Jet Pump Direct Flow Nickel Alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-100 3.1.1-103 AAssemblies:
Inlet Neutron Flux (B.2.1.9)
Riser and Brace, Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 BHolddown Beam,Diffuser,
- Tailpipe, Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2Wedges, and (B.2.1.9)
Repair Water Chemistry (B.2.1.2)
IV.B1 .RP-26 3.1.1-43 BComponents Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-100 3.1.1-103 ANeutron Flux (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .R-100 3.1.1-103 BCumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1DamageLoss 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 BBWR Vessel Internals IV.B1 .RP-377 3.1.1-100 A(B.2.1.9)
Loss of Preload TLAA H, 4X-750 alloy Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .RP-381 3.1.1-104 ANeutron Flux (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .RP-381 3.1.1-104 BCumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1DamageLoss of Fracture BWR Vessel Internals IV.B1 .RP-200 3.1.1-99 AToughness (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 ILaSalle Countition, Units 1 and 2License ReneW plication 0 Page 3.1-87 Section 3 -Aging Management Review ResultsTable 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BAssemblies:
Inlet Neutron Flux BWR Vessel Internals Riser and Brace, (B.2.1 .9)Holddown Beam,Diffuser,
- Tailpipe, Loss of Preload TLAA H, 4Wedges, andRepairComponents Reactor Vessel Structural Support to Cast Austenitic Reactor Coolant Cracking BWR Vessel Internals IV.B1.R-104 3.1.1-102 AInternals 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 BControl Rod Drive flow distribution Guide Tube Loss of Fracture BWR Vessel Internals IV.B1.RP-220 3.1.1-99 AToughness (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 BStainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-104 3.1.1-102 CNeutron Flux (B.2.1.9)
Water Chemistry (B.2.1.2)
IV.B1 .R-104 3.1.1-102 DLoss 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 BReactor Vessel Direct Flow Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1 .R-99 3.1.1-103 CInternals Neutron Flux (B.2.1.9)
Components:
Core Water Chemistry (B.2.1.2)
IV.B1 .R-99 3.1.1-103 DPlate DP/SLC LineLaSalle County Station, Units 1 and 2License Renewal Application Page 3.1-88 Section 3 -Aging Management Review ResultsTable 3.1.2-3 Reactor Vessel Internals (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Reactor Vessel Direct Flow Stainless Steel Reactor Coolant and Loss of Material BWR Vessel Internals IV.B1.RP-26 3.1.1-43 E, 2Internals Neutron Flux (B.2.1.9)
Components:
CorePlate DP/SLC Line Water Chemistry (8.2.1.2)
V.81 .RP-26 3.1.1-43 BSteam 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 CWater Chemistry (B.2.1.2)
IV.B1 .R-104 3.1.1-102 DLoss 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 BTop Guide Structural Support to Stainless Steel Reactor Coolant and Cracking BWR Vessel Internals IV.B1.R-98 3.1.1-103 Amaintain core Neutron Flux (B.2.1.9) configuration and Water Chemistry (B.2.1.2)
IV.B1.R-98 3.1.1-103 Bflow distribution Cumulative Fatigue TLAA IV.B1.R-53 3.1.1-3 A, 1DamageLoss 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 BLaSalle County on, Units 1 and 2License RenevW lication0 Page 3.1-89 Section 3 -Aging Management Review ResultsTable 3.1.2-3 Reactor Vessel Internals (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 andenvironment 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 neutronfluence 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 bracerepair 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 andauxiliary wedges.LaSalle County Station, Units 1 and 2 Page 3.1-90License Renewal Application This Page Intentionally Left Blank Section 3 -Aging Management Review Results3.2 AGING MANAGEMENT OF ENGINEERED SAFETY FEATURES3.
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 agingmanagement review. The systems, or portions of systems, which are addressed in thissection 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 RESULTSThe following tables summarize the results of the aging management review forEngineered 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 AgingManagement Programs3.2.2.1.1 High Pressure Core Spray SystemMaterials 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 CladdingLaSalle County Station, Units 1 and 2 Page 3.2-1License Renewal Application Section 3 -Aging Management Review Results" Glass" Stainless Steel" Stainless Steel Bolting" ZincEnvironments The High Pressure Core Spray System components are exposed to the following environments:
- Air -Indoor Uncontrolled
" Lubricating Oil* Treated WaterAging Effects Requiring Management The following aging effects associated with the High Pressure Core Spray Systemcomponents require management:
" Cumulative Fatigue Damage" Loss of Material* Loss of Preload* Wall ThinningAging Management ProgramsThe following aging management programs manage the aging effects for the HighPressure 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 SystemMaterials The materials of construction for the Low Pressure Core Spray System components are:* Carbon Steel* Carbon and Low Alloy Steel BoltingLaSalle County Station, Units 1 and 2 Page 3.2-2License 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* ZincEnvironments The Low Pressure Core Spray System components are exposed to the following environments:
- Air -Indoor Uncontrolled
" Lubricating Oil" Treated WaterAging Effects Requiring Management The following aging effects associated with the Low Pressure Core Spray Systemcomponents require management:
- Cumulative Fatigue Damage* Loss of Material" Loss of Preload* Wall ThinningAging Management ProgramsThe following aging management programs manage the aging effects for the LowPressure 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 2License Renewal Application Page 3.2-3 Section 3 -Aging Management Review Results3.2.2.1.3 Reactor Core Isolation Cooling SystemMaterials 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* ZincEnvironments The Reactor Core Isolation Cooling System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Air -Outdoor* Condensation
- Lubricating Oil* Soil* Steam* Treated WaterAging Effects Requiring Management The following aging effects associated with the Reactor Core Isolation Cooling Systemcomponents require management:
" Cracking* Cumulative Fatigue Damage* Loss of Coating Integrity LaSalle County Station, Units 1 and 2 Page 3.2-4License Renewal Application Section 3 -Aging Management Review Results* Loss of Material* Loss of Preload" Reduction of Heat Transfer* Wall ThinningAging Management ProgramsThe following aging management programs manage the aging effects for the ReactorCore 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 andMaintenance Program (B.2.2.1)
- TLAA* Water Chemistry (B.2.1.2) 3.2.2.1.4 Residual Heat Removal SystemMaterials 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 BoltingLaSalle County Station, Units 1 and 2 Page 3.2-5License Renewal Application Section 3 -Aging Management Review ResultsEnvironments The Residual Heat Removal System components are exposed to the following environments:
" Air -Indoor Uncontrolled
" Condensation
- Lubricating Oil" Treated WaterAging Effects Requiring Management The following aging effects associated with the Residual Heat Removal Systemcomponents require management:
- Cumulative Fatigue Damage* Loss of Material" Loss of Preload* Reduction of Heat Transfer" Wall ThinningAging Management ProgramsThe following aging management programs manage the aging effects for the ResidualHeat 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 SystemMaterials The materials of construction for the Standby Gas Treatment System components are:" Aluminum Alloy" Carbon SteelLaSalle County Station, Units 1 and 2License 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 SteelEnvironments The Standby Gas Treatment System components are exposed to the following environments:
" Air -Indoor Uncontrolled
" Condensation
- Waste WaterAging Effects Requiring Management The following aging effects associated with the Standby Gas Treatment Systemcomponents require management:
- Hardening and Loss of Strength* Loss of Material* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the StandbyGas 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 ReportNUREG-1801 provides the basis for identifying those programs that warrant furtherevaluation by the reviewer in the license renewal application.
For the Engineered SafetyFeatures, those programs are addressed in the following subsections.
LaSalle County Station, Units 1 and 2 Page 3.2-7License Renewal Application Section 3 -Aging Management Review Results3.2.2.2.1 Cumulative Fatigue DamageFatigue is a time-limited aging analysis (TLAA) as defined in 10 CFR 54.3. TLAAs arerequired 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, ReactorCore Isolation Cooling System, Reactor Water Cleanup System, and Residual HeatRemoval System is discussed in Section 4.3.3.2.2.2.2 Loss of Material due to Cladding BreachLoss of material due to cladding breach could occur for PWR steel pump casings withstainless steel cladding exposed to treated borated water. The GALL Report references NRC Information Notice 94-63, Boric Acid Corrosion of Charging Pump Casings Causedby Cladding Cracks, and recommends further evaluation of a plant-specific AMP toensure 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 encasedstainless steel tanks exposed to raw water due to cracking of the perimeter seal fromweathering.
The GALL Report recommends further evaluation to ensure that theaging effect is adequately managed.
The GALL Report recommends that a plant-specific AMP be evaluated because moisture and water can egress under the tank ifthe perimeter seal is degraded.
Acceptance criteria are described in BranchTechnical 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 nopartially encased stainless steel tanks exposed to raw water in Engineered SafetyFeatures systems at LSCS.2. Loss of material due to pitting and crevice corrosion could occur for stainless steelpiping, piping components, piping elements, and tanks exposed to outdoor air. Thepossibility of pitting and crevice corrosion also extends to components exposed to airwhich has recently been introduced into buildings,
- i. e., components near intakevents. Pitting and crevice corrosion is only known to occur in environments containing sufficient halides (primarily chlorides) and in which condensation ordeliquescence is possible.
Condensation or deliquescence should generally beassumed to be possible.
Applicable outdoor air environments (and associated indoorair environments)
- include, but are not limited to, those within approximately 5 miles ofa saltwater coastline, those within 1/2 mile of a highway which is treated with salt inthe wintertime, those areas in which the soil contains more than trace chlorides, those plants having cooling towers where the water is treated with chlorine orchlorine compounds, and those areas subject to chloride contamination from otheragricultural or industrial sources.
This item is applicable for the environments described above.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-8 Section 3 -Aging Management Review ResultsGALL AMP XI.M36, "External Surfaces Monitoring,
" is an acceptable method tomanage the aging effect. The applicant may demonstrate that this item is notapplicable by describing the outdoor air environment present at the plant anddemonstrating that external pitting or crevice corrosion is not expected.
The GALLReport 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 crevicecorrosion in stainless steel piping, piping components, and piping elements exposedto outdoor air in the Reactor Core Isolation Cooling System. The External SurfacesMonitoring of Mechanical Components (B.2.1.24) program provides for management of aging effects through periodic visual inspection of external surfaces for evidence ofthe loss of material.
Any visible evidence of the loss of material will be evaluated foracceptability of continued service.
Deficiencies will be documented in accordance with the 10 CFR Part 50, Appendix B Corrective Action Program.
The ExternalSurfaces Monitoring of Mechanical Components (B.2.1.24) program is described inAppendix B.3.2.2.2.4 Loss of Material due to ErosionLoss of material due to erosion could occur in the stainless steel high-pressure safetyinjection (HPSI) pump miniflow recirculation orifice exposed to treated borated water.The GALL Report recommends a plant-specific AMP be evaluated for erosion of theorifice due to extended use of the centrifugal HPSI pump for normal charging.
The GALLReport 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 ofmaterial due to erosion for Engineered Safety Features systems at LSCS is addressed inItem 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 occurfor steel drywell and suppression chamber spray system nozzle and flow orifice internalsurfaces exposed to air -indoor uncontrolled.
This could result in plugging of the spraynozzles and flow orifices.
This aging mechanism and effect will apply since the spraynozzles and flow orifices are occasionally wetted, even though the majority of the timethis 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 criteriaare 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 floworifices or nozzles in an uncontrolled indoor air environment in Engineered SafetyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-9 Section 3 -Aging Management Review ResultsFeatures systems at LSCS. At LSCS, the drywell and suppression chamber spraynozzles are cast austenitic stainless steel.3.2.2.2.6 Cracking due to Stress Corrosion CrackingCracking due to stress corrosion cracking could occur for stainless steel piping, pipingcomponents, piping elements and tanks exposed to outdoor air. The possibility ofcracking 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 inenvironments containing sufficient halides (primarily chlorides) and in whichcondensation or deliquescence is possible.
Condensation or deliquescence shouldgenerally be assumed to be possible.
Applicable outdoor air environments (andassociated indoor air environments)
- include, but are not limited to, those withinapproximately 5 miles of a saltwater coastline, those within 1/2 mile of a highway whichis treated with salt in the wintertime, those areas in which the soil contains more thantrace chlorides, those plants having cooling towers where the water is treated withchlorine or chlorine compounds, and those areas subject to chloride contamination fromother 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 managethe aging effect. The applicant may demonstrate that this item is not applicable bydescribing the outdoor air environment present at the plant and demonstrating thatexternal chloride stress corrosion cracking is not expected.
The GALL Reportrecommends further evaluation to determine whether an aging management program isneeded to manage this aging effect based on the environmental conditions applicable tothe 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 steelpiping, piping components, and piping elements exposed to outdoor air in the ReactorCore Isolation Cooling System. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program provides for management of aging effects throughperiodic visual inspection of external surfaces for evidence of cracking.
Any visibleevidence 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 andAppendix B, Section B.1.4.LaSalle County Station, Units 1 and 2 Page 3.2-10License Renewal Application Section 3 -Aging Management Review Results3.2.2.2.9 Loss of Material due to Recurring Internal Corrosion Recurring internal corrosion can result in the need to augment AMPs beyond therecommendations in the GALL Report. During the search of plant-specific OE conducted during the LRA development, recurring internal corrosion can be identified by the numberof 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 revealsrepetitive 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 ormore sequential or nonsequential cycles for a 5-year OE search) of aging effects with thesame aging mechanism in which the aging effect resulted in the component either notmeeting 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, beevaluated 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 onsusceptibility to aging effect and consequences of failure, a greater frequency ofinspections),
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 todetect the recurring aging effect before affecting the ability of a component to perform itsintended
- 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 whereincreased inspections would be implemented (e.g., the extent of degradation at individual corrosion sites, the rate of degradation change),
(d) how inspections of components thatare not easily accessed (i.e., buried, underground) will be conducted, and (e) how leaksin any involved buried or underground components will be identified.
Each plant-specific operating experience example should be evaluated to determine ifthe chosen AMP should be augmented even if the thresholds for significance of agingeffect 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 360degree 30 percent wall loss occurred at copper alloy to steel joints. Neither thesignificance of the aging effect nor the frequency of occurrence of aging effect threshold has been exceeded.
Nevertheless, the operating experience should be evaluated todetermine 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 providereasonable assurance that the CLB intended functions of the component will be metthroughout the period of extended operation.
- Likewise, the GALL Report AMR itemsassociated with the new FE items only cite raw water and waste water environments because OE indicates that these are the predominant environments associated withrecurring internal corrosion;
- however, if the search of plant-specific OE reveals recurring internal corrosion in other water environments (e.g., treated water), the aging effectshould be addressed in a similar manner.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-11 Section 3 -Aging Management Review ResultsLR-ISG-2012-02 has been issued which addresses instances of recurring internalcorrosion identified during review of plant-specific operating experience.
The operating experience for LSCS has been reviewed and instances of recurring internal corrosion inthe Engineered Safety Features systems have not been identified with a frequency thatis consistent with the thresholds discussed in LR-ISG-2012-02.
3.2.2.3 Time-Limited Aging AnalysisThe 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 StressAnalyses" Section 4.3.5, High-Energy Line Break (HELB) Analyses Based Upon Fatigue3.
2.3 CONCLUSION
The Engineered Safety Features piping, fittings, and components that are subject toaging management review have been identified in accordance with the requirements of10 CFR 54.4. The aging management programs selected to manage aging effects forthe Engineered Safety Features components are identified in the summaries in Section3.2.2.1 above.A description of these aging management programs is provided in Appendix B, alongwith the demonstration that the identified aging effects will be managed for the period ofextended operation.
Therefore, based on the conclusions provided in Appendix B, the effects of agingassociated with the Engineered Safety Features components will be adequately managed so that there is reasonable assurance that the intended functions aremaintained consistent with the current licensing basis during the period of extendedoperation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-12 0 0 Section 3 -Aging Management ReviewTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 isPiping, piping damage aging analysis (TLAA) to documented in Subsection 3.2.2.2.1.
components, and piping due to fatigue be evaluated for theelements exposed to period of extendedTreated water (borated) operation.
See the SRP,Section 4.3 "MetalFatigue,"
for acceptable methods for meeting therequirements of 10 CFR54.21 (c)(1).3.2.1-2 PWR Only3.2.1-3 PWR Only3.2.1-4 Stainless steel Piping, Loss of material Chapter XI.M36, Yes, environmental Consistent with NUREG-1801.
Thepiping 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 beexposed to Air -outdoor Components" used to manage loss of material ofstainless 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 OnlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-13 Section 3 -Aging Management Review ResultsTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 toAir -indoor, uncontrolled (Internal) 3.2.1-7 Stainless steel Piping, Cracking Chapter XI.M36, Yes, environmental Consistent with NUREG-1801.
Thepiping 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 beexposed to Air -outdoor Components" used to manage cracking of stainless steelpiping, piping components, and pipingelements exposed to air -outdoor in theReactor Core Isolation Cooling System.See subsection 3.2.2.2.6.
3.2.1-8 PWR Only3.2.1-9 PWR Only3.2.1-10 Cast austenitic stainless Loss of fracture Chapter XI.M12, No Not Applicable.
steel Piping, piping toughness "Thermal Agingcomponents, and piping due to thermal aging Embrittlement of Cast piping components, and piping elementselements exposed to embrittlement Austenitic Stainless Steel exposed to treated water (borated)
>2500CTreated water (borated)
(CASS)" exposd tor treated water (b raed > 250°>250'C (>482OF),
(>482iF) or treated water >250sC (>482°F)Treated water >250oC in Engineered Safety Features systems.(>482'F)LaSalle Count lion, Units 1 and 2License ReneW plication Page 30 0 O Section 3 -Aging Management Review .Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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) programelements exposed to accelerated corrosion will be used to manage wall thinning of theSteam, Treated water carbon steel piping, piping components, and piping elements exposed to steam andtreated water in the Reactor CoolantPressure Boundary System, Reactor CoreIsolation Cooling System, Reactor WaterCleanup System, and Residual HeatRemoval System.3.2.1-12 Steel, high-strength Cracking Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The BoltingClosure bolting exposed due to cyclic loading, Integrity" Integrity (B.2.1.11) program will be used toto Air with steam or water stress corrosion manage cracking of the high strength lowleakage cracking alloy steel bolting exposed to air with thepotential for reactor coolant leakage in theReactor Coolant Pressure BoundarySystem.3.2.1-13 Steel; stainless steel Loss of material Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The BoltingBolting, Closure bolting due to general (steel Integrity" Integrity (B.2.1.11) program will be used toexposed 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 boltinguncontrolled (External) exposed to air -indoor uncontrolled in theHigh Pressure Core Spray System, LowPressure Core Spray System, ReactorCoolant Pressure Boundary System,Reactor Core Isolation Cooling System,Residual Heat Removal System, andStandby 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 tosteam or water leakage corrosion air with steam or water leakage inEngineered Safety Features systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-15 Section 3 -Aging Management Review ResultsTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 Boltingalloy, Steel; stainless due to thermal Integrity" Integrity (B.2.1.11) program will be used tosteel, Stainless steel, effects, gasket creep, manage loss of preload of the carbon andSteel; stainless steel and self-loosening low alloy steel and stainless steel boltingBolting, Closure bolting exposed to air -indoor uncontrolled andexposed to Any treated water in the High Pressure Coreenvironment, Air -Spray System, Low Pressure Core Sprayoutdoor (External),
Raw System, Reactor Coolant Pressurewater, Treated borated Boundary System, Reactor Core Isolation water, Fuel oil, Treated Cooling System, Residual Heat Removalwater, 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 withisolation 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 Watersurfaces),
Piping, piping corrosion Time Inspection" Chemistry (B.2.1.2) program will be used tocomponents, and piping manage loss of material of the carbon steelelements exposed to and gray cast iron heat exchanger Treated water components, piping, piping components, and piping elements, reactor vesselexternal attachments, and tanks exposed totreated water in the High Pressure CoreSpray System, Low Pressure Core SpraySystem, Reactor Coolant PressureBoundary System, Reactor Core Isolation Cooling System, Reactor Vessel, andResidual Heat Removal System.An exception applies to the NUREG-1 801recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle Countv ion, Units 1 and 2License Reneyplication Page30 Section 3 -Aging Management ReviewTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 withsteel 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 Waterelements exposed to Time Inspection" Chemistry (B.2.1.2) program will be used toTreated water manage loss of material of the carbon orlow alloy steel with stainless steel claddingand stainless steel heat exchanger components, and piping, pipingcomponents, and piping elements exposedto treated water and treated water > 140 Fin the High Pressure Core Spray System,Low Pressure Core Spray System, ReactorCoolant Pressure Boundary System,Reactor Core Isolation Cooling System,and Residual Heat Removal System.The Bolting Integrity (B.2.1.11) programhas been substituted and will be used tomanage loss of material of stainless steelbolting exposed to treated water in the HighPressure Core Spray System, LowPressure Core Spray System, ReactorCore Isolation Cooling System, andResidual 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 Featesexposed to Treated water water in Engineered Safety Featuressystems are addressed by Item Number3.2.1-17.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-17 Section 3 -Aging Management Review ResultsTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 withexchanger 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 heatexchanger components exposed to treatedwater in the Residual Heat RemovalSystem.An exception applies to the NUREG-1 801recommendations for Water Chemistry (B.2.1.2) program implementation.
3.2.1-20 PWR Only3.2.1-21 PWR Only3.2.1-22 PWR Only3.2.1-23 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 inexposed to Raw water fouling that leads to Engineered Safety Features systems.corrosion 3.2.1-24 PWR OnlyLaSalle Count.dtion, Units 1 and 2License ReneW plication Page30 O O Section 3- Aging Management Review esTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 heatContainment isolation and microbiologically-System" Ther componess st ainmentpiping and components influenced corrosion; exchanger components or containment (Internal surfaces) fouling that leads to isolation piping and components exposedexposed to Raw water corrosion to raw water in Engineered Safety Featuressystems.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 heatexposed to Raw water due to fouling System" Ther tubes steed heatexchanger tubes exposed to raw water inEngineered 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 heatexposed to Raw water due to fouling System" Ther tubes sed or ster inexchanger tubes exposed to raw water inEngineered 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, pipingpiping elements exposed corrosion cracking Systems" componeno and piping posedto Closed-cycle cooling components, and piping elements exposedwater >60C C (>140°F) to closed-cycle cooling water >60°C(>140°F) in Engineered Safety Featuressystems.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, pipingelements exposed to pitting, and crevice Systems" There and piping pipingClosed-cycle cooling corrosion components, and piping elements exposedwater c to closed-cycle cooling water in Engineered Safety Features systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-19 Section 3 -Aging Management Review ResultsTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 Closedcomponents exposed to due to general, "Closed Treated Water Treated Water Systems (B.2.1.13) programClosed-cycle cooling pitting,
- crevice, and Systems" will be used to manage loss of material ofwater galvanic corrosion the carbon steel heat exchanger components exposed to closed cyclecooling water in the Reactor CoolantPressure 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 WaterPiping, piping crevice corrosion Systems" There are no stainless steel heatcomponents, and piping exchanger components or piping, pipingelements exposed to components, and piping elements exposedClosed-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 Closedexchanger components, due to pitting,
- crevice, "Closed Treated Water Treated Water Systems (B.2.1.13) programPiping, piping and galvanic Systems" will be used to manage loss of material ofcomponents, and piping corrosion the copper alloy heat exchanger elements exposed to components exposed to closed cycleClosed-cycle cooling cooling water in the Reactor Coolantwater 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 steeltubes exposed to Closed- due to fouling Systems" heat exchanger tubes exposed to closed-cycle cooling water cycle cooling water in Engineered SafetyFeatures systems.LaSalle County on, Units 1 and 2License Rene 1wlication Page 30 0 0 Section 3- Aging Management Review Re9Table 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 orcomponents, and piping leaching
>8% Al) piping, piping components, andexchanger components piping elements or heat exchanger exposed to Closed-cycle components exposed to closed-cycle exposedol Cler cooling water in Engineered Safetycooling water Features systems.3.2.1-35 PWR Only3.2.1-36 PWR Only3.2.1-37 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, pipingpiping elements exposed leaching Teeaen rycs rnppnppnto Soil components, and piping elements exposedto soil in Engineered Safety Featuressystems.3.2.1-38 Elastomers Elastomer Hardening and loss of Chapter XI.M36, No Consistent with NUREG-1801.
Theseals 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 beuncontrolled (External) degradation Components" used to manage hardening and loss ofstrength of the elastomer seals andcomponents exposed to air -indooruncontrolled in the Standby Gas Treatment System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-21 Section 3 -Aging Management Review ResultsTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 Surfacescomponents (External corrosion Monitoring of Mechanical There are no steel containment isolation surfaces) exposed to Components" piping and components exposed toCondensation (External) condensation (external) in Engineered Safety Features systems.LaSalle County on, Units 1 and 2License Rene1W licationPage 30 Section 3 -Aging Management Review RITable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.2.1-40Steel Ducting, piping, andcomponents (External surfaces),
Ducting,closure bolting,Containment isolation piping and components (External surfaces) exposed to Air -indoor,uncontrolled (External)
Loss of materialdue to generalcorrosion Chapter XI.M36,"External SurfacesMonitoring of Mechanical Components" NoConsistent with NUREG-1801.
TheExternal Surfaces Monitoring of Mechanical Components (B.2.1.24) program will beused to manage loss of material of thecarbon or low alloy steel with stainless steelcladding, carbon steel, carbon steel (withinternal coating),
and gray cast iron ductingand components, heat exchanger components, piping, piping components, and piping elements, reactor vesselexternal attachments, and tanks exposed toair- indoor, uncontrolled in the HighPressure Core Spray System, LowPressure Core Spray System, ReactorCoolant Pressure Boundary System,Reactor Core Isolation Cooling System,Reactor Vessel, Residual Heat RemovalSystem, and Standby Gas Treatment System.The aging effect of loss of material due togeneral corrosion does not apply to theexternal surfaces of reactor vessel, nozzle,and safe end components exposed to air-indoor, uncontrolled in the Reactor VesselSystem. During power operation theinsulated reactor vessel, nozzles, and safeend components have external temperature greater than 212 degrees F and are at ahigher temperature than the air-indoor (uncontrolled) environment.
During plantshutdown the containment atmosphere isnormally below the dewpoint temperature.
Therefore, wetting due to condensation andmoisture accumulation will not occur duringpower operation or plant shutdown and lossof material due to general corrosion doesnot apply.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-23 Section 3 -Aging Management Review ResultsTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 Surfaceselements exposed to Air -crevice corrosion Monitoring of Mechanical There are no aluminum piping, pipingoutdoor Components" components, and piping elements exposedto air -outdoor in Engineered SafetyFeatures 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 andexposed to Air -indoor, due to elastomer Surfaces in componeno elasto air anduncontrolled (Internal) degradation Miscellaneous Piping and components exposed to air -indoor,oucting Components" uncontrolled (internal) in Engineered SafetyFeatures systems.
The internalenvironment of elastomer seals andcomponents in the Standby Gas Treatment System is considered to be condensation.
Hardening and loss of strength of thesecomponents is managed by the Inspection of Internal Surfaces in Miscellaneous Pipingand 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 aircomponents (Internal Miscellaneous Piping and(internal) insurfaces) exposed to Air Ducting Components" Engineered Safety Features systems.
The-indoor, uncontrolledEnierdSftFauesytm.Th (Internal) applicable internal environment for pipingand components and ducting andcomponents in Engineered Safety Featuressystems is considered to be condensation, and is addressed by Item Number 3.2.1-46.
LaSalle Count jon, Units 1 and 2License ReneW ýlication Page 30 Section 3 -Aging Management ReviewTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation
_ _Recommended 3.2.1-45 PWR Only3.2.1-46 Steel Piping and Loss of material Chapter XI.M38, No Consistent with NUREG-1801.
Thecomponents (Internal due to general, "Inspection of Internal Inspection of Internal Surfaces insurfaces) exposed to pitting, and crevice Surfaces in Miscellaneous Piping and DuctingCondensation (Internal) corrosion Miscellaneous Piping and Components (B.2.1.25) program will beDucting Components" used to manage loss of material of thecarbon steel, galvanized steel, and graycast iron ducting and components, piping,piping components, and piping elements, and tanks exposed to condensation in theReactor Core Isolation Cooling System,Residual Heat Removal System, andStandby Gas Treatment System.3.2.1-47 PWR Only3.2.1-48 Stainless steel Piping, Loss of material Chapter XI.M38, No Consistent with NUREG-1801.
Thepiping components, and due to pitting and "Inspection of Internal Inspection of Internal Surfaces inpiping elements (Internal crevice corrosion Surfaces in Miscellaneous Piping and Ductingsurfaces);
tanks exposed Miscellaneous Piping and Components (B.2.1.25) program will beto Condensation Ducting Components" used to manage loss of material of the(Internal) stainless steel ducting and components, piping, piping components, and pipingelements, and tanks exposed tocondensation in the Combustible GasControl System, Reactor Core Isolation Cooling System, Residual Heat RemovalSystem, Standby Gas Treatment System,and Standby Liquid Control System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-25 Section 3 -Aging Management Review ResultsTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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.
Thecomponents, and piping due to general, "Lubricating Oil Analysis,"
Lubricating Oil Analysis (B.2.1.26) programelements 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 ofTime Inspection" material of the carbon steel, carbon steel(with internal coating),
and gray cast ironheat exchanger components, piping, pipingcomponents, and piping elements, andtanks exposed to lubricating oil in the HighPressure Core Spray System, LowPressure Core Spray System, ReactorCoolant 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. Thesteel Piping, piping due to pitting and "Lubricating Oil Analysis,"
Lubricating Oil Analysis (B.2.1.26) programcomponents, 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 ofLubricating oil Time Inspection" material of the copper alloy and stainless steel heat exchanger components, andpiping, piping components, and pipingelements, exposed to lubricating oil in theReactor Coolant Pressure BoundarySystem and Reactor Core Isolation CoolingSystem.LaSalle Countwflion, Units 1 and 2License ReneW plication Page 30 Section 3 -Aging Management Review sutTable 3.2.1Summary of Aging Management Evaluations for the Engineered Safety FeaturesDiscussion
- omponent 4 iSteel, Copper alloy,Stainless steel Heatexchanger tubesexposed to Lubricating oilReduction of heattransferdue to foulingChapter XI.M39,"Lubricating Oil Analysis,"
andChapter XI.M32, "One-Time Inspection" NoConsistent with NUREG-1801.
TheLubricating Oil Analysis (B.2.1.26) programand the One-Time Inspection (B.2.1.21) program will be used to manage reduction of heat transfer of the copper alloy andstainless steel heat exchanger tubesexposed to lubricating oil in the ControlRoom Ventilation System, Diesel Generator and Auxiliaries System, Essential CoolingWater 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 orcomponents, and piping pitting,
- crevice, and and Tanks" wrea n pno pip ing c oelements exposed to Soil microbiologically-wrapping) piping, piping components, andor Concrete influenced corrosion piping elements exposed to soil or concretein Engineered Safety Features systems.3.2.1-53 Stainless steel, nickel Loss of material Chapter XI.M41, "Buried No Consistent with NUREG-1801.
The Buriedalloy 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 ofelements exposed to soil material of the stainless steel piping, pipingor concrete components, and piping elements exposedto soil in the Reactor Core Isolation CoolingSystem.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 nickelpiping, piping only), pitting and and Tanks" Th er gr oun d piping, pipingcomponents, and piping crevice corrosion alloy underground piping, pipingelements exposed to air- components, and piping elements exposedintso expontrled toair- to air-indoor uncontrolled or condensation condensation (external)
(external) in Engineered Safety Featuressystems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-27 Section 3 -Aging Management Review ResultsTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 withpiping 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 Waterto Treated water >60°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 steelpiping, piping components, and pipingelements exposed to treated water > 140 Fin the Reactor Coolant Pressure BoundarySystem.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, pipingelements exposed to concrete are consistent componentostee piping pipingConcrete with ACI 318 or ACI 349 components, and piping elements exposed(low water-to-cement to concrete in Engineered Safety Featuresratio, low permeability, systems.and adequate airentrainment) as cited inNUREG-1557, and2) plant OE indicates nodegradation of theconcrete3.2.1-56 Aluminum Piping, piping None None NA -No AEM or Consistent with NUREG-1801.
components, and piping AMPelements exposed to Air-indoor, uncontrolled (Internal/External)
LaSalle Count.,lion, Units 1 and 2License ReneV plication Page 30 Section 3- Aging Management Review esTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 AMPpiping elements exposedto Air -indoor,uncontrolled (External),
Gas3.2.1-58 PWR Only3.2.1-59 Galvanized steel Ducting, None None NA -No AEM or Not Applicable.
piping, and components AMPexposed 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, AMPuncontrolled (External),
Lubricating oil, Rawwater, Treated water,Treated water (borated),
Air with borated waterleakage, Condensation (Internal/External),
Gas,Closed-cycle coolingwater, Air -outdoor3.2.1-61 Nickel alloy Piping, piping None None NA -No AEM or Consistent with NUREG-1801.
components, and piping AMPelements exposed to Air-indoor, uncontrolled (External)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-29 Section 3 -Aging Management Review ResultsTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 AMPelements exposed to Air There are no nickel alloy piping, pipingwith borated water components, and piping elements exposedleakage to air with borated water leakage inEngineered Safety Features systems.3.2.1-63 Stainless steel Piping, None None NA -No AEM or Consistent with NUREG-1801.
piping components, and AMPpiping elements exposedto Air -indoor,uncontrolled (External),
Air with borated waterleakage,
- Concrete, Gas,Air -indoor, uncontrolled (Internal) 3.2.1-64 Steel Piping, piping None None NA -No AEM or Not Applicable.
components, and piping AMPelements exposed to Air There are no steel piping, piping-indoor, controlled components, and piping elements exposed(External),
Gas to air -indoor, controlled or gas inEngineered 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) programpiping elements exposed will be used to manage wall thinning of theto treated water, treated carbon or low alloy steel with stainless steelwater (borated)
- cladding, carbon steel, and stainless steelpiping, piping components, and pipingelements exposed to treated water in theHigh Pressure Core Spray System, LowPressure Core Spray System, and ReactorCore Isolation Cooling System.LaSalle County,%Wion, Units 1 and 2License 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 FeaturesItem 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 towaste water address recurring internalcorrosion 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 aluminumthe scope of Chapter cracking Tanks" tan e n the ste o r a inmXI.M29, "Aboveground tanks (within the scope of Chapter XI.M29,Metallic Tanks") exposed "Aboveground Metallic Tanks") exposed toto soil or concrete, or the soil or concrete, or exposed to externaltosolorowin rexteornenvironments of air-outdoor, air-indoor following external uncontrolled, moist air, or condensation inair-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 ofXI .M29, "Aboveground crevice corrosion aluminum tanks (within the scope ofMetallic Tanks") exposed Chapter XI.M29, "Aboveground MetallicMtalic Tanks"creteporhed Tanks") exposed to soil or concrete, orto soil or concrete, or the external environments of air-outdoor, air-environments air-outdoor, indoor uncontrolled, moist air, orair-indoor uncontrolled, condensation in Engineered Safetymoist 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 toexposed to condensation, corrosion XI.M29, "Aboveground condensation or air-outdoor in Engineered air-outdoor Metallic Tanks," (for Safety Features systems.tanks only) Sft etrsssesLaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-31 Section 3 -Aging Management Review ResultsTable 3.2.1 Summary of Aging Management Evaluations for the Engineered Safety FeaturesItem 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 orthe scope of Chapter only), pitting and Tanks" There a n kstelithinle s te ofXI.M29, "Aboveground crevice corrosion aluminum tanks (within the scope ofMetallic Tanks") exposed Chapter XI.M29, "Aboveground Metallicto treated water, treated Tanks") exposed to treated water or treatedborated water borated water in Engineered SafetyFeatures 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 tankstanks exposed to XI.M29, "Aboveground exposed to condensation or air-outdoor incondensation, air-outdoor Metallic Tanks," (for Engineered Safety Features systems.tanks only)LaSalle County,"ion, Units 1 and 2License Rene V Plication Page 3 ,
0 O Section 3 -Aging Manageint Review ResultsTable 3.2.2-1High Pressure Core Spray SystemSummary of Aging Management Evaluation Table 3.2.2-1 High Pressure Core Spray SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 ABoltingStainless Steel Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 ATreated 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, 1Flow Device Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 AUncontrolled (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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (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 Acomponents, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
_TLaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-33 Section 3 -Aging Management Review ResultsTable 3.2.2-1High Pressure Core Spray System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsLeakage BoundaryCarbon Steel Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16AWater Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16BI I t +Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneV.F.EP-18 3.2.1-63ATreated Water (Internal)
Cumulative FatigueDamageTLAAVII.E3.A-62 3.3.1-2A, 5Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17AI. +Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17B4.2EP7 3.2.-17-Pressure Boundary Carbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Comoonents (B.2.1 .24',V.D2.E-26 3.2.1-40ALubricating 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 BTreated Water (Internal)
Cumulative FatigueDamageTLAAV.D2.E-10 3.2.1-1A, 5Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16A4 +Water Chemistry (B.2.1 .2'V.D2.EP-60 3.2.1-168Glass Air- Indoor None None V.F.EP-15 3.2.1-60 AUncontrolled (External)
Lubricating Oil (Internal)
None None V.F.EP-16 3.2.1-60 AStainless SteelAir -IndoorUncontrolled (External)
NoneNoneV.F.EP-18 3.2.1-63ALaSalle County lon, Units 1 and 2License RenevWýlication Page 3.2-34 0 0 Section 3 -Aging Manag #t Review ResultsTable 3.2.2-1High Pressure Core Spray System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemL Management Piping, piping Pressure Boundary Stainless Steel Treated Water (Internal)
Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 5components, and Damagepiping 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 BZinc Air -Indoor None External Surfaces F, 3Uncontrolled (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 BPump 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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (B.2.1.10)
Carbon or Low Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 AAlloy 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 AI I_ (B.2.1.21)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-35 Section 3 -Aging Management Review ResultsTable 3.2.2-1High Pressure Core Spray System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AStainless Steel Corrosion (B.2.1.10)
CladdingStainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (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 BTreated 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 BPressure 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 BTreated 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 BValve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 AUncontrolled (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 BLaSalle Countyjon, Units 1 and 2License lication0 Page 3.2-36 Section 3 -Aging Manageent Review ResultsTable 3.2.2-1High Pressure Core Spray System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve Body Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 AUncontrolled (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 BStainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-37 Section 3 -Aging Management Review ResultsTable 3.2.2-1 High Pressure Core Spray System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 duringeach 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 agingeffects.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 3.2-38License Rene l lication 0Section 3 -Aging gemaent Review ResultsTable 3.2.2-2Low Pressure Core Spray SystemSummary of Aging Management Evaluation Table 3.2.2-2 Low Pressure Core Spray SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 ABoltingStainless Steel Treated Water Loss of Material Bolting Integrity (B.2.1.11)
V.D2.EP-73 3.2.1-17 E, 1, 2Bolting (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-122 3.2.1-15 A, 1Flow Device Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 AUncontrolled (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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (B.2.1.10)
Throttle Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 AUncontrolled (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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (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 Acomponents, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-39 Section 3 -Aging Management Review ResultsTable 3.2.2-2Low Pressure Core Spray System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemT _Management Piping, pipingcomponents, andpiping elementsLeakage Boundary Carbon SteelTreated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16AWater Chemistry (B.2.1.2)1 V.D2.EP-60 3.2.1-16BGlass Air- Indoor None None V.F.EP-15 3.2.1-60 AUncontrolled (External)
ITreated Water (Internal)
None None V.F.EP-29 3.2.1-60 AStainless SteelAir- IndoorUncontrolled (External)
NoneNoneV.F.EP-18 3.2.1-63ATreated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17AWater Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17BPressure Boundary Carbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
V.E.E-443.2.1-40ALubricating 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, 1Treated Water (Internal)
Cumulative FatigueDamageTLAAV.D2.E-10 3.2.1-1A, 5Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16AWater Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16BCopper Alloy withless than 15%ZincAir -IndoorUncontrolled (External)
NoneNoneV.F.EP-1 03.2.1-57A'F 4 .4. .4Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
VIII.A.SP-101 3.4.1-16A__________
____________
-_________
-_____________________________
- a. u _________
a _____LaSalle Units 1 and 2License Rene1 plication
.Page 3.2-40 9 0 Section 3 -Aging Manag Review ResultsTable 3.2.2-2Low Pressure Core Spray System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 Bcomponents, and less than 15%pipiping elements ZincGlass Air- Indoor None None V.F.EP-15 3.2.1-60 AUncontrolled (External)
Lubricating Oil (Internal)
None None V.F.EP-16 3.2.1-60 AStainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (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 BZinc Air -Indoor None External Surfaces F, 3Uncontrolled (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 BPump 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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 AL _ _ I__ _Corrosion (B.2.1.10)
, ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-41 Section 3 -Aging Management Review ResultsTable 3.2.2-2Low Pressure Core Spray System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (B.2.1.10)
Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (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, 1Treated 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 BPressure 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, 1Treated 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 BValve Body Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 AUncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
LaSalle ion, Units 1 and 2License Rene p lication0 Page 3.2-42 Section 3 -Aging Management Review ResultsTable 3.2.2-2Low Pressure Core Spray System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemI 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 BPressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 AUncontrolled (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 BStainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-43 Section 3 -Aging Management Review ResultsTable 3.2.2-2 Low Pressure Core Spray System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 duringeach 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 agingeffects.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 3.2-44License ReneW W lication 0Section 3 -Aging #t Review ResultsTable 3.2.2-3Reactor Core Isolation Cooling SystemSummary of Aging Management Evaluation Table 3.2.2-3 Reactor Core Isolation Cooling SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 ABoltingStainless Steel Air -Indoor Loss of Material Bolting Integrity (8.2.1.11)
V.E.EP-70 3.2.1-13 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 ATreated 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, 1Flow Device Pressure Boundary Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (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 SideComponents LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-45 Section 3 -Aging Management Review ResultsTable 3.2.2-3Reactor Core Isolation Cooling System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 CComponents (B.2.1.21)
Copper Alloy with Air -Indoor None None V.F.EP-10 3.2.1-57 Cless 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 DHeat 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 ATransfer (B.2.1.21)
Water Chemistry (B.2.1.2)
VIII.E.SP-100 3.4.1-18 BPressure Boundary Copper Alloy with Lubricating Oil Loss of Material Lubricating Oil Analysis V.D2.EP-76 3.2.1-50 C15% Zinc or More (External)
(B.2.1.26)
One-Time Inspection V.D2.EP-76 3.2.1-50 CI I I I I__ _ _ _ _ _ _ _ (B.2.1.21)
I I I ILaSalle County.10jon, Units 1 and 2License RenevW lication.Page 3.2-46 Section 3 -Aging Management Review ResultsTable 3.2.2-3Reactor Core Isolation Cooling System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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, 7Loss 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 DSelective 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 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (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 Acomponents, 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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 BWall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 ACorrosion (B.2.1.10)
Glass Air -Indoor None None V.F.EP-15 3.2.1-60 AUncontrolled (External)
Treated Water (Internal)
None None V.F.EP-29 3.2.1-60 AStainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (External)
_LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-47 Section 3 -Aging Management Review ResultsTable 3.2.2-3Reactor Core Isolation Cooling System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsLeakage BoundaryStainless SteelTreated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17AWater Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17B4 4__ __ __ __ _ __ _ ---.E-- ---- 32.1-17 BPressure BoundaryCarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
V.E.E-443.2.1-40ALubricating 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 BWall Thinning Flow-Accelerated V.D2.E-07 3.2.1-11 ACorrosion (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, 1Treated Water (Internal)
Cumulative FatigueDamaaeTLAAV.D2.E-10 3.2.1-1A, 8Loss 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 BWall ThinningFlow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11AGlass Air -Indoor None None V.F.EP-15 3.2.1-60 AUncontrolled (External)
Lubricating Oil (Internal)
None None V.F.EP-16 3.2.1-60 ATreated Water (Internal)
None None V.F.EP-29 3.2.1-60 AStainless SteelAir -IndoorUncontrolled (External)
NoneNoneV.F.EP-18 3.2.1-63ALaSalle CountyAon, Units 1 and 2License Rene Page 3.2-48 Section 3 -Aging Management Review ResultsTable 3.2.2-3Reactor Core Isolation Cooling System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Stainless Steel Air -Outdoor (External)
Cracking External Surfaces V.D2.EP-103 3.2.1-7 Acomponents, and Monitoring of Mechanical piping elements Components (B.2.1.24)
Loss of Material External Surfaces V.D2.EP-107 3.2.1-4 AMonitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (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, 5Piping (B.2.1.28)
Loss of Material Buried and Underground V.D2.EP-72 3.2.1-53 APiping (B.2.1.28)
Treated Water (Internal)
Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 8DamageLoss 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 BZinc Air -Indoor None External Surfaces F, 3Uncontrolled (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 2License Renewal Application Page 3.2-49 Section 3 -Aging Management Review ResultsTable 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType 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 BSelective 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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 BPump 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 BLaSalle Countvtion, Units 1 and 2License Rene w p lication0Page 3.2-50 00Section 3 -Aging Management Review Results0 Section 3 -Aging Management Review ResultsTable 3.2.2-3Reactor Core Isolation Cooling System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy 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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (B.2.1.10)
Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (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 BWall Thinning Flow-Accelerated V.D2.E-408 3.2.1-65 ACorrosion (B.2.1.10)
Rupture Disks Pressure Boundary Nickel Alloy Air -Indoor None None V.F.EP-17 3.2.1-61 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-274 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (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 2License Renewal Application Page 3.2-51 Section 3 -Aging Management Review ResultsTable 3.2.2-3Reactor Core Isolation Cooling System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Strainer ElementFilterCarbon SteelTreated Water(External)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16A, 1Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16B, 1Treated Water (internal:
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16AWater Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16BStainless SteelTreated Water(External)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17A, 1Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17B, 1Treated Water (Internal Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17AWater Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17BPressure Boundary Carbon SteelLubricating Oil(External)
Loss of MaterialLubricating Oil Analysis(B.2.1.26)
V.D2.EP-77 3.2.1-49AOne-Time Inspection (B.2.1.21)
V.D2.EP-77 3.2.1-49ALubricating 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, 1Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16AWater Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16BStainless SteelTreated Water(External)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17A, 1Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17B, 1Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17A__________________
a ____________________
a ________________
i _______________________
U _________________________
- i.
- A +/- +/- _________
LaSalle Countylion, Units 1 and 2License Rene~yP licationPage 3.2-52 Section 3 -Aging Management Review ResultsTable 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BTanks (Turbine Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.E.E-44 3.2.1-40 ALube 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, 6Service Level IIIAugmented CoatingsMonitoring andMaintenance 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 ATank) 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 CSurfaces in Miscellaneous Piping and DuctingComponents (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 DSelective 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 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-53 Section 3 -Aging Management Review ResultsTable 3.2.2-3Reactor Core Isolation Cooling System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManMgement Valve BodyLeakage BoundaryCarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
V.E.E-443.2.1-40ACondensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16A-4 4 I.Water Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16BWall ThinningFlow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11A4 1- 1 + 4 4Pressure Boundary I Carbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Comoonents (B.2.1 .24)V.E.E-443.2.1-40ACondensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 ASurfaces in Miscellaneous Piping and DuctingComponents (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 BWall Thinning Flow-Accelerated V.D2.E-07 3.2.1-11 ACorrosion (B.2.1.10)
Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-60 3.2.1-16AWater Chemistry (B.2.1.2)
V.D2.EP-60 3.2.1-16BWall ThinningFlow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11ALaSalle County on, Units 1 and 2License ReneW plication Page 3.2-54 0Section 3 -Aging Management Review ResultsTable 3.2.2-3Reactor Core Isolation Cooling System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve Body Pressure Boundary Stainless Steel Air -Outdoor (External)
Cracking External Surfaces V.D2.EP-103 3.2.1-7 AMonitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces V.D2.EP-107 3.2.1-4 AMonitoring 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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-55 Section 3 -Aging Management Review ResultsTable 3.2.2-3 Reactor Core Isolation Cooling System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 duringeach 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 agingeffects.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 3.2-56License Rene Wplication 0 0 0 0 Section 3- Aging Managelnt Review ResultsTable 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 andService Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable tocarbon 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 2License Renewal Application Page 3.2-57 Section 3 -Aging Management Review ResultsTable 3.2.2-4Residual Heat Removal SystemSummary of Aging Management Evaluation Table 3.2.2-4 Residual Heat Removal SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 ABoltingStainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
V.E.EP-70 3.2.1-13 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 ATreated 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, 1Flow Device Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 AUncontrolled (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 BNickel Alloy Air- Indoor None None V.F.EP-17 3.2.1-61 AUncontrolled (External)
Treated Water (Internal)
Loss of Material One-Time Inspection G, 3(B.2.1.21)
Water Chemistry (B.2.1.2)
G, 3Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (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 BLaSalle Countvlon, Units 1 and 2License Rene V P lication.Page 3.2-58 0 0 Section 3- Aging Management Review ResultsTable 3.2.2-4Residual Heat Removal System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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, 3Stainless 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 BHeat 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 DHeat 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 DSheetHeat 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 BPressure 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 DHoses Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 AUncontrolled (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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-59 Section 3 -Aging Management Review ResultsTable 3.2.2-4Residual Heat Removal System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsLeakage BoundaryStainless SteelAir -IndoorUncontrolled (External)
NoneNoneV.F.EP-1 83.2.1-63ATreated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
V.D2.EP-73 3.2.1-17A4 + 4Water Chemistry (B.2.1.2)
V.D2.EP-73 3.2.1-17BPressure Boundary Carbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
V.D2.E-26 3.2.1-40ACondensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 ASurfaces in Miscellaneous Piping and DuctingComponents (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, 1Treated Water (Internal)
Cumulative FatigueDamaaeTLAAV.D2.E-10 3.2.1-1A, 4Loss 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 BWall ThinningFlow-Accelerated Corrosion (B.2.1.10)
V.D2.E-09 3.2.1-11AGlassAir -IndoorUncontrolled (External)
NoneNoneV.F.EP-15 3.2.1-60ALubricating Oil (Internal) 1None None I V.F.EP-16 3.2.1-60 1 ATreated Water (Internal)
NoneNoneV.F.EP-29 3.2.1-60ALaSalle County iion, Units 1 and 2License Rene plication 0 Page 3.2-60 0Section 3 -Aging Manageent Review ResultsTable 3.2.2-4 Residual Heat Removal System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 Acomponents, 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 BPump 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 BPump 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 BCarbon or Low Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 AAlloy 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 BStainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (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 BSpray Nozzles Spray Stainless Steel Air- Indoor None None V.F.EP-18 3.2.1-63 AI Uncontrolled (External)
ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-61 Section 3 -Aging Management Review ResultsTable 3.2.2-4 Residual Heat Removal System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemI E Management Spray Nozzles Spray Stainless Steel Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (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, 1Treated 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 BPressure 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, 1Treated 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 BValve Body Leakage Boundary Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (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 BPressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces V.D2.E-26 3.2.1-40 AUncontrolled (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 BWall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 ACorrosion (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 2License ReneW plication
.Page 3.2-62 Section 3 -Aging Management Review ResultsTable 3.2.2-4 Residual Heat Removal System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-63 Section 3 -Aging Management Review ResultsTable 3.2.2-4 Residual Heat Removal System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 eachISI 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 thiscomponent 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 2License ReneW plication O Page 3.2-64 Section 3 -Aging Management Review ResultsTable 3.2.2-5Standby Gas Treatment SystemSummary of Aging Management Evaluation Table 3.2.2-5 Standby Gas Treatment SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
V.E.EP-69 3.2.1-15 ABoltingGalvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 CUncontrolled (External)
Ducting and Leakage Boundary Stainless Steel Condensation Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 C, 1Components (External)
Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Aluminum Alloy Air -Indoor None None V.F.EP-3 3.2.1-56 CUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Carbon Steel Air -Indoor Loss of Material External Surfaces V.B.E-26 3.2.1-40 AUncontrolled (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 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-65 Section 3 -Aging Management Review ResultsTable 3.2.2-5Standby Gas Treatment System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Ducting and Pressure Boundary Elastomers Air -Indoor Hardening and Loss of External Surfaces V.B.EP-59 3.2.1-38 AComponents Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 2Strength Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Glass Air -Indoor None None V.F.EP-15 3.2.1-60 CUncontrolled (External)
Condensation (Internal)
None None V.F.EP-66 3.2.1-60 CFlexible Pressure Boundary Elastomers Air- Indoor Hardening and Loss of External Surfaces V.B.EP-59 3.2.1-38 AConnection Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.F1.AP-113 3.3.1-82 AMonitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 2Strength Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Loss of Material Inspection of Internal G, 2Surfaces in Miscellaneous Piping and DuctingComponents (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 Acomponents, and Uncontrolled (External)
Monitoring of Mechanical piping elements I I Components (B.2.1.24)
LaSalle Countyjion, Units 1 and 2License Rene V 1lication Page 3.2-66 Section 3 -Aging Management Review ResultsTable 3.2.2-5Standby Gas Treatment System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal V.D2.E-27 3.2.1-46 Acomponents, and Surfaces in Miscellaneous piping elements Piping and DuctingComponents (B.2.1.25)
Copper Alloy with Air -Indoor None None V.F.EP-10 3.2.1-57 Aless than 15% Uncontrolled (External)
Zinc Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Structural Integrity Carbon Steel Air- Indoor Loss of Material External Surfaces V.B.E-26 3.2.1-40 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Copper Alloy with Air -Indoor None None V.F.EP-10 3.2.1-57 A15% Zinc or More Uncontrolled (External) 1_1_1_1 _ 1LaSalle County Station, Units 1 and 2License Renewal Application Page 3.2-67 Section 3 -Aging Management Review ResultsTable 3.2.2-5Standby Gas Treatment System(Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve Body Pressure Boundary Copper Alloy with Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 A15% Zinc or More Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air -Indoor None None V.F.EP-18 3.2.1-63 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
ILaSalle Countwnion, Units 1 and 2License ReneW plication
.Page 3.2-68 Section 3 -Aging Management Review ResultsTable 3.2.2-5 Standby Gas Treatment System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 3.2-69License Renewal Application This Page Intentionally Left Blank Section 3 -Aging Management Review Results.3.33.3.1AGING MANAGEMENT OF AUXILIARY SYSTEMSINTRODUCTION 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 aredescribed 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 2License Renewal Application Page 3.3-1 Section 3 -Aging Management Review Results3.3.2 RESULTSThe 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 AgingManagement 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 AgingManagement 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 AgingManagement Evaluation LaSalle County Station, Units 1 and 2 Page 3.3-2License Renewal Application Section 3 -Aging Management Review ResultsTable 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 ofAging 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 AgingManagement ProgramsClosed Cycle Cooling Water SystemMaterials 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.3.3.2.13.3.2.1.1 LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-3 Section 3 -Aging Management Review ResultsEnvironments 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 OilAging Effects Requiring Management The following aging effects associated with the Closed Cycle Cooling Water Systemcomponents require management:
" Cracking* Loss of Material* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the ClosedCycle 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 SystemMaterials The materials of construction for the Combustible Gas Control System components are:* Carbon Steel" Carbon and Low Alloy Steel Bolting* GlassLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-4 Section 3 -Aging Management Review Results* Stainless Steel* Stainless Steel BoltingEnvironments The Combustible Gas Control System components are exposed to the following environments:
- Air -Indoor Uncontrolled
" Condensation
- Waste WaterAging Effects Requiring Management The following aging effects associated with the Combustible Gas Control Systemcomponents require management:
- Loss of Material" Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for theCombustible 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 SystemMaterials 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% ZincEnvironments The Compressed Air System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Condensation LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-5 Section 3 -Aging Management Review ResultsAging Effects Requiring Management The following aging effects associated with the Compressed Air System components require management:
" Loss of Material* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for theCompressed 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 SystemMaterials 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 BoltingEnvironments The Control Rod Drive System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Condensation
- Lubricating Oil* Treated Water* Waste WaterAging Effects Requiring Management The following aging effects associated with the Control Rod Drive System components require management:
- Cumulative Fatigue Damage* Loss of MaterialLaSalle County Station, Units 1 and 2 Page 3.3-6License Renewal Application Section 3 -Aging Management Review Results* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the ControlRod 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 SystemMaterials 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 BoltingEnvironments 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 3.3-7License Renewal Application Section 3 -Aging Management Review Results* Lubricating Oil* Waste WaterAging Effects Requiring Management The following aging effects associated with the Control Room Ventilation Systemcomponents require management:
" Hardening and Loss of Strength" Loss of Material" Loss of Preload* Reduction of Heat TransferAging Management ProgramsThe following aging management programs manage the aging effects for the ControlRoom 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 SystemMaterials The materials of construction for the Cranes, Hoists and Refueling Equipment Systemcomponents are:* Aluminum Alloy* Carbon Steel* Carbon and Low Alloy Steel Bolting* Stainless Steel* Stainless Steel BoltingEnvironments The Cranes, Hoists and Refueling Equipment System components are exposed to thefollowing environments:
- Air -Indoor Uncontrolled
" Treated WaterLaSalle County Station, Units 1 and 2 Page 3.3-8License Renewal Application Section 3 -Aging Management Review ResultsAging 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 PreloadAging Management ProgramsThe 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)
HandlingSystems (B.2.1.14)
- TLAA" Water Chemistry (B.2.1.2) 3.3.2.1.7 Demineralized Water Makeup SystemMaterials 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 SteelEnvironments The Demineralized Water Makeup System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Treated WaterLaSalle County Station, Units 1 and 2 Page 3.3-9License Renewal Application Section 3 -Aging Management Review ResultsAging Effects Requiring Management The following aging effects associated with the Demineralized Water Makeup Systemcomponents require management:
- Cracking* Loss of Coating Integrity
- Loss of Material" Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for theDemineralized 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 andMaintenance Program (B.2.2.1)
- Water Chemistry (B.2.1.2) 03.3.2.1.8 Diesel Generator and Auxiliaries SystemMaterials The materials of construction for the Diesel Generator and Auxiliaries Systemcomponents 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 BoltingLaSalle County Station, Units 1 and 2 Page 3.3-10License Renewal Application Section 3 -Aging Management Review ResultsEnvironments 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 WaterAging Effects Requiring Management The following aging effects associated with the Diesel Generator and Auxiliaries Systemcomponents require management:
- Cracking* Cumulative Fatigue Damage* Hardening and Loss of Strength* Loss of Material* Loss of Preload" Reduction of Heat TransferAging Management ProgramsThe following aging management programs manage the aging effects for the DieselGenerator 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 3.3-11License Renewal Application Section 3 -Aging Management Review Results" One-Time Inspection (B.2.1.21)
" Selective Leaching (B.2.1.22)
" TLAA3.3.2.1.9 Drywell Pneumatic SystemMaterials 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 BoltingEnvironments 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 WaterAging 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 PreloadLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-12 Section 3 -Aging Management Review ResultsAging Management ProgramsThe following aging management programs manage the aging effects for the DrywellPneumatic 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 SystemMaterials The materials of construction for the Electrical Penetration Pressurization Systemcomponents are:" Carbon Steel* Stainless SteelEnvironments The Electrical Penetration Pressurization System components are exposed to thefollowing environments:
" Air -Indoor Uncontrolled
" Air/Gas -DryAging Effect Requiring Management The following aging effect associated with the Electrical Penetration Pressurization System components requires management:
- Loss of MaterialAging Management ProgramThe 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 2License Renewal Application Page 3.3-13 Section 3 -Aging Management Review Results3.3.2.1.11 Essential Cooling Water SystemMaterials 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 BoltingEnvironments 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 WaterAging Effects Requiring Management The following aging effects associated with the Essential Cooling Water Systemcomponents require management:
- Cracking* Loss of Coating Integrity
- Loss of Material" Loss of Preload* Reduction of Heat TransferLaSalle County Station, Units 1 and 2 Page 3.3-14License Renewal Application Section 3 -Aging Management Review ResultsAging Management ProgramsThe 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 andMaintenance Program (B.2.2.1)
- Water Chemistry (B.2.1.2) 3.3.2.1.12 Fire Protection SystemMaterials 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 3.3-15License Renewal Application Section 3 -Aging Management Review Results" Reinforced Concrete* Stainless Steel* Stainless Steel BoltingEnvironments The Fire Protection System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Air -Outdoor* Air/Gas -Dry* Condensation
" Diesel Exhaust* Raw Water* SoilAging 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 PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the FireProtection 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 3.3-16License Renewal Application Section 3 -Aging Management Review Results" Selective Leaching (B.2.1.22)
- Service Level III and Service Level III Augmented Coatings Monitoring andMaintenance Program (B.2.2.1)
- Structures Monitoring (B.2.1.34)
" TLAA3.3.2.1.13 Fuel Pool Cooling and Storage SystemMaterials 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 BoltingEnvironments The Fuel Pool Cooling and Storage System components are exposed to the following environments:
" Air -Indoor Uncontrolled
- Condensation
" Treated Water" Waste WaterAging Effects Requiring Management The following aging effects associated with the Fuel Pool Cooling and Storage Systemcomponents require management:
- Loss of Material* Loss of Preload* Reduction of Neutron Absorbing Capacity; Change in Dimensions and Loss ofMaterialLaSalle County Station, Units 1 and 2 Page 3.3-17License Renewal Application Section 3 -Aging Management Review ResultsAging Management ProgramsThe following aging management programs manage the aging effects for the Fuel PoolCooling 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 SystemMaterials 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 SteelEnvironments The Nonessential Cooling Water System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Air -Outdoor" Air/Gas -Dry" Concrete* Condensation
- Raw Water" SoilLaSalle County Station, Units 1 and 2 Page 3.3-18License Renewal Application Section 3 -Aging Management Review ResultsAging Effects Requiring Management The following aging effects associated with the Nonessential Cooling Water Systemcomponents require management:
- Cracking* Loss of Coating Integrity
- Loss of Material* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for theNonessential 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 andMaintenance Program (B.2.2.1) 3.3.2.1.15 Nonsafety-Related Ventilation SystemMaterials 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 SteelEnvironments The Nonsafety-Related Ventilation System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Air/Gas -Dry* Closed Cycle Cooling WaterLaSalle County Station, Units 1 and 2 Page 3.3-19License Renewal Application Section 3 -Aging Management Review Results* Condensation Aging Effects Requiring Management The following aging effects associated with the Nonsafety-Related Ventilation Systemcomponents require management:
" Loss of Material* Loss of PreloadAging Management ProgramsThe 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 SystemMaterials 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 SteelEnvironments The Plant Drainage System components are exposed to the following environments:
" Air -Indoor Uncontrolled
" Concrete* Condensation
- Waste WaterLaSalle County Station, Units 1 and 2 Page 3.3-20License Renewal Application Section 3 -Aging Management Review ResultsAging 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 PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the PlantDrainage 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 andMaintenance Program (B.2.2.1) 3.3.2.1.17 Primary Containment Ventilation SystemMaterials The materials of construction for the Primary Containment Ventilation Systemcomponents 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 SteelEnvironments The Primary Containment Ventilation System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Air/Gas -Dry* Closed Cycle Cooling Water" Condensation
" Lubricating OilLaSalle County Station, Units 1 and 2 Page 3.3-21License Renewal Application Section 3 -Aging Management Review Results* Waste WaterAging Effects Requiring Management The following aging effects associated with the Primary Containment Ventilation Systemcomponents require management:
- Loss of Material" Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the PrimaryContainment 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 SystemMaterials 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 BoltingEnvironments The Process Radiation Monitoring System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Closed Cycle Cooling WaterLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-22 Section 3 -Aging Management Review Results* Condensation
" Raw Water" Waste WaterAging Effects Requiring Management The following aging effects associated with the Process Radiation Monitoring Systemcomponents require management:
- Loss of Material* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the ProcessRadiation 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 SystemMaterials 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 BoltingLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-23 Section 3 -Aging Management Review ResultsEnvironments The Process Sampling and Post Accident Monitoring System components are exposedto the following environments:
- Air -Indoor Uncontrolled
- Air/Gas -Dry* Closed Cycle Cooling Water* Condensation
" Treated Water* Waste WaterAging Effects Requiring Management The following aging effects associated with the Process Sampling and Post AccidentMonitoring System components require management:
" Loss of Material* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the ProcessSampling 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 SystemMaterials The materials of construction for the Radwaste System components are:* Carbon Steel" Carbon and Low Alloy Steel Bolting* Ductile Cast Iron* Stainless SteelLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-24 Section 3 -Aging Management Review Results* Stainless Steel BoltingEnvironments The Radwaste System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Condensation
- Treated WaterAging Effects Requiring Management The following aging effects associated with the Radwaste System components requiremanagement:
- Loss of Material" Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the RadwasteSystem 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 SystemMaterials 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 SteelLaSalle County Station, Units I and 2 Page 3.3-25License Renewal Application Section 3 -Aging Management Review ResultsEnvironments The Reactor Water Cleanup System components are exposed to the following environments:
" Air -Indoor Uncontrolled
- Treated Water* Treated Water > 140 FAging Effects Requiring Management The following aging effects associated with the Reactor Water Cleanup Systemcomponents require management:
- Cracking" Cumulative Fatigue Damage" Loss of Material* Loss of Preload* Wall ThinningAging Management ProgramsThe following aging management programs manage the aging effects for the ReactorWater 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 SystemMaterials 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 SteelLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-26 Section 3 -Aging Management Review Results* Stainless SteelEnvironments The Safety-Related Ventilation System components are exposed to the following environments:
" Air -Indoor Uncontrolled
- Condensation
- Waste WaterAging Effects Requiring Management The following aging effects associated with the Safety-Related Ventilation Systemcomponents require management:
" Hardening and Loss of Strength" Loss of Material* Reduction of Heat TransferAging Management ProgramsThe 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 SystemMaterials 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 BoltingLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-27 Section 3 -Aging Management Review ResultsEnvironments The Standby Liquid Control System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Condensation
- Sodium Pentaborate Solution" Treated Water" Waste WaterAging Effects Requiring Management The following aging effects associated with the Standby Liquid Control Systemcomponents require management:
- Cracking* Loss of Material* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for the StandbyLiquid 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 SystemMaterials 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 SteelEnvironments LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-28 Section 3 -Aging Management Review ResultsThe Suppression Pool Cleanup System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Treated WaterAging Effects Requiring Management The following aging effects associated with the Suppression Pool Cleanup Systemcomponents require management:
- Loss of Material* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for theSuppression 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 SystemMaterials The materials of construction for the Traversing Incore Probe System components are:0 Stainless SteelEnvironments 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 Systemcomponents requires management:
- Loss of Material3.3.2.1.25 LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-29 Section 3 -Aging Management Review ResultsAging Management ProgramsThe 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 ReportNUREG-1 801 provides the basis for identifying those programs that warrant furtherevaluation 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 DamageFatigue is a TLAA as defined in 10 CFR 54.3. TLAAs are required to be evaluated inaccordance with 10 CFR 54.21(c).
The evaluation of metal fatigue as a TLAA for theFeedwater System, High Pressure Core Spray System, Reactor Coolant PressureBoundary System, Reactor Core Isolation Cooling System, and Reactor Water CleanupSystem is discussed in Section 4.3. The evaluation of crane load cycles as a TLAA forthe 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 LoadingCracking due to SCC and cyclic loading could occur in stainless steel PWR non-regenerative heat exchanger components exposed to treated borated water greater than600C (>1400F) in the chemical and volume control system. The existing agingmanagement program on monitoring and control of primary water chemistry in PWRsmanages 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 notoccurring.
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 toensure 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 CrackingCracking due to stress corrosion cracking could occur for stainless steel piping, pipingcomponents, piping elements and tanks exposed to outdoor air. The possibility ofcracking 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 inenvironments containing sufficient halides (primarily chlorides) and in whichcondensation or deliquescence is possible.
Condensation or deliquescence shouldgenerally be assumed to be possible.
Applicable outdoor air environments (andassociated indoor air environments)
- include, but are not limited to, those withinapproximately 5 miles of a saltwater coastline, those within 1/2 mile of a highway whichLaSalle County Station, Units 1 and 2 Page 3.3-30License Renewal Application Section 3 -Aging Management Review Resultsis treated with salt in the wintertime, those areas in which the soil contains more thantrace chlorides, those plants having cooling towers where the water is treated withchlorine or chlorine compounds, and those areas subject to chloride contamination fromother 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 managethe aging effect. The applicant may demonstrate that this item is not applicable bydescribing the outdoor air environment present at the plant and demonstrating thatexternal chloride stress corrosion cracking is not expected.
The GALL Reportrecommends 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 thecomponents.
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 steelpiping, piping components, and piping elements exposed to outdoor air in the DieselGenerator and Auxiliaries System. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program provides for management of aging effects throughperiodic visual inspection of external surfaces for evidence of cracking.
Any visibleevidence 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 BreachLoss of material due to cladding breach could occur for PWR steel charging pumpcasings with stainless steel cladding exposed to treated borated water. The GALLReport references NRC Information Notice 94-63, "Boric Acid Corrosion of ChargingPump Casings Caused by Cladding Cracks,"
and recommends further evaluation of aplant-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 steelpiping, piping components, piping elements, and tanks exposed to outdoor air. Thepossibility of pitting and crevice corrosion also extends to components exposed to airwhich 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 notlimited to, those within approximately 5 miles of a saltwater coastline, those within 1/2LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-31 Section 3 -Aging Management Review Resultsmile of a highway which is treated with salt in the wintertime, those areas in which thesoil contains more than trace chlorides, those plants having cooling towers where thewater is treated with chlorine or chlorine compounds, and those areas subject to chloridecontamination from other agricultural or industrial sources.
This item is applicable for theenvironments described above.GALL AMP X1. M36, "External Surfaces Monitoring, "is an acceptable method to managethe aging effect. The applicant may demonstrate that this item is not applicable bydescribing the outdoor air environment present at the plant and demonstrating thatexternal pitting or crevice corrosion is not expected.
The GALL Report recommends further evaluation to determine whether an adequate aging management program isused to manage this aging effect based on the environmental conditions applicable to theplant and ASME Code Section X1 requirements Quality Assurance for AgingManagement 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 instainless steel piping, piping components, and piping elements exposed to outdoor air inthe Diesel Generator and Auxiliaries System. The External Surfaces Monitoring ofMechanical Components (B.2.1.24) program provides for management of aging effectsthrough periodic visual inspection of external surfaces for evidence of the loss ofmaterial.
Any visible evidence of the loss of material will be evaluated for acceptability ofcontinued service.
Deficiencies will be documented in accordance with the 10 CFR Part50, Appendix B Corrective Action Program.
The External Surfaces Monitoring ofMechanical 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 andAppendix 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 therecommendations in the GALL Report. During the search of plant-specific OE conducted during the LRA development, recurring internal corrosion can be identified by the numberof 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 revealsrepetitive 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 ormore sequential or nonsequential cycles for a 5-year OE search) of aging effects with thesame aging mechanism in which the aging effect resulted in the component either notmeeting 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 2License Renewal Application Page 3.3-32 Section 3 -Aging Management Review ResultsThe GALL Report recommends that a plant-specific AMP, or a new or existing AMP, beevaluated 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 onsusceptibility to aging effect and consequences of failure, a greater frequency ofinspections),
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 todetect the recurring aging effect before affecting the ability of a component to perform itsintended
- 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 whereincreased inspections would be implemented (e.g., the extent of degradation at individual corrosion sites, the rate of degradation change),
(d) how inspections of components thatare not easily accessed (i.e., buried, underground) will be conducted, and (e) how leaksin any involved buried or underground components will be identified.
Each plant-specific operating experience example should be evaluated to determine ifthe chosen AMP should be augmented even if the thresholds for significance of agingeffect 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 360degree 30 percent wall loss occurred at copper alloy to steel joints. Neither thesignificance of the aging effect nor the frequency of occurrence of aging effect threshold has been exceeded.
Nevertheless, the operating experience should be evaluated todetermine 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 providereasonable assurance that the CLB intended functions of the component will be metthroughout the period of extended operation.
- Likewise, the GALL Report AMR itemsassociated with the new FE items only cite raw water and waste water environments because OE indicates that these are the predominant environments associated withrecurring internal corrosion;
- however, if the search of plant-specific OE reveals recurring internal corrosion in other water environments (e.g., treated water), the aging effectshould be addressed in a similar manner.LR-ISG-2012-02 has been issued which addresses instances of recurring internalcorrosion identified during review of plant-specific operating experience.
The operating experience for LSCS has been reviewed and instances of internal corrosion in theEssential Cooling Water System, Nonessential Cooling Water System, Fire Protection System, and Plant Drainage System have been identified with a frequency that isconsistent 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 managethe loss of material due to recurring internal corrosion in above-ground and buriedcarbon steel piping exposed to raw water in the Essential Cooling Water System andNonessential Cooling Water System. A minimum of ten (10) MIC degradation LaSalle County Station, Units 1 and 2 Page 3.3-33License Renewal Application Section 3 -Aging Management Review Resultsinspections in aboveground Essential Cooling Water System piping and a minimumof ten (10) MIC degradation inspections in aboveground Nonessential Cooling WaterSystem piping will be performed every 24 months until the frequency of MICoccurrences no longer meets the criteria for recurring internal corrosion.
Theseinspections supplement those that are being performed to implement therequirements of GL 89-13. A portion of these inspection locations will be selectedwith process conditions similar (e.g. flow, temperature) to those in buried portions ofthe 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 ofmaterial due to recurring internal corrosion in above-ground and buried carbon steelpiping exposed to raw water in the Fire Protection System. Inspections will beperformed at five locations in aboveground piping susceptible to MIC every year untilthe frequency of MIC occurrences no longer meets the criteria for recurring internalcorrosion.
A portion of these inspection locations will be selected with processconditions similar (e. g. flow, temperature) to those in buried portions of the piping toprovide 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 exposedto waste water in the Plant Drainage System. Ten different locations will beinspected during each ten-year inspection period of this program.
Inspections willcontinue 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 areaat a minimum of three inches on either side of the location of interest.
The entireboundary of any area found thinned is recorded, even if it extends beyond the originalspecified examination area. When inspections identify multiple corrosion sites, they arereviewed to determine if they may be evaluated as separate flaws to assess thestructural 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 wallthickness or previous wall thickness measurements to determine rate of corrosion degradation, (2) a comparison to the design minimum allowable wall thickness todetermine the acceptability of the component for continued use, and (3) a determination of reinspection interval.
Additional locations will be examined if these examinations orplant operating experience identify significant degradation.
Where the degradation isidentified in ASME Section III portions of piping, the applicable ASME Section IIIrequirements for augmented examinations will be utilized.
Where the degradation isidentified 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 50percent 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 theEssential Cooling Water system, an operability evaluation is performed for degradedLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-34 Section 3 -Aging Management Review Resultsconditions that involve system leakage or the measured remaining pipe wall thickness isless than design thickness.
The operability evaluation includes reviews for loss of flow,water spraying on surrounding SSC, flooding, and potential for flaw propagation.
Basedon the operability evaluation, any appropriate compensatory actions are identified andimplemented until such time as repair or replacement is completed.
Deficiencies will be documented in accordance with the 10 CFR Part 50, Appendix BCorrective 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 inMiscellaneous Piping and Ducting Components (B.2.1.25) program are described inAppendix B.3.3.2.3 Time-Limited Aging AnalysisThe 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 Analysis3.
3.3 CONCLUSION
The Auxiliary Systems piping, fittings, and components that are subject to agingmanagement review have been identified in accordance with the requirements of 10 CFR54.4. The aging management programs selected to manage aging effects for theAuxiliary 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, alongwith the demonstration that the identified aging effects will be managed for the period ofextended operation.
Therefore, based on the conclusions provided in Appendix B, the effects of agingassociated with the Auxiliary Systems components will be adequately managed so thatthere is reasonable assurance that the intended functions are maintained consistent withthe current licensing basis during the period of extended operation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-35 This Page Intentionally Left Blank
- 0Section 3 -Aging Managementew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 isgirders 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 extendedoperation for structural girders of cranes that fallwithin the scope of 10CFR 54 (Standard Review Plan, Section 4.7,"Other Plant-Specific Time-Limited AgingAnalyses,"
for genericguidance for meeting therequirements of 10 CFR54.21 (c)(1))3.3.1-2 Stainless steel, Steel Cumulative fatigue Fatigue is a time-limited Yes, TLAA Fatigue is a TLAA; further evaluation isHeat exchanger damage aging analysis (TLAA) to documented in Subsection 3.3.2.2.1.
components and tubes, due to fatigue be evaluated for thePiping, piping period of extendedcomponents, and piping operation.
See the SRP,elements exposed to Section 4.3 "MetalTreated borated water, Fatigue,"
for acceptable Air -indoor, uncontrolled, methods for meeting theTreated water requirements of 10 CFR54.21 (c)(1).3.3.1-3 PWR OnlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-36 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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.
Thepiping 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 beexposed to Air -outdoor Components" used to manage cracking of stainless steelpiping, piping components, and pipingelements exposed to air -outdoor in theDiesel Generator and Auxiliaries System.See subsection 3.3.2.2.3.
3.3.1-5 PWR Only3.3.1-6 Stainless steel Piping, Loss of material Chapter XI.M36, Yes, environmental Consistent with NUREG-1801.
Thepiping 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 beexposed to Air -outdoor Components" used to manage loss of material ofstainless steel piping, piping components, and piping elements exposed to air -outdoor in the Diesel Generator andAuxiliaries System.See subsection 3.3.2.2.5.
3.3.1-7 PWR Only3.3.1-8 PWR OnlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-37 Section 3 -Aging Manag nteview ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-9 PWR Only3.3.1-10 Steel, high-strength Cracking Chapter XI.M18, "Bolting No Not Applicable.
Closure bolting exposed due to stress Integrity" There is no steel, high-strength closureto Air with steam or water corrosion cracking; tis nosed hith-steam oreleakage cyclic loading bolting exposed to air with steam or waterleakage 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 toleakage air with steam or water leakage in Auxiliary Systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-38 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 BoltingClosure bolting, Bolting due to general (steel Integrity" Integrity (B.2.1.11) program will be used toexposed to only), pitting, and manage loss of material of carbon and lowCondensation, Air -crevice corrosion alloy steel bolting and stainless steel boltingindoor, 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 DriveSystem, 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 StorageSystem, Nonessential Cooling WaterSystem, Nonsafety-Related Ventilation System, Plant Drainage System, PrimaryContainment Ventilation System, ProcessRadiation Monitoring System, ProcessSampling and Post Accident Monitoring System, Radwaste System, Reactor WaterCleanup System, Standby Liquid ControlSystem, and Suppression Pool CleanupSystem.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 toair with steam or water leakage in Auxiliary Systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-39 Section 3 -Aging Management~eview ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 BoltingBolting exposed to Soil Integrity" Integrity (B.2.1.11) program will be used tomanage loss of preload of the carbon andlow alloy steel bolting exposed to soil in theFire Protection System.3.3.1-15 Steel; stainless steel, Loss of preload Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The BoltingCopper alloy, Nickel due to thermal Integrity" Integrity (B.2.1.11) program will be used toalloy, Stainless steel effects, gasket creep, manage loss of preload of carbon and lowClosure bolting, Bolting and self-loosening alloy steel bolting and stainless steel boltingexposed to Air -indoor, exposed to air -indoor uncontrolled anduncontrolled (External),
raw water in the Closed Cycle CoolingAny environment, Air -Water System, Combustible Gas Controloutdoor (External),
Raw System, Compressed Air System, Controlwater, Treated borated Rod Drive System, Control Roomwater, Fuel oil, Treated Ventilation System, Demineralized Waterwater Makeup System, Diesel Generator andAuxiliaries System, Drywell Pneumatic System, Essential Cooling Water System,Fire Protection System, Fuel Pool Coolingand Storage System, Nonessential CoolingWater System, Nonsafety-Related Ventilation System, Plant Drainage System,Primary Containment Ventilation System,Process Radiation Monitoring System,Process Sampling and Post AccidentMonitoring System, Radwaste System,Reactor Water Cleanup System, StandbyLiquid Control System, and Suppression Pool Cleanup System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-40 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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,"
andpiping elements exposed corrosion
- cracking, Chapter XI.M25, "BWR The main process piping in the LSCSto Treated water >60'C intergranular stress Reactor Water Cleanup Reactor Water Cleanup (RWCU) System is(>140°F) corrosion cracking System" carbon steel. There are no stainless steelpiping, piping components, and pipingelements
-4 inch NPS exposed to treatedwater >60°C (>140°F).
Therefore, LSCSdoes not use the Chapter XI.M25, "BWRReactor Water Cleanup System" programto manage cracking.
Cracking in RWCU System stainless steelpiping, piping components, and pipingelements
< 4 inch NPS exposed to treatedwater >60'C (>140°F) is addressed in3.3.1-19.
3.3.1-17 Stainless steel Heat Reduction of heat Chapter XI.M2, 'Water No Not Applicable.
exchanger tubes transfer Chemistry,"
andexposed to Treated due to fouling Chapter XI.M32, "One- There are no stainless steel heatwater, Treated borated Time Inspection" exchanger tubes exposed to treated waterwater or treated borated water in Auxiliary Systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-41 0 9 Section 3 -Aging Managemeqiew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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,"
andPiping, 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 treatedTreated borated water borated water >60°C (>140°F) or sodium>60'C (>140'F),
Sodium pentaborate solution
>60. C (>140°F) inpentaborate solution Auxiliary Systems.>60oC (>140'F)3.3.1-19 Stainless steel Cracking Chapter XI.M2, 'Water No Consistent with NUREG-1801 withRegenerative 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°C (>140'F) cracking of the carbon or low alloy steelwith stainless steel cladding and stainless steel regenerative heat exchanger components, piping, piping components, and piping elements exposed to treatedwater > 140'F in the Reactor WaterCleanup System.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-42 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 withsteel; 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 manageexposed to Treated cracking of the carbon or low alloy steelborated water >60°C with stainless steel cladding and stainless
(>140°F),
Treated water steel non-regenerative heat exchanger
>60*C (>140°F) components exposed to treated water >140'F in the Reactor Water CleanupSystem.An exception applies to the NUREG-1801 recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-43 Section 3 -Aging ManagemenPeview ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 withcomponents, 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 manageloss of material of carbon steel, ductile castiron, and gray cast iron accumulator, heatexchanger components, piping, pipingcomponents, and piping elements, andtanks exposed to treated water in theControl Rod Drive System, Demineralized Water Makeup System, Fuel Pool Coolingand Storage System, Process Samplingand Post Accident Monitoring System,Radwaste System, Reactor Water CleanupSystem, and Suppression Pool CleanupSystem.An exception applies to the NUREG-1 801recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-44 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 withpiping 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 manageloss of material of copper alloy with 15%zinc or more and copper alloy with lessthan 15% zinc piping, piping components, and piping elements exposed to treatedwater in the Demineralized Water MakeupSystem and Standby Liquid ControlSystem.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 elementsTreated water Time Inspection" exposed to treated water is addressed in3.3.1-25.
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 elementsTreated water Time Inspection" exposed to treated water is addressed in3.3.1-25.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-45 0 0 .Section 3 -Aging Management ew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 withsteel; 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 managecomponents, and piping loss of material of aluminum, aluminumelements, Heat alloy, carbon or low alloy steel withexchanger components stainless steel cladding, and stainless steelexposed to Treated crane/hoist (fuel prep machine),
heatwater, Sodium exchanger components, miscellaneous pentaborate solution steel, piping, piping components, andpiping elements, and tanks exposed tosodium pentaborate
- solution, treated water,and treated water > 140°F in the ControlRod Drive System, Cranes, Hoists andRefueling Equipment System, Essential Cooling Water System, Fuel Pool Coolingand Storage System, Process Samplingand Post Accident Monitoring System,Radwaste System, Reactor Water CleanupSystem, Standby Liquid Control System,Suppression Pool Cleanup System, andStructural Commodity Group.An exception applies to the NUREG-1 801recommendations for Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-46 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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,"
andelsoe iigor crevice corrosion Chapter XI.M32, "One- There are no steel (with elastomer lining)elastomer lining orceiecroin CatrXI3,"n-piping, piping components, and pipingstainless steel cladding)
(only for steel after Time Inspection" elements exposed to treated water inPiping, 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 treatedwater 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 withexchanger 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 managereduction of heat transfer of stainless steelheat exchanger tubes exposed to treatedwater in the Essential Cooling WaterSystem.An exception applies to the NUREG-1 801recommendations for Water Chemistry (B.2.1.2) program implementation.
3.3.1-28 PWR Only3.3.1-29 PWR OnlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-47 Section 3 -Aging Managementeiew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 Watercomponents, and piping due to aggressive System" There are no concrete; cementitious elements exposed to chemical attack material piping, piping components, andelemnts ed tpiping elements exposed to raw water inRaw 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 pipingeto Raw water (internal) absorption piping components, and piping elementsexposed 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 Watercomponents, and piping System" There are no concrete; cementitious elements exposed to material piping, piping components, andRaw Water piping elements exposed to raw water inAuxiliary 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, asbestospiping components, and chemical attack and System" cement piping, piping components, andpiping elements exposed leaching; c ement exp osed tompon e r into Raw water Changes in material piping elements exposed to raw water inproperties Auxiliary Systems.due to aggressive chemical attackLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-48 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 andraw water elastomer System" components exposed to raw water indegradation; loss of Auxiliary Systems.material due toerosion3.3.1-33 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, andelements exposed to chemical attack, and piping pipin g ompone r inRaw Water leaching piping elements exposed to raw water inAuxiliary 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 Watercomponents, and piping pitting, and crevice System" There are no nickel alloy piping, pipingelements exposed to corrosion components, and piping elements exposedRaw water to raw water in Auxiliary Systems.
The lossof material in copper alloy piping, pipingcomponents, and piping elements exposedto 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 elementsinfluenced corrosion exposed to raw water is addressed in 3.3.1-36.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-49 Section 3 -Aging Managementeiew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 ofto Raw water microbiologically-material of copper alloy with less than 15%influenced corrosion; zinc piping, piping components, and pipingfouling that leads to elements exposed to raw water in thecorrosion Nonessential Cooling Water System andProcess 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 ofelements exposed to microbiologically-material of carbon steel (with internalRaw water influenced corrosion; coating) and carbon steel (with externalfouling that leads to coating) heat exchanger components, corrosion; piping, piping components, and pipinglining/coating
- elements, and traveling water screendegradation framework exposed to raw water in theEssential Cooling Water System andNonessential 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 waterscreen framework is managed by theService Level III and Service Level IIIAugmented Coatings Monitoring andMaintenance Program (B.2.2.1) plant-specific program.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-50 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 ofgalvanic, and material of carbon steel, copper alloy withmicrobiologically-15% zinc or more, copper alloy with 15%influenced corrosion; zinc or more (with internal coating),
copperfouling that leads to alloy with less than 15% zinc, and gray castcorrosion iron traveling water screen framework, heat exchanger components, piping, pipingcomponents, and piping elements exposedto raw water in the Essential Cooling WaterSystem and Nonessential Cooling WaterSystem.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 steelpiping elements exposed crevice corrosion System" Thn poss omatentstand steelto Raw water piping, piping components, and pipingelements exposed to raw water isaddressed in 3.3.1-40.
LaSalle County Station, Units 1 and 2License Renewal Application 0Page 3.3-51 0 0 Section 3-Aging Managernenteiew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 ofto Raw water fouling that leads to material of carbon or low alloy steel withcorrosion stainless steel cladding and stainless steelfish barrier, heat exchanger components, piping, piping components, and pipingelements in the Essential Cooling WaterSystem, Nonessential Cooling WaterSystem, 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 Powerpiping elements exposed and microbiologically-System" Plants (B.2.1.35) program has beento Raw water influenced corrosion substituted and will be used to manage theloss of material in stainless steel concreteanchors exposed to raw water in the LakeScreen 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 with15% zinc or more, copper alloy with lessthan 15% zinc, and stainless steel heatexchanger tubes exposed to raw water inthe Essential Cooling Water System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-52 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsComponent Aging Effect/ Aging Management Further Discussion Mechanism Programs Evaluation Recommended Stainless steel Piping, Cracking Chapter XI.M21A, No Consistent with NUREG-1801.
The Closedpiping components, and due to stress "Closed Treated Water Treated Water Systems (B.2.1.13) programpiping elements exposed corrosion cracking Systems" will be used to manage cracking ofto Closed-cycle cooling stainless steel piping, piping components, water >60*C (>140°F) and piping elements exposed to closedcycle cooling water > 140°F in the ClosedCycle Cooling Water System.Stainless steel; steel with Cracking Chapter XI.M21A, No Consistent with NUREG-1801.
The Closedstainless steel cladding due to stress "Closed Treated Water Treated Water Systems (B.2.1.13) programHeat exchanger corrosion cracking Systems" will be used to manage cracking ofcomponents exposed to stainless steel heat exchanger components Closed-cycle cooling exposed to closed cycle cooling water >water >60°C (>140°F) 140'F in the Closed Cycle Cooling WaterSystem.Steel Piping, pipingcomponents, and pipingelements; tanks exposedto Closed-cycle coolingwaterLoss of materialdue to general,pitting, and crevicecorrosion Chapter XI.M21A,"Closed Treated WaterSystems"NoConsistent with NUREG-1801.
The ClosedTreated Water Systems (B.2.1.13) programwill be used to manage loss of material ofcarbon steel, ductile cast iron, and graycast iron piping, piping components, andpiping elements and tanks exposed toclosed cycle cooling water in the ClosedCycle Cooling Water System, DieselGenerator and Auxiliaries System, DrywellPneumatic System, Nonsafety-Related Ventilation System, Primary Containment Ventilation System, and Process Samplingand Post Accident Monitoring System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-530 Section 3 -Aging Managementview ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsComponent Aging Effect/ Aging Management Further Discussion Mechanism Programs Evaluation Recommended Steel, Copper alloy Heatexchanger components, Piping, pipingcomponents, and pipingelements exposed toClosed-cycle coolingwaterLoss of materialdue to general,pitting,
- crevice, andgalvanic corrosion Chapter XI.M21A,"Closed Treated WaterSystems"NoConsistent with NUREG-1 801. The ClosedTreated Water Systems (B.2.1.13) programwill be used to manage loss of material ofcarbon steel, copper alloy with 15% zinc ormore, copper alloy with less than 15% zinc,and gray cast iron heat exchanger components, piping, piping components, and piping elements exposed to closedcycle cooling water in the Closed CycleCooling 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 notHeat exchanger microbiologically-Systems" a predicted aging mechanism for the loss ofcomponents exposed to influenced corrosion material in the closed cycle cooling waterClosed-cycle cooling environment.
The loss of material inwater stainless steel heat exchanger components exposed to closed cycle cooling water isaddressed 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, pipingelements exposed to crevice corrosion Systems" componeno a nd piping p osedClosed-cycle cooling components, and piping elements exposedwater to closed-cycle cooling water in Auxiliary Systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-54 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 Closedpiping components, and due to pitting and "Closed Treated Water Treated Water Systems (B.2.1.13) programpiping elements exposed crevice corrosion Systems" will be used to manage loss of material ofto Closed-cycle cooling stainless steel heat exchanger water components, piping, piping components, and piping elements exposed to closedcycle cooling water and closed cyclecooling water > 140'F in the Closed CycleCooling Water System, Diesel Generator and Auxiliaries System, Nonsafety-Related Ventilation System, Primary Containment Ventilation System, Process Radiation Monitoring System, and Process Samplingand Post Accident Monitoring System.3.3.1-50 Stainless steel, Copper Reduction of heat Chapter XL.M21A, No Consistent with NUREG-1801.
The ClosedAlloy, Steel Heat transfer "Closed Treated Water Treated Water Systems (B.2.1.13) programexchanger tubes due to fouling Systems" will be used to manage reduction of heatexposed to Closed-cycle transfer of copper alloy with 15% zinc orcooling water more heat exchanger tubes exposed toclosed cycle cooling water in the DieselGenerator 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 neutronabsorbing 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 forTreated borated water, neutron absorption.
The reduction inTreated w war neutron absorbing capacity for boral andrio-tinto alcan composite is addressed inItem Number 3.3.1-102.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-55 0 0 Section 3 -Aging Managementeview ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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.
Thestructural girders due to general "Inspection of Overhead Inspection of Overhead Heavy Load andexposed to Air -indoor, corrosion Heavy Load and Light Light Load (Related to Refueling)
Handlinguncontrolled (External)
Load (Related to Systems (B.2.1.14) program will be used toRefueling)
Handling manage loss of material of carbon steelSystems" crane/hoist components exposed to air -indoor uncontrolled in the Cranes, Hoistsand Refueling Equipment System.3.3.1-53 Steel Cranes -rails Loss of material Chapter XI.M23, No Consistent with NUREG-1801.
Theexposed to Air -indoor, due to wear "Inspection of Overhead Inspection of Overhead Heavy Load anduncontrolled (External)
Heavy Load and Light Light Load (Related to Refueling)
HandlingLoad (Related to Systems (B.2.1.14) program will be used toRefueling)
Handling manage loss of material of carbon steelSystems" crane/hoist components exposed to air -indoor uncontrolled in the Cranes, Hoistsand Refueling Equipment System.3.3.1-54 Copper alloy Piping, Loss of material Chapter XI.M24, No Consistent with NUREG-1801.
Thepiping 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 ofto Condensation corrosion material of the copper alloy piping, pipingcomponents, and piping elements exposedto condensation in the Compressed AirSystem..LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-56 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 withcomponents, and piping due to general and "Compressed Air exceptions.
The Compressed Airelements:
compressed pitting corrosion Monitoring" Monitoring (B.2.1.15) program will be usedair system exposed to to manage loss of material of carbon steelCondensation (Internal) piping, piping components, and pipingelements exposed to condensation in theCompressed Air System.An exception applies to the NUREG-1801 recommendations for Compressed AirMonitoring (B.2.1.15) programimplementation.
3.3.1-56 Stainless steel Piping, Loss of material Chapter XI.M24, No Consistent with NUREG-1 801 withpiping components, and due to pitting and "Compressed Air exceptions.
The Compressed Airpiping elements exposed crevice corrosion Monitoring" Monitoring (B.2.1.15) program will be usedto Condensation to manage loss of material of stainless steel(Internal) accumulators, piping, piping components, and piping elements exposed tocondensation in the Drywell Pneumatic System and Traversing Incore ProbeSystem.An exception applies to the NUREG-1 801recommendations for Compressed AirMonitoring (B.2.1.15) programimplementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-570 Section 3 -Aging Managementew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 Firepenetration seals shrinkage; loss of Protection" Protection (B.2.1.16) program will be usedexposed to Air -indoor, strength to manage change in material properties ofuncontrolled, Air -due to weathering elastomers fire barriers (penetration sealsoutdoor and fire stops) exposed to air -indooruncontrolled 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 Firedioxide fire suppression due to general, Protection" Protection (B.2.1.16) program will be usedsystem piping, piping pitting, and crevice to manage loss of material of carbon steelcomponents, and piping corrosion and gray cast iron carbon dioxide fireelements 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 firesuppression systems at LSCS.3.3.1-59 Steel Fire rated doors Loss of material Chapter XI.M26, "Fire No Consistent with NUREG-1801.
The Fireexposed to Air -indoor, due to wear Protection" Protection (B.2.1.16) program will be useduncontrolled, Air -to manage loss of material of carbon steeloutdoor 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 2License Renewal Application Page 3.3-58 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 FireStructural fire barriers:
and spalling Protection,"
and Protection (B.2.1.16) program andwalls, ceilings and floors due to aggressive Chapter Xl.S6, Structures Monitoring (B.2.1.34) programexposed to Air -indoor, chemical attack, and "Structures Monitoring" will be used to manage concrete crackinguncontrolled reaction with and spalling and cracking of concrete block,aggregates grout, and reinforced concrete fire barriers(penetration seals and fire stops) and firebarriers (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 FireStructural fire barriers:
material Protection,"
and Protection (B.2.1.16) program andwalls, ceilings and floors due to freeze-thaw, Chapter XI.S6, Structures Monitoring (B.2.1.34) programexposed to Air -outdoor aggressive chemical "Structures Monitoring" will be used to manage concrete crackingattack, and reaction and spalling of reinforced concrete firewith 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 FireStructural fire barriers:
due to corrosion of Protection,"
and Protection (B.2.1.16) program andwalls, ceilings and floors embedded steel Chapter XL.S6, Structures Monitoring (B.2.1.34) programexposed to Air -indoor, "Structures Monitoring" will be used to manage loss of material ofuncontrolled, Air -embedded steel in reinforced concrete fireoutdoor barriers (walls and slabs) exposed to air -indoor uncontrolled and air -outdoor in theFire Protection System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-59 Section 3 -Aging Manageme View ResultsTable 3.3.1Summary of Aging Management Evaluations for the Auxiliary SystemsItemNumberComponent
+ 1-3.3.1-63Steel Fire Hydrantsexposed to Air -outdoorLoss of materialdue to general,pitting, and crevicecorrosion Chapter XI.M27, "FireWater System"NoDiscussion Consistent with NUREG-1 801 withexceptions.
The Fire Water System(B.2.1.17) program will be used to manageloss of material of ductile cast iron firehydrants exposed to air -outdoor in theFire Protection System.Exceptions apply to the NUREG-1 801recommendations for Fire Water System(B.2.1.17) program implementation.
i i i i3.3.1-64Steel, Copper alloyPiping, pipingcomponents, and pipingelements exposed toRaw waterLoss of materialdue to general,pitting,
- crevice, andmicrobiologically-influenced corrosion; fouling that leads tocorrosion; flowblockage due tofoulingChapter XI.M27, "FireWater System"NoConsistent with NUREG-1 801 withexceptions.
The Fire Water System(B.2.1.17) program will be used to manageloss of material of carbon steel, copperalloy with less than 15% zinc, ductile castiron, galvanized steel, and gray cast ironpiping, piping components, and pipingelements and tanks exposed to raw waterin the Fire Protection System.Exceptions apply to the NUREG-1 801recommendations for Fire Water System(B.2.1.17) program implementation.
The Bolting Integrity (B.2. 1.11) programhas been substituted and will be used tomanage loss of material of carbon and lowalloy steel bolting exposed to raw water inthe Nonessential Cooling Water Systemand Fire Protection System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-60 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 Systemcomponents, 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 materialRaw water fouling that leads to in aluminum alloy piping, pipingcorrosion; flow components, and piping elements exposedblockage due to to raw water in the Nonessential Coolingfouling Water System.3.3.1-66 Stainless steel Piping, Loss of material Chapter Xl.M27, "Fire No Consistent with NUREG-1801 withpiping components, and due to pitting and Water System" exceptions.
The Fire Water Systempiping elements exposed crevice corrosion; (B.2.1.17) program will be used to manageto Raw water fouling that leads to loss of material of stainless steel piping,corrosion; flow piping components, and piping elementsblockage due to exposed to raw water in the Fire Protection fouling System.Exceptions apply to the NUREG-1 801recommendations 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 2License Renewal Application Page 3.3-61 Section 3 -Aging Management~eview ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 elementsFuel oil corrosion Time Inspection" exposed to fuel oil is addressed in ItemNumber 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 Fuelpiping 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 beto Fuel oil microbiologically-Time Inspection" used to manage loss of material of copperinfluenced corrosion alloy with 15% zinc or more and copperalloy with less than 15% zinc piping, pipingcomponents, and piping elements exposedto fuel oil in the Diesel Generator andAuxiliaries System.3.3.1-70 Steel Piping, piping Loss of material Chapter XI.M30, "Fuel Oil No Consistent with NUREG-1801.
The Fuelcomponents, 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 beto Fuel oil microbiologically-Time Inspection" used to manage loss of material of carboninfluenced corrosion; steel and gray cast iron piping, pipingfouling that leads to components, and piping elements andcorrosion tanks exposed to fuel oil in the DieselGenerator and Auxiliaries System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-62 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 FuelAluminum 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 beelements exposed to influenced corrosion Time Inspection" used to manage loss of material ofFuel oil stainless steel piping, piping components, and piping elements exposed to fuel oil inthe 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. Thealloy (>15% Zn or >8% due to selective "Selective Leaching" Selective Leaching (B.2.1.22) program willAl) Piping, piping leaching be used to manage loss of material ofcomponents, and piping copper alloy with 15% zinc or more, copperelements, Heat alloy with 15% zinc or more (with internalexchanger components coating),
and gray cast iron traveling waterexposed to Treated screen framework, heat exchanger water, Closed-cycle components, piping, piping components, cooling water, Soil, Raw and piping elements, and tanks exposed towater, Waste water closed cycle cooling water, raw water, soil,treated water, and waste water in theClosed 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 WaterSystem, Primary Containment Ventilation System, Process Sampling and PostAccident Monitoring System, Reactor CoreIsolation Cooling System, Standby LiquidControl System, and Suppression PoolCleanup System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-630 Section 3- Aging Manageme iew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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, andelements exposed to Air -chemical attack Components" piping pipin g compouts, inoutdoor piping elements exposed to air -outdoor inAuxiliary 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, andelements exposed to Air -Components"maeilpiniigcooetsad ouentdr epiping elements exposed to air -outdoor inoutdoor Auxiliary Systems.3.3.1-75 Reinforced
- concrete, Cracking Chapter XI.M36, No Not Applicable.
asbestos cement Piping, due to aggressive "External Surfacespiping components, and chemical attack and Monitoring of Mechanical There are no reinforced
- concrete, asbestospiping elements exposed leaching; Components" cement piping, piping components, andto Air -outdoor Changes in material piping elements exposed to air -outdoor inproperties Auxiliary Systems.due to aggressive chemical attack3.3.1-76 Elastomers Elastomer:
Hardening and loss of Chapter XL.M36, No Consistent with NUREG-1 801. Theseals 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 beuncontrolled degradation Components" used to manage hardening and loss of(Internal/External) strength of elastomer seals andcomponents exposed to air -indooruncontrolled in the Control RoomVentilation System, Diesel Generator andAuxiliaries System, and Safety-Related Ventilation System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-64 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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, andelements exposed to Air -chemical attack, and Components" piping piping compouts, inoutdor leahingpiping elements exposed to air -outdoor inoutdoor leaching Auxiliary Systems.3.3.1-78 Steel Piping and Loss of material Chapter XL.M36, No Consistent with NUREG-1801.
Thecomponents (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 becomponents (External Components" used to manage loss of material of carbonsurfaces),
Ducting; or low alloy steel with stainless steelclosure bolting exposed cladding, carbon steel, carbon steel (withto Air -indoor, internal coating),
ductile cast iron,uncontrolled (External),
galvanized steel, and gray cast ironAir -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 CycleCooling Water System, Combustible GasControl System, Compressed Air System,Control Rod Drive System, Control RoomVentilation System, Demineralized WaterMakeup System, Diesel Generator andAuxiliaries System, Drywell Pneumatic System, Electrical Penetration Pressurization System, Essential CoolingWater System, Fire Protection System,Fuel Pool Cooling and Storage System,Nonessential Cooling Water System,Nonsafety-Related Ventilation System,Plant Drainage System, PrimaryLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-65 Section 3-Aging Managemen iew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem Component Aging Effectl Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended Containment Ventilation System, ProcessRadiation Monitoring System, ProcessSampling and Post Accident Monitoring System, Radwaste System, Reactor WaterCleanup System, Safety-Related Ventilation System, Standby Liquid ControlSystem, and Suppression Pool CleanupSystem.The Fire Protection (B.2.1.16) program hasbeen substituted and will be used tomanage loss of material of carbon steel andgalvanized steel fire barriers (doors)exposed to air -indoor uncontrolled and air-outdoor in the Fire Protection System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-66 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 withpiping 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 Number3.3.1-89.
The Inspection of InternalSurfaces in Miscellaneous Piping andDucting Components (B.2.1.25) program isused to manage the loss of material incopper alloy heat exchanger tubes exposedto condensation (external).
The tubes arelocated inside the heat exchanger and theexternal surfaces of the tubes are subject tothe internal HVAC environment ofcondensation during normal operation.
TheInspection of Internal Surfaces inMiscellaneous Piping and DuctingComponents program performs visualinspections of the external surfaces of thetubes during heat exchanger internalinspections.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-67 Section 3 -Aging Manag ntemview ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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.
Thecomponents, 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 bepiping elements exposed corrosion Components" used to manage loss of material of carbonto Air -indoor, steel heat exchanger shell sideuncontrolled (External),
components exposed to air -indoorAir -outdoor (External) uncontrolled in the Demineralized WaterMakeup System, Diesel Generator andAuxiliaries System, Control RoomVentilation System and PrimaryContainment Ventilation System.The Buried and Underground Piping(B.2.1.28) program has been substituted and will be used to manage loss of materialof carbon steel piping, piping components, and piping elements located underground, exposed to an air-outdoor environment, inthe Essential Cooling Water System andNonessential 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 aluminumcomponents, and piping crevice corrosion Monitoring of Mechanical piping, piping components, and pipingelements 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 2License Renewal Application Page 3.3-68 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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.
Theseals 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 beuncontrolled (External)
Components" used to manage loss of material ofelastomer seals and components exposedto air -indoor uncontrolled in the ControlRoom Ventilation System, Safety-Related Ventilation System, and Standby GasTreatment System.3.3.1-83 Stainless steel Diesel Cracking Chapter XI.M38, No Consistent with NUREG-1801.
Theengine exhaust piping, due to stress "Inspection of Internal Inspection of Internal Surfaces inpiping components, and corrosion cracking Surfaces in Miscellaneous Piping and Ductingpiping elements exposed Miscellaneous Piping and Components (B.2.1.25) program will beto Diesel exhaust Ducting Components" used to manage cracking of stainless steeldiesel engine exhaust piping, pipingcomponents, and piping elements exposedto 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 ISGs3.3.1-85 Elastomers Elastomer Hardening and loss of Chapter XI.M38, No Not Applicable.
seals and components strength "Inspection of Internal There are no elastomer seals andexposed to Closed-cycle due to elastomer Surfaces in components exposed to closed cyclecooling water degradation Miscellaneous Piping and cooling water in Auxiliary Systems.Ducting Components" LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-69 Section 3 -Aging Managemen ew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 orand components due to elastomer Surfaces in components exposed to treated boratedexposed to Treated degradation Miscellaneous Piping and water, treated water, or raw water inborated water, Treated Ducting Components" Auxiliary Systems.water, Raw water3.3.1-87 There is no Item Number 3.3.1-87 listed in NUREG-1 800 or subsequent issued ISGs3.3.1-88 Steel; stainless steel Loss of material Chapter XI.M38, No Consistent with NUREG-1 801. ThePiping, piping due to general (steel "Inspection of Internal Inspection of Internal Surfaces incomponents, and piping only), pitting, and Surfaces in Miscellaneous Piping and Ductingelements, Piping, piping crevice corrosion Miscellaneous Piping and Components (B.2.1.25) program will becomponents, and piping Ducting Components" used to manage loss of material of carbonelements, diesel engine steel and stainless diesel engine exhaustexhaust exposed to Raw piping, piping components, and pipingwater (potable),
Diesel elements exposed to diesel exhaust in theexhaust Diesel Generator and Auxiliaries Systemand Fire Protection System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-70 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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.
ThePiping, piping due to general, components:
Chapter Inspection of Internal Surfaces incomponents, and piping pitting, and crevice XI.M27, "Fire Water Miscellaneous Piping and Ductingelements exposed to corrosion System,"
or for other Components (B.2.1.25) program will beMoist 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 ironDucting Components" accumulators, heat exchanger components, piping, piping components, and pipingelements, and tanks exposed tocondensation in the Control Rod DriveSystem, 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, andStandby Liquid Control System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-71 Section 3-Aging Managemeiew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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.
Thecomponents (Internal due to general, "Inspection of Internal Inspection of Internal Surfaces insurfaces) exposed to pitting,
- crevice, and Surfaces in Miscellaneous Piping and DuctingCondensation (Internal)
(for drip pans and Miscellaneous Piping and Components (B.2.1.25) program will bedrain lines) Ducting Components" used to manage loss of material of carbonmicrobiologically-steel and galvanized steel ducting andinfluenced corrosion components, heat exchanger components, piping, piping components, and pipingelements exposed to condensation in theCombustible Gas Control System, ControlRoom Ventilation System, DrywellPneumatic System, and Safety-Related Ventilation System.3.3.1-91 Steel Piping, piping Loss of material Chapter XL.M38, No Consistent with NUREG-1801.
Thecomponents, and piping due to general, "Inspection of Internal Inspection of Internal Surfaces inelements; tanks exposed pitting,
- crevice, and Surfaces in Miscellaneous Piping and Ductingto Waste Water microbiologically-Miscellaneous Piping and Components (B.2.1.25) program will beinfluenced corrosion Ducting Components" used to manage loss of material of carbonsteel, ductile cast iron, and galvanized steelheat exchanger components, piping, pipingcomponents, and piping elements, andtanks exposed to waste water in theCombustible Gas Control System, ControlRod Drive System, Diesel Generator andAuxiliaries System, Fuel Pool Cooling andStorage System, Plant Drainage System,Reactor Coolant Pressure BoundarySystem, and Standby Liquid ControlSystem.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-72 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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.
Thecomponents, and piping due to pitting and "Inspection of Internal Inspection of Internal Surfaces inelements exposed to crevice corrosion Surfaces in Miscellaneous Piping and DuctingCondensation (Internal)
Miscellaneous Piping and Components (B.2.1.25) program will beDucting Components" used to manage loss of material ofaluminum alloy ducting and components, piping, piping components, and pipingelements, and tanks exposed tocondensation in the Condensate System,Control Room Ventilation System, DieselGenerator and Auxiliaries System, DrywellPneumatic System, Process Radiation Monitoring System, Safety-Related Ventilation System, and Standby GasTreatment 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 Internalpiping elements exposed crevice corrosion Surfaces in There are no copper alloy piping, pipingto Raw water (potable)
Miscellaneous Piping and components, and piping elements exposedDucting Components" to raw water (potable) in Auxiliary Systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-73 Section 3 -Aging Managementeiew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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.
Theand components due to pitting and "Inspection of Internal Inspection of Internal Surfaces inexposed to Condensation crevice corrosion Surfaces in Miscellaneous Piping and DuctingMiscellaneous Piping and Components (B.2.1.25) program will beDucting Components" used to manage loss of material of carbonor low alloy steel with stainless steelcladding and stainless steel ducting andcomponents, piping, piping components, and piping elements exposed tocondensation in the Control RoomVentilation System, Primary Containment Ventilation System, Process Sampling andPost Accident Monitoring System, andSafety-Related Ventilation System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-74 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem Component Aging Effect/ Aging Management Further Discussion Number Mechanism Programs Evaluation Recommended 3.3.1-95Copper alloy, Stainless steel, Nickel alloy, SteelPiping, pipingcomponents, and pipingelements, Heatexchanger components, Piping, pipingcomponents, and pipingelements; tanks exposedto Waste water,Condensation (Internal)
Loss of materialdue to pitting, crevice,and microbiologically-influenced corrosion Chapter XI.M38,"Inspection of InternalSurfaces inMiscellaneous Piping andDucting Components" NoConsistent with NUREG-1801.
TheInspection of Internal Surfaces inMiscellaneous Piping and DuctingComponents (B.2.1.25) program will beused to manage loss of material of carbonsteel, copper alloy with 15% zinc or more,copper alloy with less than 15% zinc, nickelalloy, and stainless steel accumulators, ducting and components, piping, pipingcomponents, and piping elements, structural steel elements, and tanksexposed to condensation and waste waterin the Closed Cycle Cooling Water System,Combustible Gas Control System, ControlRod Drive System, Control RoomVentilation System, Diesel Generator andAuxiliaries System, Drywell Pneumatic System, Fire Protection System, Fuel PoolCooling and Storage System, PlantDrainage System, Primary Containment Ventilation System, Process Radiation Monitoring System, Process Sampling andPost 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, RadwasteBuilding, Reactor Building, and TurbineBuilding.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-75 0 1 0 Section 3 -Aging Managene view ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 andexposed to Air -indoor, Surfaces in Th e ne e xpo sela to air anduncontrolled (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.
Thecomponents, and piping due to general, "Lubricating Oil Analysis,"
Lubricating Oil Analysis (B.2.1.26) programelements, 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 ofcollection system: tanks, Time Inspection" material of carbon steel and gray cast ironReactor coolant pump oil gearbox, heat exchanger components, collection system: piping, piping, piping components, and pipingtubing, valve bodies elements and tanks exposed to lubricating exposed to Lubricating oil oil in the Closed Cycle Cooling WaterSystem, Control Rod Drive System, ControlRoom Ventilation System, Diesel Generator and Auxiliaries System, and DrywellPneumatic System.3.3.1-98 Steel Heat exchanger Loss of material Chapter XI.M39, No Consistent with NUREG-1801.
Thecomponents exposed to due to general, "Lubricating Oil Analysis,"
Lubricating Oil Analysis (B.2.1.26) programLubricating 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 ofinfluenced corrosion; Time Inspection" material of carbon steel and gray cast ironfouling that leads to heat exchanger components exposed tocorrosion lubricating oil in the Essential CoolingWater System and Diesel Generator andAuxiliaries System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-76 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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.
ThePiping, piping due to pitting and "Lubricating Oil Analysis,"
Lubricating Oil Analysis (B.2.1.26) programcomponents, 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 ofLubricating oil Time Inspection" material of aluminum alloy, copper alloywith 15% zinc or more, and copper alloywith less than 15% zinc heat exchanger components, piping, piping components, and piping elements, and tanks exposed tolubricating oil in the Control RoomVentilation System, Diesel Generator andAuxiliaries System, Drywell Pneumatic System, Primary Containment Ventilation System, and Reactor Coolant PressureBoundary System.3.3.1-100 Stainless steel Piping, Loss of material Chapter XI.M39, No Consistent with NUREG-1801.
Thepiping components, and due to pitting,
- crevice, "Lubricating Oil Analysis,"
Lubricating Oil Analysis (B.2.1.26) programpiping 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 ofTime 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 2License Renewal Application Page 3.3-77 Section 3 -Aging Managemen iew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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.
Theexchanger tubes transfer "Lubricating Oil Analysis,"
Lubricating Oil Analysis (B.2.1.26) programexposed 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 heatexchanger components exposed tolubricating oil in the Diesel Generator andAuxiliaries System.3.3.1-102 Boralo; boron steel, and Reduction of neutron-Chapter XI.M40, No Consistent with NUREG-1801.
Theother 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 willSpent fuel storage racks: and loss of material than Boraflex" be used to manage reduction of neutronneutron-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 racksabsorbing sheets (BWR) exposed to treated water in the Fuel Poolexposed to Treated Cooling and Storage System.borated water, Treatedwater3.3.1-103 Reinforced
- concrete, Cracking Chapter XI.M41, "Buried No Not Applicable.
asbestos cement Piping, due to aggressive and Underground Piping There are no reinforced
- concrete, asbestospiping components, and chemical attack and and Tanks" cement piping, piping components, andpiping elements exposed leaching; piping piping ompons, andto Soil or concrete Changes in material piping elements exposed to soil or concreteproperties in Auxiliary Systems.due to aggressive chemical attackLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-78 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 elementsexposed 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, pipingcomponents, and piping rebar asbestos cement pipe piping, pipingelements exposed to Soil components, and piping elements exposedor 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 Buriedwrapping)
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 ofelements exposed to Soil microbiologically-material of carbon steel, ductile cast iron,or concrete influenced corrosion and gray cast iron piping, pipingcomponents, and piping elements exposedto soil in the Diesel Generator andAuxiliaries System, Essential Cooling WaterSystem, Fire Protection System, andNonessential 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 alloycomponents, and piping crevice corrosion and Tanks" pipi n o pip ing essm steel, n i pingelements exposed to Soil piping, piping components, and pipingor concrete elements exposed to soil or concrete inAuxiliary Systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-79 Section 3 -Aging Managementeview ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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, andpiping elements, bolting piping elements, bolting exposed to soil orexposed to soil or concrete in Auxiliary Systems.concrete3.3.1-109 Steel Bolting exposed to Loss of material Chapter XI.M41, "Buried No Consistent with NUREG-1801.
The BuriedSoil 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 ofcorrosion material of carbon and low alloy steelbolting 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 alloycomponents, and piping steel piping, piping components, and pipingelements elements in Auxiliary Systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-80 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 Crackingpiping elements exposed corrosion cracking Cracking,"
and (BWR Stram Corros crackingto Teatd waer 60°CChater I.M, 'Wter(B.2.1.7) program manages crackingto Treated water >60'C Chapter XI.M2, Water initiation and growth in Reactor Coolant(> 140'F) Chemistry" Pressure Boundary System piping, pipingcomponents, and piping elements
> 4 inchNPS through the implementation of anaugmented Inservice Inspection (ISI)program in accordance with ASME Code,Section XI. Cracking in stainless steelpiping, piping components, and pipingelements
< 4 inch NPS exposed to treatedwater >140'F in the Auxiliary Systems isaddressed 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, Hoistsuncontrolled (External)
- pitting, and crevice and Refel in ou mt Syste m, ho iscorrosion and Refueling Equipment System, there isno structural steel exposed to air-indoor uncontrolled in Auxiliary Systems.
The lossof material in structural steel exposed to air-indoor uncontrolled in the Cranes, Hoistsand Refueling Equipment System isaddressed in Item Number 3.3.1-52.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-81 Section 3-Aging Managemerlew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 airentrainment) as cited inNUREG-1557, and2) plant OE indicates nodegradation of theconcrete3.3.1-113 Aluminum Piping, piping None None NA -No AEM or Consistent with NUREG-1 801.components, and piping AMPelements exposed to Air-dry (Internal/External),
Air -indoor, uncontrolled (Internal/External),
Air -indoor, controlled (External),
Gas3.3.1-114 Copper alloy Piping, None None NA -No AEM or Consistent with NUREG-1 801.piping components, and AMPpiping elements exposedto Air -indoor,uncontrolled (Internal/External),
Air -dry, Gas3.3.1-115 PWR OnlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-82 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 AMPpiping elements exposedto Air -indoor,uncontrolled 3.3.1-117 Glass Piping elements None None NA -No AEM or Consistent with NUREG-1801.
exposed to Air -indoor, AMPuncontrolled (External),
Lubricating oil, Closed-cycle cooling water, Air -outdoor, Fuel oil, Rawwater, Treated water,Treated borated water,Air with borated waterleakage, Condensation (Internal/External)
Gas3.3.1-118 Nickel alloy Piping, piping None None NA- No AEM or Consistent with NUREG-1801.
components, and piping AMPelements exposed to Air-indoor, uncontrolled (External)
LaSalle County Station, Units 1 and 2License Renewal Application 0Page 3.3-83 Section 3 -Aging ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 AMPcomponents, and pipingelements exposed to Airwith borated waterleakage, Air -indoor,uncontrolled, Condensation (Internal),
Waste Water3.3.1-120 Stainless steel Piping, None None NA -No AEM or Consistent with NUREG-1 801.piping components, and AMPpiping elements exposedto Air -indoor,uncontrolled (Internal/External),
Air -indoor, uncontrolled (External),
Air withborated water leakage,Concrete, Air- dry, Gas3.3.1-121 Steel Piping, piping None None NA -No AEM or Consistent with NUREG-1801.
components, and piping AMPelements exposed to Air-indoor, controlled (External),
Air -dry, GasLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-84 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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, AMPpipigcomponents, Ping, AThere are no titanium heat exchanger piping components, and components, piping, piping components, to Air -indoor, and piping elements exposed to air -indooruncontrolled 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 AMPcontains
> 5% aluminum There are no titanium (ASTM Grades 1,2,or more than 0.20% 7, 11, or 12 that contains
> 5% aluminum oroxygen or any amount of more than 0.20% oxygen or any amount ofoxyen) Ht any amountotin) heat exchanger components other thantin) Heat exchanger tubes, piping, piping components, andtubes, Piping, piping piping elements exposed to raw water incomponents, and piping Auxiliary Systems.elements exposed toRaw water3.3.1-124 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 (withnickel-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, pipingstorage racks (PWR), components, and piping elements exposedPiping, piping to treated water >60'C (>140°F) or treatedcomponents, and piping borated water >60°C (>140°F) in Auxiliary elements; exposed to Systems.Treated water >60'C(>140*F),
Treatedborated water >60°C(>1 40'F)LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-85 Section 3 -Aging Managemen iew ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 withcladding),
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 managestorage racks (PWR), loss of material of stainless steel storagePiping, piping racks (control rod blade, defective fuel, andcomponents, and piping spent fuel) exposed to treated water in theelements; exposed to Fuel Pool Cooling and Storage System.Treated water, Treated An exception applies to the NUREG-1801 borated water A xeto ple oteNRG10recommendations 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 treatedwater (borated),
raw water, treated water (borated) or raw waterwater susceptible to wall thinning due to erosionin Auxiliary Systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-86 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 Systemcomponents, and tanks to recurring internal management program is (B.2.1.12) program will be used to manageexposed to raw water or corrosion to be evaluated to the loss of material due to recurring internalwaste water address recurring internal corrosion in carbon steel piping, pipingcorrosion components, and piping elements exposedto raw water in the Essential Cooling WaterSystem and Nonessential Cooling WaterSystem.The Fire Water System (B.2.1.17) programwill be used to manage the loss of materialdue to recurring internal corrosion in carbonsteel piping, piping components, and pipingelements exposed to raw water in the FireProtection System.The Inspection of Internal Surfaces inMiscellaneous Piping and DuctingComponents (B.2.1.25) program will beused to manage the loss of material due torecurring internal corrosion in carbon steeland galvanized steel piping, pipingcomponents, and piping elements exposedto waste water in the Plant DrainageSystem.See Subsection 3.3.2.2.8.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-87 Section 3 -Aging Managementeview ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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, orthe scope of Chapter only), pitting, or Tanks" al e outdoor tank s steel, o nXl.M29, "Aboveground crevice corrosion; aluminum outdoor tanks constructed on soilMetallic Tanks") exposed cracking due to stress or concrete, or, indoor large-volume tanksto soil or concrete, or the corrosion cracking (100,000 gallons and greater) designed tofollowing external (stainless steel and internal pressures approximating environments air-outdoor, aluminum only) atmospheric pressure and exposedair-indoor uncontrolled, internally to water (e.g., within the scope ofmoist air, condensation Chapter XI.M29, "Aboveground MetallicTanks") exposed to soil or concrete, or thefollowing external environments air-outdoor, air-indoor uncontrolled, moist air orcondensation 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 tanksindoor uncontrolled, raw and crevice corrosion Tanks" There on soil ortdo or indswater, treated water, constructed on soil or concrete, or, indoorwaste water, large-volume tanks (100,000 gallons andcondensation greater) designed to internal pressures approximating atmospheric pressure andexposed internally to water (e.g., within thescope of Chapter XI.M29, "Aboveground Metallic Tanks") exposed to soil orconcrete, air-indoor uncontrolled, rawwater, treated water, waste water orcondensation in Auxiliary Systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-88 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 withexposed to air-indoor to general (where Water System" exceptions.
The Fire Water Systemcontrolled, air-indoor applicable),
- pitting, (B.2.1.17) program will be used to manageuncontrolled, air-outdoor,
- crevice, and loss of material and flow blockage ofmoist 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 withcopper alloy, or to general (steel, and Water System" exceptions.
The Fire Water Systemaluminum fire water copper alloy only), (B.2.1.17) program will be used to managesystem piping, piping pitting,
- crevice, and loss of material and flow blockage ofcomponents and piping microbiologically-carbon steel and stainless steel piping,elements exposed to air- influenced corrosion, piping components and piping elementsindoor 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 tocondensation (internal) fouling Exceptions apply to the NUREG-1 801recommendations for Fire Water System(B.2.1.17) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-89 Section 3-Aging Managementeview ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 ofsteel, 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 ofalloy 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 elementscomponents, and tanks corrosion; cracking Metallic Tanks" (for tanks and cracking of insulated stainless steelexposed to condensation, due to stress only) piping, piping components, and pipingair-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 PrimaryContainment 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 inelements 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 Systempiping components, and copper alloy only), Surfaces in The pen-Cyc ll be ust epiping elements, and pitting,
- crevice, and Miscellaneous Piping and (B.2.1.12) program will be used to manageheat exchanger microbiologically Ducting Components" the nonsafety-related steel, stainless steel,components exposed to influenced corrosion, and copper alloy piping, pipinga raw water environment fouling that leads to components, and piping elements, and heat(for nonsafety-related corrosion exchanger components not covered bycomponents not covered NRC GL 89-13 and exposed to a raw waterby NRC GL 89-13) environment.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-90 Section 3 -Aging Management Review ResultsTable 3.3.1 Summary of Aging Management Evaluations for the Auxiliary SystemsItem 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 pumpsubmerged in a waste only), pitting,
- crevice, Monitoring of Mechanical casings submerged in a waste waterwater (internal and and microbiologically Components" (ings submerna wist inexternal) environment influenced corrosion (internal and external) environment inAuxiliary 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 orair-indoor uncontrolled, and microbiologically-aluminum fire water storage tanks exposedair-outdoor, influenced corrosion, to air-indoor uncontrolled, air-outdoor, condensation, moist air, fouling that leads to condensation, moist air, raw water, orraw water, treated water corrosion; cracking treated water in Auxiliary Systems.due to stresscorrosion cracking(stainless steel andaluminum 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, orthe scope of Chapter pitting and crevice Tanks" a re outdoor tanks steel, o nXI.M29, "Aboveground corrosion aluminum outdoor tanks constructed on soilMetallic Tanks") exposed or concrete, or, indoor large-volume tanksto treated water, treated (100,000 gallons and greater) designed toborated water internal pressures approximating atmospheric pressure and exposedinternally to water (e.g., within the scope ofChapter XI.M29, "Aboveground MetallicTanks") exposed to treated water or treatedborated water in Auxiliary Systems.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-910 0 Section 3- Aging Management Review ResultsTable 3.3.2-1Closed Cycle Cooling Water SystemSummary of Aging Management Evaluation Table 3.3.2-1 Closed Cycle Cooling Water SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingHeat 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 ASide 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 AUncontrolled (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 AWater (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 ASide Components Water (Internal)
Systems (B.2.1.13)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-92 Section 3 -Aging Management Review ResultsTable 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement 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 ASide 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 CCooling Coils) Water (Internal)
Systems (B.2.1.13)
Tube SideComponents 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 CAftercooler)
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 ACooler) 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 CSystems (B.2.1.13)
LaSalle Count~vftion, Units 1 and 2License ReneiV P lication0 Page 3.3-93 0 9 Section 3 -Aging Managemeview ResultsTable 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AComponents 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 AExchanger)
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 AExchanger)
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 CVentilation Zinc Water (Internal)
Systems (B.2.1.13)
Instrument RoomA/C Unit) TubeSide Components Hoses Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (External)
Monitoring of Mechanical I _Components (B.2.1.24)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-94 Section 3 -Aging Management Review ResultsTable 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Hoses Leakage Boundary Carbon Steel Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 AWater (Internal)
Systems (B.2.1.13)
Piping, pipingcomponents, andpiping elementsLeakage BoundaryCarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78AClosed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 AWater (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 MaterialLubricating Oil Analysis(B.2.1.26)
VII.C2.AP-127 3.3.1-97A+One-Time Inspection (B.2.1.21)
VII.C2.AP-127 3.3.1-97ACopper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 Aless than 15% Uncontrolled (External)
Zinc Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 AWater (Internal)
Systems (B.2.1.13)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
_ _ Lubricating Oil (Internal)
None None VII.J.AP-15 3.3.1-117 AStainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 AClosed Cycle CoolingWater > 140 F (Internal)
CrackingClosed Treated WaterSystems (B.2.1.13)
VII.C2.AP-186 3.3.1-43ALoss of MaterialClosed Treated WaterSystems (B.2.1.13)
VII.C2.A-52 3.3.1-49At 1~ t IPressure Boundary Carbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78A.Closed Cycle CoolingWater (Internal)
Loss of MaterialClosed Treated WaterSystems (B.2.1.13)
VII.C2.AP-202 3.3.1-45ALaSalle Count, ,on, Units 1 and 2License Rene W lication.Page 3.3-95 0Section 3 -Aging ManagemReview ResultsTable 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Carbon Steel Condensation Loss of Material External Surfaces VII.C1.A-405 3.3.1-132 A, 1components, 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 AWater (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 ABuilding 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 AWater (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 ABuilding 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 AWater (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (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 AUncontrolled (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 AWater (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 AUncontrolled (External)
IIILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-96 Section 3 -Aging Management Review ResultsTable 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement IValve Body Leakage Boundary Stainless Steel Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 AWater (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 AUncontrolled (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 AWater (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 AUncontrolled (External)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 AWater (Internal)
Systems (B.2.1.13)
LaSalle Countwlon, Units 1 and 2License ReneOpWlication 0 Page 3.3-97 0 0 Section 3 -Aging Managemeview ResultsTable 3.3.2-1 Closed Cycle Cooling Water System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 gapsin insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dewpoint of the air on the external surfaces of the insulation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-98 Section 3 -Aging Management Review ResultsTable 3.3.2-2Combustible Gas Control SystemSummary of Aging Management Evaluation Table 3.3.2-2 Combustible Gas Control SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Blower Housing Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 CSurfaces in Miscellaneous Piping and DuctingComponents (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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingStainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 AHoses Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (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 Acomponents, 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 ASurfaces in Miscellaneous Piping and DuctingL_ _Components (B.2.1.25)_
LaSalle Countvftio Units 1 and 2License ReneW plication
.Page 3.3-99 9 0 Section 3 -Aging Managemten Review ResultsTable 3.3.2-2 Combustible Gas Control System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Leakage Boundary Glass Air- Indoor None None VII.J.AP-14 3.3.1-117 Acomponents, and Uncontrolled (External) piping elements Waste Water (Internal)
None None VII.J.AP-277 3.3.1-119 APressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Structural Integrity Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Recombiners Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 CSurfaces in Miscellaneous Piping and DuctingI Components (B.2.1.25)
ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-100 Section 3 -Aging Management Review ResultsTable 3.3.2-2 Combustible Gas Control System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve BodyLeakage BoundaryCarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78AWaste Water (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.E5.AP-281 3.3.1-91APressure BoundaryCarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII. I.A-773.3.1-78ACondensation (Internal)
Loss of Material Inspection of Internal VII.F3.A-08 3.3.1-90 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Waste Water (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.E5.AP-281 3.3.1-91Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 ACondensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Waste Water (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.E5.AP-278 3.3.1-95A+ + 4Structural Integrity Carbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78At I +/- F ICondensation (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.F3.A-08 3.3.1-90CLaSalle Countrylion, Units 1 and 2License ReneW plication
.Page 3.3-101 0 Section 3 -Aging Management Review ResultsTable 3.3.2-2 Combustible Gas Control System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 2License Renewal Application Page 3.3-102 Section 3 -Aging Management Review ResultsTable 3.3.2-3Compressed Air SystemSummary of Aging Management Evaluation Table 3.3.2-3 Compressed Air SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingPiping, piping Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 Acomponents, 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 BMonitoring (B.2.1.15)
Structural Integrity Carbon Steel Air- Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 AUncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Compressed Air VII.D.A-26 3.3.1-55 BMonitoring (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 AUncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Compressed Air VII.D.A-26 3.3.1-55 BMonitoring (B.2.1.15)
Structural Integrity Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 AUncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Compressed Air VII.D.A-26 3.3.1-55 BMonitoring (B.2.1.15)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 Aless than 15% Uncontrolled (External)
ZincLaSalle Countftion, Units 1 and 2License ReneW plication
- Page 3.3-103 Section 3 -Aging Managemeview ResultsTable 3.3.2-3 Compressed Air System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Valve Body Structural Integrity Copper Alloy with Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-240 3.3.1-54 Bless than 15% Monitoring (B.2.1.15)
ZincLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-104 Section 3 -Aging Management Review ResultsTable 3.3.2-3 Compressed Air System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 3.3-105License Rene W licationVW Section 3 -Aging Manage ReviewResults Table 3.3.2-4Control Rod Drive SystemSummary of Aging Management Evaluation Table 3.3.2-4 Control Rod Drive SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Accumulator Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 CSurfaces in Miscellaneous Piping and DuctingComponents (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 DStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 CUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 CSurfaces in Miscellaneous Piping and DuctingComponents (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 DBolting Mechanical Closure Carbon and Low Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VlII.AP-124 3.3.1-15 ABoltingStainless Steel Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ALaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-106 Section 3 -Aging Management Review ResultsTable 3.3.2-4 Control Rod Drive System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Drip Pan Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 APump) 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 CSide 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 Acomponents, 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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 2License Renevlication 9 Page 3.3-107 Section 3- Aging Managemt Review ResultsTable 3.3.2-4 Control Rod Drive System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsLeakage BoundaryCarbon Steel Treated Water (Internal)
Loss of MaterialOne-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 3.3.1-21BI 4 + +Waste Water (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComoonents (B.2.1.25)
VII.E5.AP-281 3.3.1-91AGlass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
Treated Water (Internal)
None None VII.J.AP-51 3.3.1-117 AStainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 A,44.4Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
VII.E4.AP-1 103.3.1-25AWater Chemistry (B.2.1.2)
VII.E4.AP-1 103.3.1-25BPressure BoundaryCarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Comoonents (B.2.1.24)
VII.I.A-77 3.3.1-78ACondensation (Internal)
Loss of Material Inspection of Internal VII.G.A-23 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Treated Water (Internal)
Cumulative FatigueDamaaeTLAAV.D2.E-10 3.2.1-1A, 1-. 4 4 +Loss of MaterialOne-Time Inspection (B.2.1.21)
VII.E4.AP-106 3.3.1-21AWater Chemistrv (B.2.1.2)
VII.E4.AP-106 3.3.1-21B4 1 + -. ~4 + 4Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-117 3.3.1-120 A+, 4Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
VII.E4.AP-110 3.3.1-25AWater Chemistry (B.2.1.2)
VII.E4.AP-110 3.3.1-25BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-108 Section 3 -Aging Management Review ResultsTable 3.3.2-4 Control Rod Drive System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AUncontrolled (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 BValve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 BStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 BPressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 BLaSalle Count, ylfon, Units 1 and 2License Rene 1W lication0 Page 3.3-109 Section 3 -Aging Manage Review ResultsTable 3.3.2-4 Control Rod Drive System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve Body Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-110 Section 3 -Aging Management Review ResultsTable 3.3.2-4Control Rod Drive System(Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 2License
.Page 3.3-111 0 0 Section 3 -Aging ManagetReview ResultsTable 3.3.2-5Control Room Ventilation SystemSummary of Aging Management Evaluation Table 3.3.2-5 Control Room Ventilation SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingGalvanized Steel Air -Indoor None None VII.J.AP-13 3.3.1-116 CUncontrolled (External)
Stainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ADucting and Leakage Boundary Stainless Steel Condensation Loss of Material Inspection of Internal VII.F1.AP-99 3.3.1-94 A, 1Components (External)
Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Aluminum Alloy Air- Indoor None None VII.J.AP-135 3.3.1-113 CUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Carbon Steel Air -Indoor Loss of Material External Surfaces VII.F .A-10 3.3.1-78 AUncontrolled (External)
Monitoring of Mechanical I_ 1 1 Components (B.2.1.24)
ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-112 Section 3 -Aging Management Review ResultsTable 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Ducting and Pressure Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.A-08 3.3.1-90 AComponents Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Elastomers Air -Indoor Hardening and Loss of External Surfaces VII.F .AP-102 3.3.1-76 AUncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 3Strength Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Galvanized Steel Air -Indoor None None VII.J.AP-13 3.3.1-116 CUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 CUncontrolled (External)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 CStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 CUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F .AP-99 3.3.1-94 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Flexible Pressure Boundary Elastomers Air -Indoor Hardening and Loss of External Surfaces VII.F1.AP-102 3.3.1-76 AConnection Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.F1.AP-113 3.3.1-82 AMonitoring of Mechanical Components (B.2.1.24)
LaSalle CountYpion, Units 1 and 2License Rene W plication 0 Page 3.3-113 Section 3 -Aging Managent Review ResultsTable 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Flexible Pressure Boundary Elastomers Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 3Connection Strength Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Loss of Material Inspection of Internal G, 3Surfaces in Miscellaneous Piping and DuctingComponents (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 DuctingRoom HVAC Air- Components (B.2.1.25)
Cooled Condenser)
FinsHeat 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 CRoom HVAC Air- Surfaces in Miscellaneous Cooled Condenser)
Piping and DuctingShell Side Pipingnd DuctingComponents 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, 2Aux Elec Equip Zinc (External)
Transfer Surfaces in Miscellaneous Cooled Condenser)
Piping and DuctingTubens Components (B.2.1.25)
TubesLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-114 Section 3 -Aging Management Review ResultsTable 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 CAux Elec Equip Zinc (External)
Surfaces in Miscellaneous Room HVACo Air- Piping and DuctingCooled Condenser)
Components (B.2.1.25)
TubesHeat 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 DuctingRoom HVAC Components (B.2.1.25)
Supply Coolers)FinsHeat 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 CRoom HVAC Surfaces in Miscellaneous Supply Coolers)
Piping and DuctingShell 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, 2Aux Elec Equip Zinc (External)
Transfer Surfaces in Miscellaneous Room HVACSupply Coolers)
Piping and Ductingubers) Components (B.2.1.25)
TubesLaSalle Countyiion, Units 1 and 2License Rene !Wp lication.Page 3.3-115 Section 3 -Aging Managemt Review ResultsTable 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 CAux Elec Equip Zinc (External)
Surfaces in Miscellaneous Room HVACSupply Coolers)
Piping and Ductingubers) Components (B.2.1.25)
TubesHeat 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 CCompressor OilCooler) Shell SideComponents 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 AAux Equip Room ZincTrnfr(.126 HVAC Refrigerant Transfer (B.2.1.26)
Compressor Oil One-Time Inspection V.D2.EP-78 3.2.1-51 ACooler) Tubes (B.2.1.21)
Pressure Boundary Copper Alloy with Air/Gas -Dry (External)
None None VII.J.AP-9 3.3.1-114 Cless than 15% Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-133 3.3.1-99 CZinc (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 2License Renewal Application Page 3.3-116 Section 3 -Aging Management Review ResultsTable 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsPressure Boundary I Aluminum AlloyAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-135 3.3.1-113 AAir/Gas -Dry (Internal)
NoneNoneVII.J.AP-1 343.3.1-113 ACarbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 AUncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 ALubricating 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 A15% Zinc or More Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Copper Alloy withless than 15%ZincAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-144 3.3.1-114 AAir/Gas -Dry (Internal)
None None VII.J.AP-9 3.3.1-114 ACondensation 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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
ILubricating Oil (Internal)
Loss of MaterialLubricating Oil Analysis(B.2.1.26)
VII.H2.AP-133 3.3.1-99A-I. t +One-Time Inspection (B.2.1.21)
VII.H2.AP-133 3.3.1-99ALaSalle County ion, Units 1 and 2License Rene1W licationO Page 3.3-117 0Section 3 -Aging Managerl eview ResultsTable 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Glass Air- Indoor None None VII.J.AP-14 3.3.1-117 Acomponents, and Uncontrolled (External) piping elements Air/Gas -Dry (Internal)
None None VII.J.AP-98 3.3.1-117 AStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 CRoom 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 CReceiver)
Valve Body Pressure Boundary Copper Alloy with Air- Indoor None None VII.J.AP-144 3.3.1-114 A15% Zinc or More Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 Aless than 15% Uncontrolled (External)
Zinc Air/Gas -Dry (Internal)
None None VII.J.AP-9 3.3.1-114 ACondensation 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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-118 Section 3 -Aging Management Review ResultsTable 3.3.2-5 Control Room Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve Body Pressure Boundary Ductile Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
L Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 ALaSalle Countyý!
on, Units 1 and 2License lication.Page 3.3-119 0 0 Section 3-Aging Managem~eReview ResultsTable 3.3.2-5 Control Room Ventilation System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 heattransfer aging effect applicable to this component type, material, and environment combination.
The component is located within HVAC ducting andcomponents, and the external surfaces of this component are subject to the internal HVAC environment of condensation during normal operation.
TheInspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program performs visual inspections which are capable ofidentifying 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 gapsin insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dewpoint of the air on the external surfaces of the insulation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-120 Section 3 -Aging Management Review ResultsTable 3.3.2-6Cranes, Hoists and Refueling Equipment SystemSummary of Aging Management Evaluation Table 3.3.2-6 Cranes, Hoists and Refueling Equipment SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Bolting Structural Integrity Carbon and Low Air -Indoor Loss of Material Inspection of Overhead III.B5.TP-248 3.5.1-80 E, 1Alloy Steel Uncontrolled (External)
Heavy Load and LightBolting Load (Related toRefueling)
HandlingSystems (B.2.1.14)
Loss of Preload Inspection of Overhead III.B5.TP-261 3.5.1-88 E, 1Heavy Load and LightLoad (Related toRefueling)
HandlingSystems (B.2.1.14)
Stainless Steel Air -Indoor Loss of Preload Inspection of Overhead III.B5.TP-261 3.5.1-88 E, 1Bolting Uncontrolled (External)
Heavy Load and LightLoad (Related toRefueling)
HandlingSystems (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 LightLoad (Related toRefueling)
HandlingSystems (B.2.1.14)
Water Chemistry (B.2.1.2)
III.B1.2.TP-232 3.5.1-85 BLoss of Preload Inspection of Overhead III.B5.TP-261 3.5.1-88 E, 1Heavy Load and LightLoad (Related toRefueling)
HandlingSystems (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)
DamageIley/Beam/Jib Boom)LaSalle Countywon, Units 1 and 2License Rene 1W lication* Page 3.3-121 0Section 3 -Aging Management Review ResultsTable 3.3.2-6 Cranes, Hoists and Refueling Equipment System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 LightIley/Beam/Jib Load (Related toBoom) Refueling)
HandlingSystems (B.2.1.14)
Crane/Hoist (Fuel Structural Integrity Aluminum Alloy Air -Indoor None None III.B5.TP-8 3.5.1-95 CPrep 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 LightLoad (Related toRefueling)
HandlingSystems (B.2.1.14)
Water Chemistry (B.2.1.2)
VII.A4.AP-130 3.3.1-25 DCrane/Hoist (Rail Structural Integrity Carbon Steel Air -Indoor Loss of Material Inspection of Overhead VII.B.A-07 3.3.1-52 ASystems)
Uncontrolled (External)
Heavy Load and Light VII.B.A-05 3.3.1-53 ALoad (Related toRefueling)
HandlingSystems (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 LightPlatform)
Load (Related toRefueling)
HandlingSystems (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 LightPlatform)
Load (Related toRefueling)
HandlingSystems (B.2.1.14)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 CUncontrolled (External)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-122 Section 3 -Aging Management Review ResultsTable 3.3.2-6 Cranes, Hoists and Refueling Equipment System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 agingeffect(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 3.3-123License ReneW lication V P 0Section 3 -Aging Managment Review ResultsTable 3.3.2-7Demineralized Water Makeup SystemSummary of Aging Management Evaluation Table 3.3.2-7 Demineralized Water Makeup SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingHeat 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 CComponents 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 BPiping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 Acomponents, 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 DCopper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 Aless than 15% Uncontrolled (External)
Zinc Treated Water (Internal)
Loss of Material One-Time Inspection VII.E4.AP-140 3.3.1-22 AL_ (B.2.1.21)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-124 Section 3 -Aging Management Review ResultsTable 3.3.2-7 Demineralized Water Makeup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 Bcomponents, and less than 15%piping elements ZincGalvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 AUncontrolled (External)
Treated Water (Internal)
Loss of Coating Integrity Service Level III and H, 2Service Level IIIAugmented CoatingsMonitoring andMaintenance 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 AGlass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
Treated Water (Internal)
None None VII.J.AP-51 3.3.1-117 AStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 APump 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 ASelective 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 AUncontrolled (External)
Monitoring of Mechanical
__ _Components (B.2.1.24)
LaSalle Count yftjon, Units 1 and 2License ReneW lication.Page 3.3-125 0 O Section 3-Aging Manage4 Review ResultsTable 3.3.2-7 Demineralized Water Makeup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BCopper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A15% 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, 1Loss 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 BSelective 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 Aless 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 BGray Cast Iron Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 AUncontrolled (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 ASelective Leaching VII.A4.AP-31 3.3.1-72 A(B.2.1.22)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-126 Section 3 -Aging Management Review ResultsTable 3.3.2-7 Demineralized Water Makeup System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 IIIAugmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable to galvanized steel in atreated water environment.
LaSalle Count ytlion, Units 1 and 2 _ Page 3.3-127License ReneW lication 0Section 3 -Aging Manage*eeview ResultsTable 3.3.2-8Diesel Generator and Auxiliaries SystemSummary of Aging Management Evaluation Table 3.3.2-8 Diesel Generator and Auxiliaries SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Air Dryer (Housing)
Structural Integrity Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Bird Screen Filter Stainless Steel Air -Outdoor (External)
Cracking External Surfaces VII.H2.AP-209 3.3.1-4 AMonitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.H2.AP-221 3.3.1-6 AMonitoring 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingStainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 AElectric 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 AWater (Internal)
Systems (B.2.1.13)
Expansion Joints Pressure Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AI__ I_ _ ýUncontrolled (External)
ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-128 Section 3 -Aging Management Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType 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 DuctingComponents (B.2.1.25)
Loss of Material Inspection of Internal VII.H2.AP-104 3.3.1-88 ASurfaces in Miscellaneous Piping and DuctingComponents (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 AMonitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (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 AUncontrolled (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 AUncontrolled (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 AL__ (B.2.1.26)
LaSalle Countyaltjon, Units 1 and 2License Rene1W lication.Page 3.3-129 0Section 3- Aging Managem eview ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AWater (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 CSystems (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, 315% Zinc or More Water (External)
Systems (B.2.1.13)
Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 CSystems (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 SheetLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-130 Section 3 -7 Aging Management Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AWater (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 A15% 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, 315% Zinc or More Water (Internal)
Systems (B.2.1.13)
Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 CSystems (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 2License Rene~W lication0 Page 3.3-131 0Section 3 -Aging ManagemeReview ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Elastomers Air- Indoor Hardening and Loss of External Surfaces VII.F1.AP-102 3.3.1-76 AUncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 2Strength Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (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 Acomponents, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
I I __LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-132 Section 3 -Aging Management Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsLeakage BoundaryCarbon SteelCondensation (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.H2.A-23 3.3.1-89AFuel Oil (Internal)
Loss of MaterialFuel Oil Chemistry (B.2.1.19)
VII.H .AP-1053.3.1-70AOne-Time Inspection (B.2.1.21)
VII.H1 .AP-1053.3.1-70A~1- 1 1- 1GlassAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-14 3.3.1-117 AI + IFuel Oil (Internal)
NoneNoneVII.J.AP-49 3.3.1-117 APressure Boundary Aluminum AlloyAir- IndoorUncontrolled (External)
NoneNoneVII.J.AP-135 3.3.1-113 AI I +/- F ICondensation (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingCom[)onents (B.2.1.25)
VII.F .AP-1423.3.1-92A1- t I +/- ICarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.L.A-77 3.3.1-78AAir -Outdoor (External)
Loss of Material External Surfaces VII.I.A-78 3.3.1-78 AMonitoring of Mechanical Components (B.2.1.24)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 AWater (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Diesel Exhaust(Internal)
Cumulative FatigueDamageTLAAH, 1LaSalle Count'"on, Units 1 and 2License Rene W lication.Page 3.3-133 Section 3- Aging Managel Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsPressure BoundaryCarbon SteelDiesel Exhaust(Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.H2.AP-104 3.3.1-88AFuel 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 AI Piping (B.2.1.28)
Waste Water (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.E5.AP-281 3.3.1-91ACopper Alloy with Air -Indoor15% Zinc or More Uncontrolled (External)
NoneNoneVII.J.AP-144 3.3.1-114 AClosed Cycle Cooling Cracking Closed Treated Water H, 3Water (Internal)
Systems (B.2.1.13)
Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 ASystems (B.2.1.13)
Selective Leaching VII.C2.AP-43 3.3.1-72 A(B.2.1.22)
I ICondensation (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.G.AP-143 3.3.1-89ACopper Alloy withless than 15%ZincAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-144 3.3.1-114 ALaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-134 Section 3 -Aging Management Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs Item_ _ _ _ _ _ _ _ _ _ _ _ _ _ Management___
__ __Piping, pipingcomponents, andpiping elementsPressure BoundaryCopper Alloy withless than 15%ZincFuel Oil (Internal)
Loss of MaterialFuel Oil Chemistry (B.2.1.19)
VII.Hl .AP-1323.3.1-69A+ +One-Time Inspection (B.2.1 .21'iVII.H1.AP-132 3.3.1-69AGlass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
Closed Cycle Cooling None None VII.J.AP-166 3.3.1-117 AWater (Internal)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 ALubricating Oil (Internal)
None None VII.J.AP-15 3.3.1-117 AGray Cast Iron Air- Indoor Loss of Material External Surfaces VII.L.A-77 3.3.1-78 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 ACondensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Fuel Oil (Internal)
Loss of MaterialFuel Oil Chemistry (B.2.1.19)
VII.HI .AP-1363.3.1-71AOne-Time Inspection (B.2.1.21)
VII.H1 .AP-1363.3.1-71ALaSalle Countlon, Units I and 2License Rene W lication* Page 3.3-135 Section 3 -Aging Management Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Stainless Steel Lubricating Oil (Internal)
Loss of Material Lubricating Oil Analysis VII.H2.AP-138 3.3.1-100 Acomponents, 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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Structural Integrity Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 AOil 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 AUncontrolled (External)
Monitoring of Mechanical I I_ Components (B.2.1.24)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-136 Section 3 -Aging Management Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1 801 Table I Item NotesType Function Requiring Programs ItemManagement 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 DuctingComponents (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 DuctingComponents (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 AReceivers)
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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 ACooling 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 AWater (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (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 AStorage and Day Uncontrolled (External)
Monitoring of Mechanical Tanks) I I I I Components (B.2.1.24)
ILaSalle Count~iftion, Units 1 and 2License Rene /plication 0 Page 3.3-137 0Section 3 -Aging Managem t Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Tanks (Fuel Oil Pressure Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 AStorage and Day Surfaces in Miscellaneous Tanks) Piping and DuctingComponents (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 AStrainer Tank) Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F .AP-142 3.3.1-92 CSurfaces in Miscellaneous Piping and DuctingComponents (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 AUncontrolled (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 A15% Zinc or More Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (External)
Monitoring of Mechanical I __ Components (B.2.1.24)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-138 Section 3 -Aging Management Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve BodyPressure BoundaryCarbon SteelClosed Cycle CoolingWater (internal)
Loss of MaterialClosed Treated WaterSvstems (B.2.1.13'l VII.C2.AP-202 3.3.1-45ACondensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Fuel Oil (Internal)
Loss of MaterialFuel Oil Chemistry (B.2.1.19)
VII.H1 .AP-1053.3.1-70AOne-Time Inspection (B.2.1.21)
VII.H .AP-1053.3.1-70A1 1 -~ t +Copper Alloy with Air -Indoor15% Zinc or More Uncontrolled (External)
NoneNoneVII.J.AP-144 3.3.1-114 AClosed Cycle Cooling Cracking Closed Treated Water H, 3Water (Internal)
Systems (B.2.1.13)
Loss of Material Closed Treated Water VII.C2.AP-199 3.3.1-46 ASystems (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 MaterialLubricating Oil Analysis(B.2.1.26)
VII.H2.AP-133 3.3.1-99A"1 q-+ F +One-Time Inspection (B.2.1.21)
VII.H2.AP-133 3.3.1-99A+/- + 4 + _____Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-1 73.3.1-120 AClosed Cycle CoolingWater (Internal)
Loss of MaterialClosed Treated WaterSystems (B.2.1.13)
VII.C2.A-52 3.3.1-49ALaSalle CountYm"ion, Units 1 and 2License Renew plication O Page 3.3-139 0 0 Section 3- Aging Managem Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve Body Pressure Boundary Stainless Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-140 Section 3 -Aging Management Review ResultsTable 3.3.2-8 Diesel Generator and Auxiliaries System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 agingeffect(s) applicable to this component type, material and environment combination.
The TLAA designation in the Aging Management Program columnindicates 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 WaterSystems (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 3.3-141License Rene VP lication w
0 Section 3 -Aging Managem Review ResultsTable 3.3.2-9Drywell Pneumatic SystemSummary of Aging Management Evaluation Table 3.3.2-9 Drywell Pneumatic SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Accumulator Pressure Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 CUncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 CCondensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 D, 1Monitoring (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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingStainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ACompressor Leakage Boundary Ductile Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AHousing 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 AWater (Internal)
Systems (B.2.1.13)
Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 AWater (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 AI___ (B.2.1.26)
ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-142 Section 3 -Aging Management Review ResultsTable 3.3.2-9 Drywell Pneumatic System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Compressor Leakage Boundary Gray Cast Iron Lubricating Oil (Internal)
Loss of Material One-Time Inspection VII.Fl.AP-127 3.3.1-97 AHousing (B.2.1.21)
Hoses Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 A, 2Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 ACondensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 B, 1Monitoring (B.2.1.15)
Piping, piping Leakage Boundary Aluminum Alloy Air -Indoor None None VII.J.AP-135 3.3.1-113 Acomponents, and Uncontrolled (External) piping elements Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 A, 2Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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, 2Surfaces in Miscellaneous Piping and DuctingComponents (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 A15% Zinc or More Uncontrolled (External)
LaSalle County ion, Units 1 and 2License ReneW lication.Page 3.3-143 Section 3 -Aging Manage9Review ResultsTable 3.3.2-9 Drywell Pneumatic System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsLeakage BoundaryCopper Alloy with15% Zinc or MoreCondensation (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.G.AP-143 3.3.1-89A, 2Waste Water (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.E5.AP-272 3.3.1-95A, 5Selective Leaching(B.2.1.22)
VII. E5.A-4073.3.1-72A, 5Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 Aless 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 AUncontrolled (External)
Lubricating Oil (Internal)
None None VII.J.AP-15 3.3.1-117 ANickel Alloy Air -Indoor None None VII.J.AP-16 3.3.1-118 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-274 3.3.1-95 A, 2Surfaces in Miscellaneous Piping and DuctingI Components (B.2.1.25)
PolymersAir -IndoorUncontrolled (External)
Change in MaterialProperties External SurfacesMonitoring of Mechanical Components (B.2.1.24)
G, 3t. .+Condensation (Internal)
Change in MaterialProperties, Loss ofMaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
G, 4LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-144 Section 3 -Aging Management Review ResultsTable 3.3.2-9 Drywell Pneumatic System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 Acomponents, and Uncontrolled (External) piping elements Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 B, 1Monitoring (B.2.1.15)
Inspection of Internal VII.E5.AP-273 3.3.1-95 A, 2Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 ACondensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 B, 1Monitoring (B.2.1.15)
Inspection of Internal VII.E5.AP-273 3.3.1-95 A, 2Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Structural Integrity Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 B, 1Monitoring (B.2.1.15)
Inspection of Internal VII.E5.AP-273 3.3.1-95 A, 2Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Strainer Element Filter Stainless Steel Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 AValve Body Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.IA-77 3.3.1-78 AUncontrolled (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, 2Surfaces in Miscellaneous Piping and DuctingI Components (B.2.1.25)
ILaSalle Countyftion, Units 1 and 2License Rene1W lication.Page 3.3-145 eSection 3 -Aging Manage9enReview ResultsTable 3.3.2-9 Drywell Pneumatic System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve BodyLeakage BoundaryCopper Alloy withless than 15%ZincAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-144 3.3.1-114 Lubricating Oil (Internal)
Loss of MaterialLubricating Oil Analysis(B.2.1.26)
VII.H2.AP-133 3.3.1-99AOne-Time Inspection (B.2.1.21)
VII.H2.AP-133 3.3.1-99A+ 4 4 + + 4Stainless SteelAir -IndoorUncontrolled (External)
Condensation (Internal)
NoneNoneVII.J.AP-17 3.3.1-120 A, -4Loss of MaterialCompressed AirMonitoring (B.2.1.15)
VII.D.AP-81 3.3.1-56B, 1Inspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.E5.AP-273 3.3.1-95A, 2Pressure BoundaryCarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78AAir/Gas -Dry (Internal)
NoneNoneVII.J.AP-6 3.3.1-121 At + 4 + 4Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 AAir/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 ACondensation (Internal)
Loss of MaterialCompressed AirMonitorina (B.2.1.15)
VII.D.AP-81 3.3.1-56B, 14 4 4Inspection of InternalSurfaces in Miscellaneous Piping and DuctingComoonents (B.2.1.25)
VII.E5.AP-273 3.3.1-95A, 2I 4 4 '4 4 +Structural Integrity Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 A--'I. I. 4 4Condensation (Internal)
Loss of MaterialCompressed AirMonitoring (B.2.1.15)
VII.D.AP-81 3.3.1-56B, 1LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-146 Section 3 -Aging Management Review ResultsTable 3.3.2-9 Drywell Pneumatic System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 AirMonitoring (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 aninternal 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 managethe 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) programwill 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 3.3-147License W lication 0 Section 3 -Aging Managemt Review ResultsTable 3.3.2-10Electrical Penetration Pressurization SystemSummary of Aging Management Evaluation Table 3.3.2-10 Electrical Penetration Pressurization SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 Acomponents, 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 AStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 AValve Body Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 AUncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 AStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 ALaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-148 Section 3 -Aging Management Review ResultsTable 3.3.2-10 Electrical Penetration Pressurization System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 3.3-149License Rene WP licationww 0 Section 3 -Aging Management Review ResultsTable 3.3.2-11Essential Cooling Water SystemSummary of Aging Management Evaluation Table 3.3.2-11 Essential Cooling Water SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemI 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingStainless Steel Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 AAir -Outdoor (External)
Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-126 3.3.1-12 ALoss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-263 3.3.1-15 AFish Barrier Filter Stainless Steel Air -Outdoor (External)
Loss of Material Open-Cycle Cooling Water III.B2.TP-6 3.5.1-93 E, 2System (B.2.1.12)
Raw Water (External)
Loss of Material Open-Cycle Cooling Water VII.C .A-54 3.3.1-40 ASystem (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 AUncontrolled (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 CSystem (B.2.1.12)
Throttle Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 CSystem (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 ZincCoolers TubesLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-150 Section 3 -Aging Management Review ResultsTable 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs Itemq 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 ZincCoolers)
TubesHeat 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 IIISheet (with internal Augmented Coatingscoating)
Monitoring andMaintenance Program(B.2.2.1)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-179 3.3.1-38 ASystem (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, 4Service Level IIIAugmented CoatingsMonitoring andMaintenance Program(B.2.2.1)
Loss of Material Open-Cycle Cooling Water VII.Cl.AP-194 3.3.1-37 CSystem (B.2.1.12)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 C15% Zinc or More Uncontrolled (External)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-179 3.3.1-38 ASystem (B.2.1.12)
Selective Leaching VII.C1.A-66 3.3.1-72 A(8.2.1.22)
LaSalle CountYlrion, Units 1 and 2License RenempWlication
.Page 3.3-151 0 Section 3 -Aging Managemt Review ResultsTable 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 CSystem (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 A15% 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 ALPCS 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 CComponents (B.2.1.21)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C .A-54 3.3.1-40 CSystem (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 2License Renewal Application Page 3.3-152 Section 3 -Aging Management Review ResultsTable 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 CSystem (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)
TubeSheetHeat 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 ASystem (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 CSystem (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 ASystem (B.2.1.12)
LaSalle County on, Units 1 and 2License ReneVW lication* Page 3.3-153 Section 3 -Aging Manageme Review ResultsTable 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 SideComponents 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 CComponents (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-110 3.3.1-25 DHeat 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 ATransfer (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-139 3.3.1-27 BPressure Boundary Stainless Steel Raw Water (External)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 CSystem (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 DHoses Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 CSystem (B.2.1.12)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C .A-54 3.3.1-40 ASystem (B.2.1.12)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-154 Section 3 -Aging Management Review ResultsTable 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsLeakage BoundaryCarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.I.A-77 3.3.1-78ARaw Water (Internal)
Loss of MaterialOpen-Cycle Cooling WateiSystem (B.2.1.12)
VII.C .AP-1833.3.1-38CVII.C .A-4003.3.1-127 E, 5Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 ARaw Water (Internal)
Loss of MaterialOpen-Cycle Cooling WateiSystem (B.2.1.12)
VII.C .A-543.3.1-40APressure BoundaryCarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1 .24'iVII.I.A-77 3.3.1-78AAir -Outdoor (External)
Loss of Material Buried and Underground VII.H1.A-24 3.3.1-80 E, 1Piping (B.2.1.28)
Concrete (External)
None None VII.J.AP-282 3.3.1-112 ACondensation 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 CSystem (B.2.1.12)
VII.C1.A-400 3.3.1-127 E, 5Soil (External)
Loss of MaterialBuried and Underground Piping (B.2.1.28)
VII.G.AP-198 3.3.1-106 AStainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 ACondensation (External)
CrackingExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.C .A-4053.3.1-132 A, 6Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.C .A-4053.3.1-132 A, 6LaSalle Countyon, Units 1 and 2License Rene W lication.Page 3.3-155 Section 3 -Aging Managetneview ResultsTable 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Stainless Steel Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 Acomponents, and System (B.2.1.12) piping elementsPump Casing (DIG Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-123 3.3.1-120 ACooling 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, 6Monitoring 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 ASystem (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 ACooling 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 CSystem (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 APool 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 CSystem (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 AAlloy Steel with System (B.2.1.12)
Stainless SteelCladdingLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-156 Section 3 -Aging Management Review ResultsTable 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 CSystem (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, 6Monitoring 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 ASystem (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, 4Service Level IIIAugmented CoatingsMonitoring andMaintenance Program(B.2.2.1)
Loss of Material Open-Cycle Cooling Wate VII.C1.AP-194 3.3.1-37 ASystem (B.2.1.12)
I I _ ILaSalle County" on, Units 1 and 2License ReneW lication.Page 3.3-157 0 Section 3 -Aging Manageteview ResultsTable 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemI 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 AAlloy Steel with System (B.2.1.12)
Stainless SteelCladdingStrainer Element Filter Stainless Steel Raw Water (External)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 ASystem (B.2.1.12)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 ASystem (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 AUncontrolled (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 CSystem (B.2.1.12)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C .A-54 3.3.1-40 ASystem (B.2.1.12)
Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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, 1Piping (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 CSystem (B.2.1.12)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-158 Section 3 -Aging Management Review ResultsTable 3.3.2-11 Essential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 ASystem (B.2.1.12)
_ _ ILaSalle Countliftion, Units 1 and 2License ReneWplication
.Page 3.3-159 Section 3 -Aging Manage9enReview ResultsTable 3.3.2-11 Essential Cooling Water System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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, andenvironment 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 coatingintegrity.
The Service Level III and Service Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage theidentified 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 flangesSA-181/SA-105; strainer body carbon steel) with internal coating in a raw water environment include loss of coating integrity.
The Service Level III andService Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable tocarbon steel (with internal coating) in a raw water environment.
LaSalle County Station, Units 1 and 2 Page 3.3-160License Renewal Application Section 3 -Aging Management Review ResultsTable 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 isused 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 gapsin insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dewpoint of the air on the external surfaces of the insulation.
LaSalle Countwftion, Units 1 and 2License ReneW plication 0.Page 3.3-161 0 Section 3 -Aging Manageet Review ResultsTable 3.3.2-12Fire Protection SystemSummary of Aging Management Evaluation Table 3.3.2-12 Fire Protection SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingRaw Water (External)
Loss of Material Bolting Integrity (B.2.1.11)
VII.G.A-33 3.3.1-64 E, 1Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-264 3.3.1-15 ASoil (External)
Loss of Material Buried and Underground VII.I.AP-241 3.3.1-109 APiping (B.2.1.28)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-242 3.3.1-14 AStainless Steel Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 AFire 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, 10Fire 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 AGalvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 CUncontrolled (External)
Air -Outdoor (External)
Loss of Material Fire Protection (B.2.1.16)
VII.I.A-78 3.3.1-78 E, 2VII.G.A-22 3.3.1-59 AFire Barriers (For Fire Barrier Aluminum Air- Indoor Cracking Fire Protection (B.2.1.16)
F, 3Steel Components)
Silicate Uncontrolled (External)
IIILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-162 Section 3 -Aging Management Review ResultsTable 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Fire Barriers (For Fire Barrier Ceramic Fiber Air -Indoor None Fire Protection (B.2.1.16)
F, 4Steel Components)
Uncontrolled (External)
Pyrocrete Air -Indoor Cracking Fire Protection (B.2.1.16)
F, 3Uncontrolled (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, 4Uncontrolled (External)
Elastomers Air- Indoor Change in Material Fire Protection (B.2.1.16)
VII.G.A-19 3.3.1-57 AUncontrolled (External)
Properties Grout Air- Indoor Cracking Fire Protection (B.2.1.16)
VII.G.A-90 3.3.1-60 A, 5Uncontrolled (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, 3Uncontrolled (External)
Mineral Fiber Air- Indoor None Fire Protection (B.2.1.16)
F, 4Uncontrolled (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 Aand 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 CUncontrolled (External)
Gypsum Air -Indoor Cracking Fire Protection (B.2.1.16)
F, 3Uncontrolled (External)
Reinforced Air- Indoor Concrete Cracking and Fire Protection (B.2.1.16)
VII.G.A-90 3.3.1-60 AConcrete 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 ALaSalle Count~j~
ion, Units 1 and 2License ReneW plication 0 Page 3.3-163 Section 3 -Aging Managemt Review ResultsTable 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Fire Barriers (Walls Fire Barrier Reinforced Air -Indoor Loss of Material Structures Monitoring VII.G.A-91 3.3.1-62 Aand 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 ASpalling 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 AStructures 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 APiping (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 APump) 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 Acomponents, 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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 ALaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-164 Section 3 -Aging Management Review ResultsTable 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 Acomponents, 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, 9Air -Outdoor (External)
Loss of Material External Surfaces VII.I.A-78 3.3.1-78 AMonitoring of Mechanical Components (B.2.1.24)
Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 ACondensation (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)
DamageLoss of Material Inspection of Internal VII.H2.AP-104 3.3.1-88 ASurfaces in Miscellaneous Piping and DuctingComponents (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, 8Soil (External)
Loss of Material Buried and Underground VII.G.AP-198 3.3.1-106 APiping (B.2.1.28)
Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 AUncontrolled (External)
Air -Outdoor (External)
Loss of Material External Surfaces VII.I.A-78 3.3.1-78 AMonitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
LaSalle County lition, Units 1 and 2License Rene plication
- Page 3.3-165 9 0 Section 3-Aging Managemeview ResultsTable 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Galvanized Steel Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 7components, and Service Level IIIpiping elements Augmented CoatingsMonitoring andMaintenance 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 AUncontrolled (External)
Air -Indoor Loss of Material Fire Water System VII.G.A-404 3.3.1-131 BUncontrolled (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 AIntermediate 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 AJockey Pump) _ _ Uncontrolled (External)
_ _ __LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-166 Section 3 -Aging Management Review ResultsTable 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Pump Casing (Fire Pressure Boundary Stainless Steel Raw Water (Internal)
Loss of Material Fire Water System VII.G.A-55 3.3.1-66 BJockey 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 Bless 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 Bless 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 Bless 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, 9Storage)
Uncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 CTanks (Retard Pressure Boundary Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 CChamber) less than 15% Uncontrolled (External)
Zinc Raw Water (Internal)
Loss of Material Fire Water System VII.G.AP-197 3.3.1-64 DI_ (B.2.1.17)
LaSalle County~lton, Units 1 and 2License ReneV P lication.Page 3.3-167 0 0 Section 3 -Aging Managem9Review ResultsTable 3.3.2-12 Fire Protection System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Tanks (Retard Pressure Boundary Ductile Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AChamber)
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 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 Aless than 15% Uncontrolled (External)
Zinc Air/Gas -Dry (Internal)
None None VII.J.AP-8 3.3.1-114 ACondensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (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 AUncontrolled (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 AUncontrolled (External)
Monitoring of Mechanical Components (8.2.1.24)
Fire Protection (B.2.1.16)
VII.G.AP-150 3.3.1-58 A, 9Air/Gas -Dry (Internal)
None None VII.J.AP-6 3.3.1-121 ALaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-168 Section 3 -Aging Management Review ResultsTable 3.3.2-12Fire Protection System(Continued)
Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesRequiring Programs ItemManagement Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (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 ISelective Leaching VII.G.A-51 3.3.1-72 A(B.2.1.22)
I I ISoil (External)
Loss of MaterialBuried and Underground PiDina (B.2.1.28)
VII.G.AP-1198 3.3.1-106 A-. + 4Selective Leaching(B.2.1.221 VII.G.A-02 3.3.1-72ALaSalle Countydion, Units 1 and 2License Renelw lication.Page 3.3-169 0 0 Section 3- Aging Managemt Review ResultsTable 3.3.2-12 Fire Protection System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 inan 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 2License Renewal Application Page 3.3-170 Section 3 -Aging Management Review ResultsTable 3.3.2-12Fire 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 besusceptible to the same aging effects and mechanisms as reinforced concrete.
These aging effects and mechanisms are managed by the FireProtection (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 theAging 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 andService Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable togalvanized 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 managethe 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, pipingcomponents, 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 DuctingComponents (B.2.1.25) program in managing the aging effect(s) applicable to this component type, material, and environment combination.
Thedamper housings for dampers with a fire barrier intended function are evaluated with the Fire Protection System and are inspected in accordance withFire Protection (B.2.1.16) program requirements.
Fire barrier damper housings located within the in scope boundary of the various ventilation systemsalso have a pressure boundary intended function and are inspected in accordance with the Inspection of Internal Surfaces in Miscellaneous Piping andDucting Components (B.2.1.25) program.
The pressure boundary intended function is evaluated with the various ventilation systems.LaSalle CountwK'on, Units 1 and 2License ReneWOFplication 0 Page 3.3-171 Section 3 -Aging Manage#eReview ResultsTable 3.3.2-13Fuel Pool Cooling and Storage SystemSummary of Aging Management Evaluation Table 3.3.2-13 Fuel Pool Cooling and Storage SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.l.AP-124 3.3.1-15 ABoltingStainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 AControl Rod Blade Structural Integrity Stainless Steel Treated Water Loss of Material One-Time Inspection VII.A2.A-98 3.3.1-125 CStorage Racks (External)
(B.2.1.21)
Water Chemistry (B.2.1.2)
VII.A2.A-98 3.3.1-125 DFuel Storage Structural Integrity Stainless Steel Treated Water Loss of Material One-Time Inspection VII.A2.A-98 3.3.1-125 CRacks (Defective (External)
(B.2.1.21)
Fuel) Water Chemistry (B.2.1.2)
VII.A2.A-98 3.3.1-125 DFuel Storage Structural Integrity Aluminum Alloy Air- Indoor None None VII.J.AP-135 3.3.1-113 CRacks (New Fuel Uncontrolled (External)
Storage)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 CUncontrolled (External)
Fuel Storage Absorb Neutrons Boral Treated Water Reduction of Neutron Monitoring of Neutron-VII.A2.AP-236 3.3.1-102 ARacks (Unit 1 (External)
Absorbing Capacity; Absorbing Materials OtherSpent Fuel) Change in Dimensions Than Boraflex (B.2.1.27) and Loss of MaterialStructural 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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-172 Section 3 -Aging Management Review ResultsTable 3.3.2-13 Fuel Pool Cooling and Storage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs Itemt Management Fuel Storage Absorb Neutrons Rio-Tinto Alcan Treated Water Reduction of Neutron Monitoring of Neutron-VII.A2.AP-236 3.3.1-102 ARacks (Unit 2 Composite (External)
Absorbing Capacity; Absorbing Materials OtherSpent Fuel) Change in Dimensions Than Boraflex (B.2.1.27) and Loss of MaterialStructural 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 BHeat 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 DHoses Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (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 Acomponents, 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 BWaste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
Waste Water (Internal)
None None VII.J.AP-277 3.3.1-119 ALaSalle Countylion, Units 1 and 2License ReneWplication O Page 3.3-173 Section 3 -Aging Manage9Review ResultsTable 3.3.2-13 Fuel Pool Cooling and Storage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Piping, piping Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 Acomponents, 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 BWaste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 BWaste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 BWaste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (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 APool 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 2License Renewal Application Page 3.3-174 Section 3 -Aging Management Review ResultsTable 3.3.2-13 Fuel Pool Cooling and Storage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BPool CoolingPump)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 DTanks (Skimmer Pressure Boundary Stainless Steel Air -Indoor None None VII.J AP-17 3.3.1-120 CSurge Tanks) Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 CSurfaces in Miscellaneous Piping and DuctingComponents (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 DValve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 BWaste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 BLaSalle Count-lMion, Units 1 and 2License ReneW plication
.Page 3.3-175 Section 3 -Aging Manage Review ResultsTable 3.3.2-13 Fuel Pool Cooling and Storage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve Body Leakage Boundary Stainless Steel Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 BWaste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-176 Section 3 -Aging Management Review ResultsTable 3.3.2-13 Fuel Pool Cooling and Storage System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 3.3-177License Rene W licationWw 0 O Section 3 -Aging Managem#Review ResultsTable 3.3.2-14Nonessential Cooling Water SystemSummary of Aging Management Evaluation Table 3.3.2-14 Nonessential Cooling Water SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.L.AP-124 3.3.1-15 ABoltingRaw Water (External)
Loss of Material Bolting Integrity (B.2.1.11)
VII.G.A-33 3.3.1-64 E, 2, 6Loss of Preload Bolting Integrity (B.2.1.11)
VII.L.AP-264 3.3.1-15 A, 2Structural 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, 6Alloy Steel Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-264 3.3.1-15 ABoltingHeat 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, 7Components (External)
Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 3Service Level IIIAugmented CoatingsMonitoring andMaintenance Program(B.2.2.1)
Loss of Material Open-Cycle Cooling Wate VII.C1.AP-194 3.3.1-37 CSystem (B.2.1.12) rlLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-178 Section 3 -Aging Management Review ResultsTable 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemqI 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 ACondenser Unit) ZincTubes 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, 3Components Service Level IIIAugmented CoatingsMonitoring andMaintenance Program(B.2.2.1)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-194 3.3.1-37 CSystem (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 AHVAC Condenser ZincUnit) 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 ILaSalle Countydion, Units 1 and 2License Rene W lication0 Page 3.3-179 Section 3-Aging Managemeview ResultsTable 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement HHeat 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 IIITube Side coating)
Augmented CoatingsComponents Monitoring andMaintenance Program(B.2.2.1)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-194 3.3.1-37 CSystem (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, 7Condenser)
Tube (External)
Monitoring of Mechanical Side Components Components (B.2.1.24)
Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 3Service Level IIIAugmented CoatingsMonitoring andMaintenance Program(B.2.2.1)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-194 3.3.1-37 CSystem (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 AContainment ZincVentilation Chiller System (B.2.1.12)
Service WaterCondenser)
TubesLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-180 Section 3 -Aging Management Review ResultsTable 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemT_ 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 AComponents 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 ARoom A/C Unit) Zinc System (B.2.1.12)
TubesHeat 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, 7Exchanger)
Tube (External)
Monitoring of Mechanical Side Components Components (B.2.1.24)
Raw Water (Internal)
Loss of Coating Integrity Service Level III and H, 3Service Level IIIAugmented CoatingsMonitoring andMaintenance Program(B.2.2.1)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-194 3.3.1-37 CSystem (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 Acomponents, and Uncontrolled (External)
Monitoring of Mechanical piping elements Components (B.2.1.24)
LaSalle County.i~on, Units 1 and 2License RenelW lication0 Page 3.3-181 Section 3 -Aging Managem9Review ResultsTable 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemI __ __ _Management Piping, pipingcomponents, andpiping elementsLeakage BoundaryCarbon SteelCondensation (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.C .A-4053.3.1-132 A, 7Raw Water (Internal)
Loss of MaterialOpen-Cycle Cooling WaterSystem (B.2.1.12)
VII.C1.AP-183 3.3.1-38CVIICI .A-4003.3.1-127 E. 4I 4 4 + 4Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 ACondensation 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, 7Monitoring of Mechanical Components (B.2.1.24)
Raw Water (Internal)
Loss of MaterialOpen-Cycle Cooling WaterSystem (B.2.1.12)
VII.C .A-543.3.1-40AV t 1~ 4 4 4Pressure Boundary Aluminum AlloyRaw Water (External)
Loss of MaterialOpen-Cycle Cooling WaterSvstem (B.2.1.12)
VII.G.AP-180 3.3.1-65E, 11- ~. -.+ 4 _______Raw Water (Internal)
Loss of MaterialOpen-Cycle Cooling WaterSvstem (B.2.1.12)
VII.G.AP-1180 3.3.1-65E, 1+ + -4 4 _____Carbon SteelAir- IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII. I.A-773.3.1-78AAir -Outdoor (External)
Loss of Material Buried and Underground VII.H1 .A-24 3.3.1-80 E, 5Piping (B.2.1.28)
External Surfaces VII.C1.A-405 3.3.1-132 AMonitoring of Mechanical Components (B.2.1.24)
Concrete (External)
None None VII.J.AP-282 3.3.1-112 ACondensation (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.C1 .A-4053.3.1-132 A, 7LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-182 Section 3 -Aging Management Review ResultsTable 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Carbon Steel Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.AP-183 3.3.1-38 Ccomponents, and System (B.2.1.12)
VII.C1.A-400 3.3.1-127 E, 4piping elementsSoil (External)
Loss of Material Buried and Underground VII.C3.AP-198 3.3.1-106 APiping (B.2.1.28)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 ASystem (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 CSystem (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 AGland 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 CSystem (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 CScreen Framework (with external System (B.2.1.12) coating)Gray Cast Iron Concrete (External)
None None VII.J.AP-282 3.3.1-112 CLaSalle Countyiltion, Units 1 and 2License ReneW plication
.Page 3.3-183 9 0 Section 3 -Aging Management Review ResultsTable 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 CScreen 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 AUncontrolled (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 CSystem (B.2.1.12)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 Aless 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 ASystem (B.2.1.12)
Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 CSystem (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 AUncontrolled (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 2License Renewal Application Page 3.3-184 Section 3 -Aging Management Review ResultsTable 3.3.2-14 Nonessential Cooling Water System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 ASystem (B.2.1.12)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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, 5Piping (B.2.1.28)
External Surfaces VII.C1.A-405 3.3.1-132 AMonitoring 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 CSystem (B.2.1.12)
Gray Cast Iron Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 CSystem (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 2License ReneW plication 9 Page 3.3-185 0 0 Section 3 -Aging Management Review ResultsTable 3.3.2-14 Nonessential Cooling Water System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 andService Level III Augmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable tocarbon 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 isused 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, andenvironment 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 gapsin insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dewpoint of the air on the external surfaces of the insulation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-186 Section 3 -Aging Management Review ResultsTable 3.3.2-15Nonsafety-Related Ventilation SystemSummary of Aging Management Evaluation Table 3.3.2-15 Nonsafety-Related Ventilation SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingHeat 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 ACondenser)
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 CContainment Vent Zinc Water (Internal)
Systems (B.2.1.13)
Chiller GlycolCondenser)
TubesLaSalle County,4Kon, Units 1 and 2License ReneW lication.Page 3.3-187 0 0 Section 3 -Aging Management Review ResultsTable 3.3.2-15 Nonsafety-Related Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 ASupply and Water (Internal)
Systems (B.2.1.13)
Exhaust Coils)Tube SideComponents 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, 1Switchgear Rm (External)
Surfaces in Miscellaneous Supply and Piping and DuctingExhaust Coils) Components (B.2.1.25)
TubesPiping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 Acomponents, 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 AWater (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 AUncontrolled (External)
Closed Cycle Cooling None None VII.J.AP-166 3.3.1-117 AWater (Internal)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 ALaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-188 Section 3 -Aging Management Review ResultsTable 3.3.2-15 Nonsafety-Related Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemI Management Piping, piping Leakage Boundary Stainless Steel Air -Indoor None None VII J.AP-17 3.3.1-120 Acomponents, and Uncontrolled (External) piping elements Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 AWater (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 ATank 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 CElectric 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 AWater (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 CRecovery 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 AWater (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 CSurfaces in Miscellaneous Piping and DuctingComponents (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 CRecovery 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 2License Rene W lication0 Page 3.3-189 0Section 3 -Aging Manage eview ResultsTable 3.3.2-15 Nonsafety-Related Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Tanks (Heat Leakage Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 CRecovery System Surfaces in Miscellaneous Make-up Tank) Piping and DuctingComponents (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 AUncontrolled (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 AWater (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 2License Renewal Application Page 3.3-190 Section 3 -Aging Management Review ResultsTable 3.3.2-15 Nonsafety-Related Ventilation System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 DuctingComponents (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 gapsin insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dewpoint of the air on the external surfaces of the insulation.
LaSalle Countympon, Units 1 and 2 RaPage 3.3-191License RenevW licationWW Section 3 -Aging Managemevn Rview ResultsTable 3.3.2-16Plant Drainage SystemSummary of Aging Management Evaluation Table 3.3.2-16 Plant Drainage SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingHeat 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 CSide Components Surfaces in Miscellaneous Piping and DuctingComponents (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 CExchanger)
Tube Surfaces in Miscellaneous Side Components Piping and DuctingComponents (B.2.1.25)
Hoses Leakage Boundary Polymers Air -Indoor None None VII.J.AP-268 3.3.1-119 AUncontrolled (External)
Waste Water (Internal)
None None G, 1Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-192 Section 3 -Aging Management Review ResultsTable 3.3.2-16 Plant Drainage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Hoses Leakage Boundary Stainless Steel Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (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 Acomponents, 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 ASurfaces in Miscellaneous VII.E5.A-400 3.3.1-127 E, 2Piping and DuctingComponents (B.2.1.25)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 Aless than 15% Uncontrolled (External)
Zinc Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-272 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 AUncontrolled (External)
Waste Water (Internal)
Loss of Coating Integrity Service Level III and H, 3Service Level IIIAugmented CoatingsMonitoring andMaintenance Program(B.2.2.1)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 ASurfaces in Miscellaneous VII.E5.A-400 3.3.1-127 E, 2Piping and DuctingComponents (B.2.1.25)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
Waste Water (Internal)
None None VII.J.AP-277 3.3.1-119 ALaSalle CountyJwton, Units 1 and 2License Renev~W lication0 Page 3.3-193 Section 3 -Aging ManagemenReview ResultsTable 3.3.2-16 Plant Drainage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 Acomponents, and Uncontrolled (External) piping elements Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Concrete (External)
None None VII.J.AP-282 3.3.1-112 AWaste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 ASurfaces in Miscellaneous VII.E5.A-400 3.3.1-127 E, 2Piping and DuctingComponents (B.2.1.25)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 Aless than 15% Uncontrolled (External)
Zinc Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-272 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (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 2License Renewal Application Page 3.3-194 Section 3 -Aging Management Review ResultsTable 3.3.2-16 Plant Drainage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 DuctingDrain 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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 ALeakoff 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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 ASurfaces in Miscellaneous Piping and DuctingComponents (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 ABuilding Equipment Uncontrolled (External)
Monitoring of Mechanical Drain Tank) Components (B.2.1.24)
LaSalle Countygimon, Units 1 and 2License Rene~W lication.Page 3.3-195 0Section 3 -Aging Management Review ResultsTable 3.3.2-16 Plant Drainage System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Tanks (Reactor Leakage Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-280 3.3.1-95 ABuilding Equipment Surfaces in Miscellaneous Drain Tank) Piping and DuctingComponents (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-281 3.3.1-91 ASurfaces in Miscellaneous Piping and DuctingComponents (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 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingI Components (B.2.1.25)
ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-196 Section 3 -Aging Management Review ResultsTable 3.3.2-16 Plant Drainage System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 aregistered trademark of Norton Performance Plastics that represents a family of various thermoplastic polymers.
Tygon is a PVC-based material thatis 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 Pipingand 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 IIIAugmented Coatings Monitoring and Maintenance Program (B.2.2.1) is used to manage the identified aging effect applicable to galvanized steel in awaste water environment.
LaSalle Countyl on, Units 1 and 2 Page 3.3-197License Rene W lication V
Section 3 -Aging Managemen Review ResultsTable 3.3.2-17Primary Containment Ventilation SystemSummary of Aging Management Evaluation Table 3.3.2-17 Primary Containment Ventilation SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingDucting and Leakage Boundary Stainless Steel Condensation Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 A, 1Components (External)
Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 CSurfaces in Miscellaneous Piping and DuctingComponents (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 AOil 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 ATube Side Water (Internal)
Systems (B.2.1.13)
Components LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-198 Section 3 -Aging Management Review ResultsTable 3.3.2-17 Primary Containment Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement 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 AContainment Vent Zinc Water (Internal)
Systems (B.2.1.13)
Chiller Evaporator)
TubesHeat 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, 2Ventilation HX and (External)
Surfaces in Miscellaneous Drywell Area Piping and DuctingCooler) 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 Acomponents, 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 AWater (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 Aless 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 AI Uncontrolled (External)
_ --]ILaSalle County on, Units 1 and 2License ReneAyPlication
.Page 3.3-199 0Section 3 -Aging Managet Review ResultsTable 3.3.2-17 Primary Containment Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Leakage Boundary Stainless Steel Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 Acomponents, 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 AUncontrolled (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 AWater (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 APumps) 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 CWater 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 AChemical 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 2License Renewal Application Page 3.3-200 Section 3 -Aging Management Review ResultsTable 3.3.2-17 Primary Containment Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Tanks (Chilled Leakage Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VII.H2.A-23 3.3.1-89 CWater Holdup and Surfaces in Miscellaneous Expansion Tanks, Piping and DuctingChilled 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 AUncontrolled (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 AWater (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 A15% 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 AUncontrolled (External)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 AWater (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 AUncontrolled (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 AWater (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 AUncontrolled (External)
I I ILaSalle County~jion, Units 1 and 2License )lication
- Page 3.3-201 0 0 Section 3 -Aging ManageReview ResultsTable 3.3.2-17 Primary Containment Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-202 Section 3 -Aging Management Review ResultsTable 3.3.2-17 Primary Containment Ventilation System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 Pipingand 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 DuctingComponents (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 gapsin insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dewpoint of the air on the external surfaces of the insulation.
LaSalle County 4fton, Units 1 and 2 O Page 3.3-203License )lication 0 Section 3 -Aging Managel eview ResultsTable 3.3.2-18Process Radiation Monitoring SystemSummary of Aging Management Evaluation Table 3.3.2-18 Process Radiation Monitoring SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingStainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 AHoses Leakage Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 AWater (Internal)
Systems (B.2.1.13)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1.A-54 3.3.1-40 ASystem (B.2.1.12)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Piping, piping Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 Acomponents, and Uncontrolled (External) piping elements Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 AWater (Internal)
Systems (B.2.1.13)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C1 .A-54 3.3.1-40 AI__ __ I__ System (B.2.1.12)
_ _ _ _LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-204 Section 3 -Aging Management Review ResultsTable 3.3.2-18 Process Radiation Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs Itemt 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 Acomponents, and Surfaces in Miscellaneous piping elements Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 AStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Structural Integrity Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pump Casing ( Pressure Boundary Aluminum Alloy Air -Indoor None None VII.J.AP-135 3.3.1-113 ASGTS and SVS Uncontrolled (External)
Wide Range Condensation (Internal)
Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 ASample Pumps) Surfaces in Miscellaneous Piping and DuctingI _Components (B.2.1.25)
LaSalle Countyiftion, Units 1 and 2License ReneW licationO Page 3.3-205 0 0 Section 3 -Aging Manage9 eview ResultsTable 3.3.2-18 Process Radiation Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 APumps) 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 ASample Pumps) Surfaces in Miscellaneous Piping and DuctingComponents (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 AWater, 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 ASystem (B.2.1.12)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-272 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Valve Body Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 AWater (Internal)
Systems (B.2.1.13)
Raw Water (Internal)
Loss of Material Open-Cycle Cooling Water VII.C .A-54 3.3.1-40 ASystem (B.2.1.12) jLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-206 Section 3 -Aging Management Review ResultsTable 3.3.2-18 Process Radiation Monitoring System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Valve Body Leakage Boundary Stainless Steel Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Structural Integrity Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingI Components (B.2.1.25)_
LaSalle Countvftion, Units 1 and 2License ReneW plication
.Page 3.3-207 Section 3- Aging Management Review ResultsTable 3.3.2-18Process Radiation Monitoring System(Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 2License Renewal Application Page 3.3-208 Section 3 -Aging Management Review ResultsTable 3.3.2-19Process Sampling and Post Accident Monitoring SystemSummary of Aging Management Evaluation Table 3.3.2-19 Process Sampling and Post Accident Monitoring SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingStainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ACompressor Structural Integrity Carbon or Low Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 AHousing 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 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Flow Device Pressure Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 CSurfaces in Miscellaneous Piping and DuctingComponents (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, 1Treated 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 BLaSalle Countilftion, Units 1 and 2License ReneW plication
- Page 3.3-209 0 0 Section 3 -Aging Manageet Review ResultsTable 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 NotesType Function Requiring Programs ItemManagement Flow Device Throttle Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 CSurfaces in Miscellaneous Piping and DuctingComponents (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, 1Treated 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 BPiping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIDA-80 3.3.1-78 Acomponents, 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 AWater (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 BGlass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 ATreated Water (Internal)
None None VII.J.AP-51 3.3.1-117 AStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Closed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 AWater (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-210 Section 3 -Aging Management Review ResultsTable 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 NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsLeakage BoundaryStainless Steel Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
VII.E4.AP-1 103.3.1-25AWater Chemistry (B.2.1.2)
VII.E4.AP-1 103.3.1-25Bt 4 -. .+ 4Waste Water (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComoonents (B.2.1.25)
VII.E5.AP-278 3.3.1-95AF + F 4 '+ F 4Pressure BoundaryGlassAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-14 3.3.1-117 AAir/Gas -Dry (Internal)
None None VII.J.AP-98 3.3.1-117 ACondensation (Internal)
NoneNoneVII.J.AP-97 3.3.1-117 AStainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 AAir/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 ACondensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 CSurfaces in Miscellaneous Piping and DuctingComponents (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, 1Treated Water (Internal)
Loss of MaterialOne-Time Inspection (8.2.1.21)
Water Chemistry (B.2.1.2)
VII.E4.AP-1 103.3.1-25A+/- 4VII.E4.AP-1 103.3.1-25BStructural Integrity Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 ACondensation (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.F3.AP-99 3.3.1-94CLaSalle Countvftion, Units 1 and 2License Rene V plication
.Page 3.3-211 0 0 Section 3 -Aging Management Review ResultsTable 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 NotesType Function Requiring Programs ItemManagement 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 CSurfaces in Miscellaneous Piping and DuctingComponents (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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 ASurfaces in Miscellaneous Piping and DuctingComponents (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Tanks (HRSS Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 CWaste Tank) Uncontrolled (External)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-212 Section 3 -Aging Management Review ResultsTable 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 NotesType Function Requiring Programs ItemManagement Valve BodyLeakage BoundaryCarbon SteelAir -IndoorUncontrolled (External)
Loss of MaterialExternal SurfacesMonitoring of Mechanical Components (B.2.1.24)
VII.D.A-80 3.3.1-78AClosed Cycle Cooling Loss of Material Closed Treated Water VII.C2.AP-202 3.3.1-45 AWater (Internal)
Systems (B.2.1.13)
Treated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
VII.E4.AP-106 3.3.1-21A.4 I. _______Water Chemistry (B.2.1.2)
VII.E4.AP-106 3.3.1-21BCopper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A15% Zinc or More Uncontrolled (External)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-272 3.3.1-95 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Selective Leaching VII.E5.A-407 3.3.1-72 A(B.2.1.22)
Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 AClosed Cycle Cooling Loss of Material Closed Treated Water VII.C2.A-52 3.3.1-49 AWater (Internal)
Systems (B.2.1.13)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 CSurfaces in Miscellaneous Piping and DuctingComponents (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 BWaste Water (Internal)
Loss of MaterialInspection of InternalSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
VII.E5.AP-278 3.3.1-95APressure Boundary I Aluminum AlloyAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-135 3.3.1-113 ALaSalle Count, tion, Units 1 and 2License ReneWplication
.Page 3.3-213 0Section 3 -Aging Manage*e eview ResultsTable 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 NotesType Function Requiring Programs ItemManagement Valve Body Pressure Boundary Aluminum Alloy Air/Gas -Dry (Internal)
None None VII.J.AP-37 3.3.1-113 ACopper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A15% Zinc or More Uncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-9 3.3.1-114 AStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Air/Gas -Dry (Internal)
None None VII.J.AP-22 3.3.1-120 ACondensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 CSurfaces in Miscellaneous Piping and DuctingComponents (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 BStructural Integrity Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F3.AP-99 3.3.1-94 CSurfaces in Miscellaneous Piping and DuctingComponents_(B.2.1.25)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-214 Section 3 -Aging Management Review ResultsTable 3.3.2-19 Process Sampling and Post Accident Monitoring System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 thesuppression pool.LaSalle County on, Units 1 and 2 _ Page 3.3-215License Rene, W ication Section 3 -Aging Manageleview ResultsTable 3.3.2-20Radwaste SystemSummary of Aging Management Evaluation Table 3.3.2-20 Radwaste SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.1
- 1) VII.I.AP-124 3.3.1-15 ABoltingStainless Steel Air- Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.I.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 APiping, piping Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 Acomponents, 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 BStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 BPump 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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-216 Section 3 -Aging Management Review ResultsTable 3.3.2-20 Radwaste System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Tanks (RWCU Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 CCleanup Phase Uncontrolled (External)
Separators)
Condensation (Internal)
Loss of Material Inspection of Internal VII.E5.AP-273 3.3.1-95 CSurfaces in Miscellaneous Piping and DuctingComponents (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 DValve Body Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 BStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 BLaSalle Countvolon, Units 1 and 2License Rene W plication
.Page 3.3-217 0 0 Section 3 -Aging Management Review ResultsTable 3.3.2-20 Radwaste System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 3.3-218License Renewal Application Section 3 -Aging Management Review ResultsTable 3.3.2-21Reactor Water Cleanup SystemSummary of Aging Management Evaluation Table 3.3.2-21 Reactor Water Cleanup SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingHeat 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 AExchangers)
Shell (Internal)
(B.2.1.21)
Side Components Water Chemistry (B.2.1.2)
VII.E3.AP-120 3.3.1-19 BLoss 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 DHeat 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 ASide Components (Internal)
(B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-120 3.3.1-19 BLoss 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 DLaSalle CountY on, Units 1 and 2License ReneW lication0 Page 3.3-219 Section 3 -Aging Managemt Review ResultsTable 3.3.2-21 Reactor Water Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AExchangers)
Tube (Internal)
(B.2.1.21)
Side Components Water Chemistry (B.2.1.2)
VII.E3.AP-120 3.3.1-19 BLoss 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 DHeat 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 ASide Components (Internal)
(B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-1 12 3.3.1-20 BLoss 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 DStainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 CUncontrolled (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 BLoss 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 DLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-220 Section 3 -Aging Management Review ResultsTable 3.3.2-21 Reactor Water Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 CComponents (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 DPiping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 Acomponents, 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, 1DamageLoss 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 BWall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 ACorrosion (B.2.1.10)
Glass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
Treated Water (Internal)
None None VII.J.AP-51 3.3,1-117 AStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Treated Water (Internal)
Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 1DamageLoss 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 BTreated 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 DLaSalle Count. tion, Units 1 and 2License ReneWplication 0 Page 3.3-221 Section 3 -Aging Managem eview ResultsTable 3.3.2-21 Reactor Water Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Piping, piping Leakage Boundary Stainless Steel Treated Water > 140 F Cumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 1components, and (Internal)
Damagepiping 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 BPressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Cumulative Fatigue TLAA V.D2.E-10 3.2.1-1 A, 1DamageLoss 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 BWall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 ACorrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 BPump 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 BPump 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 2License Renewal Application Page 3.3-222 Section 3 -Aging Management Review ResultsTable 3.3.2-21 Reactor Water Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BPrecoat 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 APump) (B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E3.AP-106 3.3.1-21 BTanks (Clean-Up Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AFilter 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 DTanks (Clean-Up Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AFilter 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 DValve Body Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 BWall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 ACorrosion (B.2.1.10)
LaSalle Countyglion, Units 1 and 2License ReneW plication
.Page 3.3-223 0 Section 3 -Aging Managemt Review ResultsTable 3.3.2-21 Reactor Water Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve Body Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 BTreated 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 DLoss 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 BPressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 AUncontrolled (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 BWall Thinning Flow-Accelerated V.D2.E-09 3.2.1-11 ACorrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-224 Section 3 -Aging Management Review ResultsTable 3.3.2-21 Reactor Water Cleanup System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 3.3-225License Rene yPlication 1 0 Section 3 -Aging Managem9Review ResultsTable 3.3.2-22Safety-Related Ventilation SystemSummary of Aging Management Evaluation Table 3.3.2-22 Safety-Related Ventilation SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Bolting Mechanical Closure Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 CUncontrolled (External)
Ducting and Leakage Boundary Stainless Steel Condensation Loss of Material Inspection of Internal VII.F2.AP-99 3.3.1-94 A, 1Components (External)
Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Waste Water (Internal)
Loss of Material Inspection of Internal VII.E5.AP-278 3.3.1-95 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pressure Boundary Aluminum Alloy Air -Indoor None None VII.J.AP-135 3.3.1-113 CUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F2.AP-142 3.3.1-92 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Carbon Steel Air -Indoor Loss of Material External Surfaces VII.F2.A-10 3.3.1-78 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Elastomers Air- Indoor Hardening and Loss of External Surfaces VII.F2.AP-102 3.3.1-76 AUncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-226 Section 3 -Aging Management Review ResultsTable 3.3.2-22 Safety-Related Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement Ducting and Pressure Boundary Elastomers Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 2Components Strength Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Galvanized Steel Air- Indoor None None VII.J.AP-13 3.3.1-116 CUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F4.A-08 3.3.1-90 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 CUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.F2.AP-99 3.3.1-94 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Flexible Pressure Boundary Elastomers Air -Indoor Hardening and Loss of External Surfaces VII.F2.AP-102 3.3.1-76 AConnection Uncontrolled (External)
Strength Monitoring of Mechanical Components (B.2.1.24)
Loss of Material External Surfaces VII.F2.AP-113 3.3.1-82 AMonitoring of Mechanical Components (B.2.1.24)
Condensation (Internal)
Hardening and Loss of Inspection of Internal G, 2Strength Surfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Loss of Material Inspection of Internal G, 2Surfaces in Miscellaneous Piping and DuctingComponents (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 DuctingCoolers)
Fins Components (B.2.1 .25)LaSalle Countymon, Units 1 and 2License Rene W lication.Page 3.3-227 0Section 3 -Aging Manager~eeview ResultsTable 3.3.2-22 Safety-Related Ventilation System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 CCoolers)
Shell Side Surfaces in Miscellaneous Components Piping and DuctingComponents (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 DuctingCoolers)
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, 4less than 15% (External)
Surfaces in Miscellaneous Zinc Piping and DuctingComponents (B.2.1.25)
Piping, piping Pressure Boundary Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 Acomponents, 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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Valve Body Pressure Boundary Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A15% Zinc or More Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-228 Section 3 -Aging Management Review ResultsTable 3.3.2-22 Safety-Related Ventilation System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 DuctingComponents (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 heattransfer aging effect applicable to this component type, material, and environment combination.
The component is located within HVAC ducting andcomponents, and the external surfaces of this component are subject to the internal HVAC environment of condensation during normal operation.
TheInspection of Internal Surfaces in Miscellaneous Piping and Ducting Components (B.2.1.25) program performs visual inspections which are capable ofidentifying 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 DuctingComponents (B.2.1.25) program is used to manage the applicable aging effects.LaSalle Count) on, units 1 and 2 Page 3.3-229License ReneW lication 0 Section 3 -Aging Management Review ResultsTable 3.3.2-23Standby Liquid Control SystemSummary of Aging Management Evaluation Table 3.3.2-23 Standby Liquid Control SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingStainless Steel Air -Indoor Loss of Material Bolting Integrity (B.2.1.11)
VII.L.AP-125 3.3.1-12 ABolting Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 APiping, piping Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 Acomponents, 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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Copper Alloy with Air -Indoor None None VII.J.AP-144 3.3.1-114 A15% Zinc or More Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal VII.G.AP-143 3.3.1-89 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Treated Water (Internal)
Cracking One-Time Inspection H, 2(B.2.1.21)
Water Chemistry (B.2.1.2)
H, 2Loss 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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-230 Section 3 -Aging Management Review ResultsTable 3.3.2-23 Standby Liquid Control System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1 801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsLeakage BoundaryCopper Alloy with15% Zinc or MoreTreated Water (Internal)
Loss of MaterialSelective Leaching(B.2.1.22)
VII. E4.AP-323.3.1-72AGlass Air -Indoor None None VII.J.AP-14 3.3.1-117 AUncontrolled (External)
Condensation (Internal)
None None VII.J.AP-97 3.3.1-117 ASodium Pentaborate None None G, 1Solution (Internal)
Treated Water (Internal)i None None VII.J.AP-51 3.3.1-117 AStainless SteelAir- IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 ACondensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Sodium Pentaborate Loss of Material One-Time Inspection VII.E2.AP-141 3.3.1-25 ASolution (Internal)
(B.2.1.21)
_Water Chemistry (B.2.1.2)
VII.E2.AP-141 3.3.1-25 BTreated Water (Internal)l Loss of MaterialOne-Time Inspection (B.2.1.21)
VII.A4.AP-1 103.3.1-25AWater Chemistry (B.2.1.2)
VII.A4.AP-1 103.3.1-25BPressure Boundary I Stainless SteelAir -IndoorUncontrolled (External)
NoneNoneVII.J.AP-17 3.3.1-120 ACondensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Sodium Pentaborate Loss of Material One-Time Inspection VII.E2.AP-141 3.3.1-25 ASolution (Internal)
(B.2.1.21)
_Water Chemistry (B.2.1.2)
VII.E2.AP-141 3.3.1-25 BTreated Water (Internal)
Loss of MaterialOne-Time Inspection (B.2.1.21)
VII.A4.AP-1 103.3.1-25ALaSalle CountwiLion, Units 1 and 2License Rene plication
.Page 3.3-231 0 0 Section 3 -Aging Management Review ResultsTable 3.3.2-23 Standby Liquid Control System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 Bcomponents, and Structural Integrity Carbon Steel Air -Indoor Loss of Material External Surfaces VII.I.A-77 3.3.1-78 Apiping 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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Pump Casing (SLC Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 APump) 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 BTanks (SLC Pressure Boundary Stainless Steel Air- Indoor None None VII.JAP-17 3.3.1-120 ASolution Tank) Uncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 CSurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Sodium Pentaborate Loss of Material One-Time Inspection VII.E2.AP-141 3.3.1-25 CSolution (Internal)
(B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E2.AP-141 3.3.1-25 DTanks (SLC Test Leakage Boundary Stainless Steel Air -Indoor None None VlI.JAP-17 3.3.1-120 CTank) Uncontrolled (External)
_ _ILaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-232 Section 3 -Aging Management Review ResultsTable 3.3.2-23 Standby Liquid Control System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Tanks (SLC Test Leakage Boundary Stainless Steel Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 CTank) Surfaces in Miscellaneous Piping and DuctingComponents (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 DValve Body Leakage Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (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 BPressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Inspection of Internal V.D2.EP-61 3.2.1-48 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Sodium Pentaborate Loss of Material One-Time Inspection VII.E2.AP-141 3.3.1-25 ASolution (Internal)
(B.2.1.21)
Water Chemistry (B.2.1.2)
VII.E2.AP-141 3.3.1-25 BTreated 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 BStructural Integrity Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
I ILaSalle Countvlion, Units 1 and 2License ReneW plication
.Page 3.3-233 Section 3 -Aging Management Review ResultsTable 3.3.2-23Standby Liquid Control System(Continued)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-234 Section 3 -Aging Management Review ResultsTable 3.3.2-23 Standby Liquid Control System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 3.3-235License Rene V plication Section 3 -Aging Manageme*Review ResultsTable 3.3.2-24Suppression Pool Cleanup SystemSummary of Aging Management Evaluation Table 3.3.2-24 Suppression Pool Cleanup SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VII.I.AP-124 3.3.1-15 ABoltingPiping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VII.D.A-80 3.3.1-78 Acomponents, 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 BStainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (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 BPump 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 BSelective 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 AUncontrolled (External)
Monitoring of Mechanical
'I_ I _ Components (B.2.1.24)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.3-236 Section 3 -Aging Management Review ResultsTable 3.3.2-24 Suppression Pool Cleanup System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 BLaSalle CountYdlion, Units 1 and 2License Rene V P licationO Page 3.3-237 0 0 Section 3 -Aging ManagemeReview ResultsTable 3.3.2-24 Suppression Pool Cleanup System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 3.3-238License Renewal Application Section 3 -Aging Management Review ResultsTable 3.3.2-25Traversing Incore Probe SystemSummary of Aging Management Evaluation Table 3.3.2-25 Traversing Incore Probe SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Stainless Steel Air- Indoor None None VII.J.AP-17 3.3.1-120 Acomponents, and Uncontrolled (External) piping elements Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 BMonitoring (B.2.1.15)
Valve Body Pressure Boundary Stainless Steel Air -Indoor None None VII.J.AP-17 3.3.1-120 AUncontrolled (External)
Condensation (Internal)
Loss of Material Compressed Air VII.D.AP-81 3.3.1-56 BMonitoring (B.2.1.15)
LaSalle Countyd~on, Units 1 and 2License Rene1W lication0 Page 3.3-239 Section 3 -Aging ManagemOReview ResultsTable 3.3.2-25 Traversing Incore Probe System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 2License Renewal Application Page 3.3-240 This Page Intentionally Left Blank
0 Section 3 -Aging Management Review Results3.4 AGING MANAGEMENT OF STEAM AND POWER CONVERSION SYSTEM3.
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 toaging management review. The systems, or portions of systems, which are addressed inthis 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 RESULTSThe following tables summarize the results of the aging management review for Steamand 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 AgingManagement Programs3.4.2.1.1 Condensate SystemMaterials 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 SteelLaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-1 Section 3 -Aging Management Review ResultsEnvironments The Condensate System components are exposed to the following environments:
- Air -Indoor Uncontrolled
" Air -Outdoor* Concrete" Condensation
- Soil" Treated WaterAging Effects Requiring Management The following aging effects associated with the Condensate System components requiremanagement:
- Cracking* Loss of Material* Loss of PreloadAging Management ProgramsThe following aging management programs manage the aging effects for theCondensate 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 SystemMaterials The materials of construction for the Condenser and Air Removal System components are:* Carbon Steel" Carbon and Low Alloy Steel Bolting* Stainless SteelLaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-2 Section 3 -Aging Management Review ResultsEnvironments The Condenser and Air Removal System components are exposed to the following environments:
" Air -Indoor Uncontrolled
- Treated WaterAging Effects Requiring Management The following aging effects associated with the Condenser and Air Removal Systemcomponents require management:
" Cumulative Fatigue Damage* Loss of Material* Loss of Preload" Wall ThinningAging Management ProgramsThe 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 SystemMaterials The materials of construction for the Feedwater System components are:* Carbon Steel* Carbon and Low Alloy Steel Bolting" Stainless SteelEnvironments The Feedwater System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Treated Water* Treated Water > 140 FLaSalle County Station, Units 1 and 2 Page 3.4-3License Renewal Application Section 3 -Aging Management Review ResultsAging Effects Requiring Management The following aging effects associated with the Feedwater System components requiremanagement:
- Cracking" Cumulative Fatigue Damage" Loss of Material* Loss of Preload* Wall ThinningAging Management ProgramsThe 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 SystemMaterials The materials of construction for the Main Steam System components are:" Carbon Steel" Carbon and Low Alloy Steel Bolting* Stainless SteelEnvironments The Main Steam System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Condensation
- Steam* Treated Water" Treated Water > 140 FLaSalle County Station, Units 1 and 2 Page 3.4-4License Renewal Application Section 3 -Aging Management Review ResultsAging Effects Requiring Management The following aging effects associated with the Main Steam System components requiremanagement:
- Cracking* Cumulative Fatigue Damage* Loss of Material" Loss of Preload* Wall ThinningAging Management ProgramsThe following aging management programs manage the aging effects for the MainSteam 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 SystemMaterials The materials of construction for the Main Turbine and Auxiliaries System components are:* Carbon SteelEnvironments The Main Turbine and Auxiliaries System components are exposed to the following environments:
- Air -Indoor Uncontrolled
- Treated WaterAging Effects Requiring Management The following aging effects associated with the Main Turbine and Auxiliaries Systemcomponents require management:
- Loss of MaterialLaSalle County Station, Units 1 and 2 Page 3.4-5License Renewal Application Section 3 -Aging Management Review Results* Wall ThinningAging Management ProgramsThe following aging management programs manage the aging effects for the MainTurbine 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 ReportNUREG-1 801 provides the basis for identifying those programs that warrant furtherevaluation by the reviewer in the license renewal application.
For the Steam and PowerConversion System, those programs are addressed in the following subsections.
3.4.2.2.1 Cumulative Fatigue DamageFatigue is a time-limited aging analysis (TLAA) as defined in 10 CFR 54.3. TLAAs arerequired to be evaluated in accordance with 10 CFR 54.21(c).
The evaluation of metalfatigue as a TLAA for the Condenser and Air Removal System, Feedwater System, MainSteam System, and Reactor Coolant Pressure Boundary System is discussed in Section4.3.3.4.2.2.2 Cracking due to Stress Corrosion Cracking (SCC)Cracking due to stress corrosion cracking could occur for stainless steel piping, pipingcomponents, piping elements, and tanks exposed to outdoor air. The possibility ofcracking 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 inenvironments containing sufficient halides (primarily chlorides) and in whichcondensation or deliquescence is possible.
Condensation or deliquescence shouldgenerally be assumed to be possible.
Applicable outdoor air environments (andassociated indoor air environments)
- include, but are not limited to, those withinapproximately 5 miles of a saltwater coastline, those within 1/2 mile of a highway whichis treated with salt in the wintertime, those areas in which the soil contains more thantrace chlorides, those plants having cooling towers where the water is treated withchlorine or chlorine compounds, and those areas subject to chloride contamination fromother 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 managethe aging effect. The applicant may demonstrate that this item is not applicable bydescribing the outdoor air environment present at the plant and demonstrating thatexternal chloride stress corrosion cracking is not expected.
The GALL Reportrecommends 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 3.4-6License Renewal Application Section 3 -Aging Management Review Resultsapplicable to the plant and ASME Code Section X1 requirements applicable to thecomponents.
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 steelpiping, 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 throughperiodic 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 foracceptability of continued service.
Deficiencies will be documented in accordance withthe 10 CFR Part 50, Appendix B Corrective Action Program.
The External SurfacesMonitoring 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 steelpiping, piping components, piping elements, and tanks exposed to outdoor air. Thepossibility of pitting and crevice corrosion also extends to components exposed to airwhich 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 notlimited to, those within approximately 5 miles of a saltwater coastline, those within 1/2mile of a highway which is treated with salt in the wintertime, those areas in which thesoil contains more than trace chlorides, those plants having cooling towers where thewater is treated with chlorine or chlorine compounds, and those areas subject to chloridecontamination from other agricultural or industrial sources.
This item is applicable for theenvironments described above.GALL AMP X1. M36, "External Surfaces Monitoring,"
is an acceptable method to managethe aging effect. The applicant may demonstrate that this item is not applicable bydescribing the outdoor air environment present at the plant and demonstrating thatexternal pitting or crevice corrosion is not expected.
The GALL Report recommends further evaluation to determine whether an adequate aging management program isused to manage this aging effect based on the environmental conditions applicable to theplant and ASME Code Section X1 requirements Quality Assurance for AgingManagement 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, pipingcomponents, and piping elements exposed to an outdoor air environment in theCondensate System. The External Surfaces Monitoring of Mechanical Components (B.2.1.24) program provides for management of aging effects through periodic visualinspection 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 forLaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-7 Section 3 -Aging Management Review Resultsacceptability of continued service.
Deficiencies will be documented in accordance with10 CFR Part 50, Appendix B corrective Action Program.
The External surfacesMonitoring 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 andAppendix 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 therecommendations in the GALL Report. During the search of plant-specific OE conducted during the LRA development, recurring internal corrosion can be identified by the numberof 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 revealsrepetitive 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 ormore sequential or nonsequential cycles for a 5-year OE search) of aging effects with thesame aging mechanism in which the aging effect resulted in the component either notmeeting 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, beevaluated 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 onsusceptibility to aging effect and consequences of failure, a greater frequency ofinspections),
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 todetect the recurring aging effect before affecting the ability of a component to perform itsintended
- 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 whereincreased inspections would be implemented (e.g., the extent of degradation at individual corrosion sites, the rate of degradation change),
(d) how inspections of components thatare not easily accessed (i.e., buried, underground) will be conducted, and (e) how leaksin any involved buried or underground components will be identified.
Each plant-specific operating experience example should be evaluated to determine ifthe chosen AMP should be augmented even if the thresholds for significance of agingeffect 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 360LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-8 Section 3 -Aging Management Review Resultsdegree 30 percent wall loss occurred at copper alloy to steel joints. Neither thesignificance of the aging effect nor the frequency of occurrence of aging effect threshold has been exceeded.
Nevertheless, the operating experience should be evaluated todetermine 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 providereasonable assurance that the CLB intended functions of the component will be metthroughout the period of extended operation.
- Likewise, the GALL Report AMR itemsassociated with the new FE items only cite raw water and waste water environments because OE indicates that these are the predominant environments associated withrecurring internal corrosion;
- however, if the search of plant-specific OE reveals recurring internal corrosion in other water environments (e.g., treated water), the aging effectshould be addressed in a similar manner.LR-ISG-2012-02 has been issued which addresses instances of recurring internalcorrosion identified during review of plant-specific operating experience.
The operating experience for LSCS has been reviewed and instances of internal corrosion in the Steamand Power Conversion System have not been identified with a frequency that isconsistent with the thresholds discussed in LR-ISG-2012-02.
3.4.2.3Time-Limited Aging AnalysisThe time-limited aging analyses identified below are associated with the Steam andPower 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 StressAnalyses* Section 4.3.5, High-Energy Line Break (HELB) Analysis Based on Fatigue" Section 4.3.6, Main Steam Relief Valve Discharge Piping Fatigue AnalysesLaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-9 Section 3 -Aging Management Review Results3.
4.3 CONCLUSION
The Steam and Power Conversion System piping, fittings, and components that aresubject to aging management review have been identified in accordance with therequirements of 10 CFR 54.4. The aging management programs selected to manageaging effects for the Steam and Power Conversion System components are identified inthe summaries in Section 3.4.2.1 above.A description of these aging management programs is provided in Appendix B, alongwith the demonstration that the identified aging effects will be managed for the period ofextended operation.
Therefore, based on the conclusions provided in Appendix B, the effects of agingassociated with the Steam and Power Conversion System components will beadequately managed so that there is reasonable assurance that the intended functions are maintained consistent with the current licensing basis during the period of extendedoperation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-10 O O Section 3 -Aging Managemeneview ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 iscomponents, and piping damage aging analysis (TLAA) to documented in Subsection 3.4.2.2.1.
elements exposed to due to fatigue be evaluated for theSteam or Treated water period of extendedoperation.
See the SRP,Section 4.3 "MetalFatigue,"
for acceptable methods for meeting therequirements of 10 CFR54.21 (c)(1).3.4.1-2 Stainless steel Piping, Cracking Chapter XI.M36, Yes, environmental Consistent with NUREG-1801.
Thepiping 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 beexposed to Air -outdoor Components" used to manage cracking of the stainless steel piping, piping components, and pipingelements exposed to air -outdoor in theCondensate 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.
Thepiping 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 beexposed to Air -outdoor Components" used to manage loss of material of thestainless 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 OnlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-11 Section 3 -Aging Management Review ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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) programelements exposed to accelerated corrosion will be used to manage wall thinning of theSteam, Treated water carbon steel piping, piping components, and piping elements, and turbine casingsexposed to steam and treated water in theCondenser 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 boltingexposed to soil in the Steam and PowerConversion 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 closureto Air with steam or water stress corrosion th e xpose to ai r with steam or eleakae crakingbolting exposed to air with steam or waterleakage cracking leakage in the Steam and PowerConversion System.3.4.1-8 Steel; stainless steel Loss of material Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The BoltingBolting, Closure bolting due to general (steel Integrity" Integrity (B.2.1.11) program will be used toexposed 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 theCondensate System, Condenser and AirRemoval System, Feedwater System, andMain Steam System.LaSalle County Station, Units 1 and 2License Renewal Application 0Page 3.4-12 Section 3 -Aging Managemen:eview ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 toair with steam or water leakage in theSteam and Power Conversion System.3.4.1-10 Copper alloy, Nickel Loss of preload Chapter XI.M18, "Bolting No Consistent with NUREG-1801.
The Boltingalloy, Steel; stainless due to thermal Integrity" Integrity (B.2.1.11) program will be used tosteel, Steel; stainless
- effects, gasket creep, manage loss of preload of the carbon andsteel Bolting, Closure and self-loosening low alloy steel bolting exposed to air -bolting exposed to Any indoor uncontrolled and air -outdoor in theenvironment, Air -Condensate System, Condenser and Airoutdoor (External),
Air- Removal System, Feedwater System, andindoor, uncontrolled Main Steam System.(External) 3.4.1-11 Stainless steel Piping, Cracking Chapter XI.M2, 'Water No Consistent with NUREG-1801 withpiping 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 managecomponents exposed to cracking of the stainless steel piping, pipingSteam, Treated water components, and piping elements exposed>601C (>140°F) to steam and treated water > 140 F in theFeedwater System, Main Steam System,and Reactor Coolant Pressure BoundarySystem.An exception applies to the NUREG-1801 recommendations for the Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-13 Section 3 -Aging Management Review ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 withTanks 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 manageloss of material of the carbon steel tanksexposed 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 Only3.4.1-14 Steel Piping, piping Loss of material Chapter XI.M2, 'Water No Consistent with NUREG-1801 withcomponents, 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 manageexposed to Steam, loss of material of the carbon steel piping,Treated water piping components, and piping elementsand turbine casings exposed to steam andtreated water in the Condensate System,Condenser and Air Removal System,Feedwater System, Main Steam System,Main Turbine and Auxiliaries System,Reactor Coolant Pressure BoundarySystem, and Reactor Core Isolation Cooling System.An exception applies to the NUREG-1 801recommendations for the Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application 0Page 3.4-14 0 0 Section 3-Aging Managementiew ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemComponent Aging Aging Management Further Discussion Effect/Mechanism Programs Evaluation Recommended Steel Heat exchanger components exposed toTreated waterLoss of materialdue to general,pitting,
- crevice, andgalvanic corrosion Chapter XI.M2, "WaterChemistry,"
andChapter XI.M32, "One-Time Inspection" NoConsistent with NUREG-1801 withexceptions.
The One-Time Inspection (B.2.1.21) program and Water Chemistry (B.2.1.2) program will be used to manageloss of material of the carbon steel heatexchanger components and piping, pipingcomponents, and piping elements exposedto treated water in the Condenser and AirRemoval System and Demineralized WaterMakeup System.An exception applies to the NUREG-1 801recommendations for the Water Chemistry (B.2.1.2) program implementation.
+ i I I3.4.1-16Copper alloy, Stainless steel, Nickel alloy,Aluminum Piping, pipingcomponents, and pipingelements, Heatexchanger components and tubes, PWR heatexchanger components exposed to Treatedwater, SteamLoss of materialdue to pitting andcrevice corrosion Chapter XI.M2, 'WaterChemistry,"
andChapter XI.M32, "One-Time Inspection" NoConsistent with NUREG-1801 withexceptions.
The One-Time Inspection (B.2.1.21) program and Water Chemistry (B.2.1.2) program will be used to manageloss of material of the aluminum alloy,copper alloy, and stainless steel heatexchanger components and piping, pipingcomponents, and piping elements exposedto steam and treated water in theCondensate System, Condenser and AirRemoval System, Demineralized WaterMakeup System, Feedwater System, LowPressure Core Spray System, Main SteamSystem, Reactor Coolant PressureBoundary System , and Reactor CoreIsolation Cooling System.An exception applies to the NUREG-1 801recommendations for the Water Chemistry (B.2.1.2) program implementation.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-15 Section 3 -Aging Management Review ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem Component Aging Aging Management Further Discussion Number Effect/Mechanism Programs Evaluation Recommended 3.4.1-17 PWR Only3.4.1-18 Copper alloy, Stainless Reduction of heat Chapter XI.M2, "Water No Consistent with NUREG-1801 withsteel 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 managereduction of heat transfer of the copperalloy heat exchanger tubes exposed totreated water in the Reactor Core Isolation Cooling System.An exception applies to the NUREG-1 801recommendations 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 heatcomponents exposed to pitting,
- crevice, System" Th er compo ness se d t o rawRaw water galvanic, and exchanger components exposed to rawmicrobiologically-water in the Steam and Power Conversion influenced corrosion; System.fouling that leads tocorrosion 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 steelcomponents, and piping and microbiologically-System" There piping copp e nts, a in gelements exposed to influenced corrosion piping, piping components, and pipingRaw water elements exposed to raw water in theSteam and Power Conversion System.3.4.1-21 PWR OnlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-16 0 Section 3 -Aging Managerne view ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 Waterexchanger tubes, Heat due to fouling System" There are no stainless steel, copper alloy,exchanger components steel heat exchanger tubes, and heatexposed to Raw water exchanger components exposed to rawwater 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 Waterpiping elements exposed corrosion cracking Systems" There are no stainless steel piping, pipingto Closed-cycle cooling components, and piping elements exposedwater >60°C (>140cF) to closed-cycle cooling water >600C(>1400F) in the Steam and PowerConversion 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 lewater galvanic corrosion components exposed to closed-cycle cooling water in the Steam and PowerConversion 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 lewater galvanic corrosion components exposed to closed-cycle cooling water in the Steam and PowerConversion System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-17 Section 3 -Aging Management Review ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 WaterPiping, piping crevice corrosion Systems" There are no stainless steel heatcomponents, and piping exchanger components, piping, pipingelements exposed to components, and piping elements exposedClosed-cycle cooling to closed-cycle cooling water in the Steamwater 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, pipingpiping elements exposed and galvanic Systems"to Closed-cycle cooling corrosion components, and piping elements exposedwater to closed-cycle cooling water in the Steamand 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, copperexchanger components due to fouling Systems"and tubes, Heat alloy heat exchanger components andexchanger tubes tubes, heat exchanger tubes exposed toexposed to Closed-cycle closed-cycle cooling water in the Steamcooling 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 Metallicpitting, and crevice Tanks" There are no steel tanks exposed to air-corrosion outdoor (external) in the Steam and PowerConversion System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-18 Section 3 -Aging Management wl e ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 Metallicthe scope of Chapter only) pitting, and Tanks" There ate no steel or stainless steel tanksXI.M29, "Aboveground crevice corrosion; (within the scope of chapter X.M29,Metallic Tanks") exposed cracking due to stress "Aboveground Metallic Tanks") exposed toto Soil or Concrete, or the corrosion cracking soil or concrete, or the following externalfollowing external (stainless steel and environments of air-outdoor, air-indoor environments air-outdoor, aluminum only) uncontrolled, moist air, condensation in theair-indoor uncontrolled, Steam and Power Conversion System.moist air, condensation Aluminum tanks (within the scope ofchapter XI.M29, "Aboveground MetallicTanks) are evaluated in 3.4.1-31.
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-19 Section 3 -Aging Management Review ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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.
TheAluminum 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 ofXI.M29, "Aboveground due to stress material of the aluminum alloy tanks (cycledMetallic Tanks") exposed corrosion cracking condensate storage tank) exposed to air-to Soil or Concrete, or the outdoor, condensation,
- concrete, and soil infollowing external the Condensate System. The aging effectenvironments air-outdoor, of cracking due to stress corrosion crackingair-indoor uncontrolled, does not apply. Cracking in aluminum alloymoist air, condensation of these environments occurs when thealuminum alloy chemical composition includes greater than 12% zinc or greaterthan 6% magnesium (ref. EPRI Report1010639, Non-Class 1 Mechanical Implementation Guideline and Mechanical Tools, Revision 4 dated January 2006).The cycled condensate storage tank isconstructed of ASTM B209 alloy 5454plates and ASTM B308 alloy 6061-T6structural members.
Both these alloyscontain less than 12% zinc and less than6% magnesium.
See 3.4.2.2.2 for furtherevaluation.
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, pipingpiping elements exposed leaching components, and piping elements exposedto Soil to soil in the Steam and Power Conversion System.LaSalle County Station, Units 1 and 2License Renewal Application 0Page 3.4-20 Section 3 -Aging Management iew ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 alloyAl) Piping, piping leachingThrarnogacstinoropealy components, and piping piping, piping components or pipingelements exposed to elements exposed to treated water or rawTreated water, Raw water in the Steam and Power Conversion water, Closed-cycle System.cooling water3.4.1-34 Steel External surfaces Loss of material Chapter XI.M36, No Consistent with NUREG-1801.
Theexposed 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 beAir -outdoor (External),
Components" used to manage loss of material of theCondensation (External) carbon steel heat exchanger components, piping, piping components, and pipingelements, and tanks exposed to air -indooruncontrolled and air -outdoor in theCondensate System, Condenser and AirRemoval System, Feedwater System, MainSteam System, and Main Turbine andAuxiliaries System.3.4.1-35 Aluminum Piping, piping Loss of material Chapter XI.M36, No Consistent with NUREG-1801.
Thecomponents, 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 beoutdoor Components" used to manage loss of material of thealuminum alloy piping, piping components, and piping elements exposed to air -outdoor in the Condensate System.3.4.1-36 PWR OnlyLaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-21 Section 3 -Aging Management Review ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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.
Thecomponents, and piping due to general, "Inspection of Internal Inspection of Internal Surfaces inelements exposed to pitting, and crevice Surfaces in Miscellaneous Piping and DuctingCondensation (Internal) corrosion Miscellaneous Piping and Components (B.2.1.25) program will beDucting Components" used to manage loss of material of thecarbon steel piping, piping components, and piping elements and tanks exposed tocondensation in the Condensate Systemand Main Steam System.3.4.1-38 PWR Only3.4.1-39 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, pipingpiping elements exposed crevice corrosion Surfaces in componeno and piping p osedto Condensation Miscellaneous Piping and components, and piping elements exposed(Internal)
Ducting Components" to condensation (internal) in the Steam andPower 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, pipingelements exposed to pitting, and crevice and components, and piping elements exposedLubricating oil corrosion Chapter XI.M32, "One- to lubricating oil in Steam and PowerTime Inspection" Conversion System.3.4.1-41 PWR Only3.4.1-42 PWR OnlyLaSalle County Station, Units 1 and 2License Renewal Application 0Page 3.4-22 0 0 Section 3 -Aging Managemenl ew ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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, pipingpiping elements exposed crevice corrosion and There and piping posedto Lubricating oil Chapter XI.M32, 'One- components, and piping elements exposedTime Inspection" to lubricating oil in the Steam and PowerConversion 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, pipingpiping elements, Heat and microbiologically-and The no and piping pipingexchanger components influenced corrosion Chapter XI.M32, "One-exchanger components exposed toexposed to Lubricating oil Time Inspection" lubricating oil in the Steam and PowerConversion System.3.4.1-45 PWR Only3.4.1-46 PWR Only3.4.1-47 Steel (with coating or Loss of material due Chapter XI.M41, "Buried No Consistent with NUREG-1801.
The Buriedwrapping),
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 ofpiping components, and and microbiologically-material of the carbon steel piping, pipingpiping elements; tanks influenced corrosion components, and piping elements exposedexposed to Soil or to soil in the Condensate System.Concrete3.4.1-48 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 alloysoil crevice corrosion and Tanks" bolting exposed to soil in the Steam andPower Conversion System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-23 Section 3 -Aging Management Review ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 alloycomponents, and piping corrosion and Tanks" pipi n o pip ing e ns , and or pn gelements exposed to soil piping, piping components, and pipingor concrete elements exposed to soil or concrete in theSteam 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 inpitting 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, pipingelements components, and piping elements in theSteam 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, pipingelements exposed to concrete are consistent components, and piping elements exposedConcrete 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 airentrainment) as cited inNUREG-1557, and2) plant OE indicates nodegradation of theconcreteLaSalle County Station, Units 1 and 2License Renewal Application 0Page 3.4-24 Section 3 -Aging Management~eview ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 AMPelements exposed to There are no aluminum piping, pipingGas, Air- indoor, components, and piping elements exposeduncontrolled to gas, air-indoor, uncontrolled onteroll/xed
) (internal/external) in the Steam and Power(internal/External)
Conversion System.3.4.1-53 PWR Only3.4.1-54 Copper alloy Piping, None None NA -No AEM or Consistent with NUREG-1 801.piping components, and AMPpiping elements exposedto 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 AMPoil, Air -outdoor,Condensation (Internal/External),
Rawwater, Treated water, Airwith borated waterleakage, 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 AMPelements exposed to Air There are no nickel alloy piping, pipingeeindoor, uncontrolled components, and piping elements exposed(External) to air-indoor, uncontrolled (external) in theSteam and Power Conversion System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-25 Section 3 -Aging Management Review ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 AMPpiping elements exposed There are no nickel alloy or PVC piping,to Air with borated water piping components, and piping elementsleakage, Air -indoor, exposed to air-indoor, uncontrolled oruncontrolled, condensation (internal) in the Steam andCondensation (Internal)
Power Conversion System.3.4.1-58 Stainless steel Piping, None None NA -No AEM or Consistent with NUREG-1801.
piping components, and AMPpiping elements exposedto 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 AMPelements 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 inthe 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) programpiping elements exposed will be used to manage wall thinning of theto treated water carbon steel heat exchanger components exposed to treated water in the Condensate and Air Removal System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-26 0Section 3 -Aging Managementeiew ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 isexposed to raw water or corrosion to be evaluated towaste water address recurring internalcorrosion 3.4.1-62 Steel, stainless steel or Loss of material due Chapter XL.M29, No Consistent with NUREG-1801.
Thealuminum 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 ofXI.M29, "Aboveground crevice corrosion material of the aluminum alloy tanksMetallic Tanks") exposed exposed to treated water in the Condensate to treated water System.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-27 Section 3 -Aging Management Review ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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.
Thesteel, 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 bealloy (> 15% Zn) piping, or crevice corrosion, Components" or Chapter used to manage loss of material of thepiping 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 pipingcondensation, air-outdoor cracking (aluminum, only) elements and cracking of the stainless steelstainless steel and piping, piping components, and pipingcopper alloy (>15% elements exposed to air-outdoor in theZn) only) Condensate System. The aging effect ofcracking due to stress corrosion cracking inaluminum does not apply. Cracking inaluminum alloy of these environments occurs when the aluminum alloy chemicalcomposition includes greater than 12% zincor greater than 6% magnesium (ref. EPRIReport 1010639, Non-Class 1 Mechanical Implementation Guideline and Mechanical Tools, Revision 4 dated January 2006).The cycled condensate storage tank isconstructed of ASTM B209 alloy 5454plates and ASTM B308 alloy 6061-T6structural members.
Both these alloyscontain less than 12% zinc and less than6% magnesium.
3.4.1-64 Jacketed calcium silicate Reduced thermal Chapter XI.M36, No Consistent with NUREG-1801.
Theor 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 beor air-outdoor intrusion Components" used to manage reduced thermal insulation environment resistance of the jacketed calcium silicateor fiberglass insulation exposed to air-indoor uncontrolled and air-outdoor in theStructural Commodity Group.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-28 0 0 Section 3 -Aging Managemerteview ResultsTable 3.4.1 Summary of Aging Management Evaluations for the Steam and Power Conversion SystemItem 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 beor air-outdoor intrusion Components" used to manage reduced thermal insulation environment resistance of the jacketed foamed plasticinsulation and stainless steel insulation andinsulation jacketing exposed to air-indoor uncontrolled and air-outdoor in theStructural Commodity Group.LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-29 Section 3 -Aging Management Review ResultsTable 3.4.2-1Condensate SystemSummary of Aging Management Evaluation Table 3.4.2-1 Condensate SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VIII.H.SP-83 3.4.1-10 ABoltingAir -Outdoor (External)
Loss of Material Bolting Integrity (B.2.1.11)
VIII.H.SP-82 3.4.1-8 ALoss of Preload Bolting Integrity (B.2.1.11)
VIII.H.SP-1 51 3.4.1-10 APiping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 Acomponents, 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 BStainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 AUncontrolled (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 BPressure Boundary Aluminum Alloy Air -Outdoor (External)
Loss of Material External Surfaces VIII.H.SP-147 3.4.1-35 AMonitoring of Mechanical VIII.E.S-402 3.4.1-63 AComponents (B.2.1.24)
I.S4416_ None None VIII.E.S-402 3.4.1-63 I, 3LaSalle County,"'on, Units 1 and 2License Rene W lication.Page 3.4-30 Section 3 -Aging Management Review ResultsTable 3.4.2-1 Condensate System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, piping Pressure Boundary Aluminum Alloy Condensation Loss of Material Inspection of Internal VII.F1.AP-142 3.3.1-92 A, 1components, and (External)
Surfaces in Miscellaneous piping elements Piping and DuctingComponents (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, 2Treated 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 BCarbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 AUncontrolled (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 AMonitoring of Mechanical Vlll.E.5A02 3.4.1-63 AComponents (B.2.1.24)
Soil (External)
Loss of Material Buried and Underground VIII.E.SP-145 3.4.1-47 APiping (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 BStainless Steel Air -Indoor None None VIII.I.SP-12 3.4.1-58 AUncontrolled (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 BTanks (Cycled Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 ACondensate Gland Uncontrolled (External)
Monitoring of Mechanical Seal Head Tank) Components (B.2.1.24)
LaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-31 Section 3 -Aging Management Review ResultsTable 3.4.2-1 Condensate System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Tanks (Cycled Leakage Boundary Carbon Steel Condensation (Internal)
Loss of Material Inspection of Internal VIII.G.SP-60 3.4.1-37 CCondensate Gland Surfaces in Miscellaneous Seal Head Tank) Piping and DuctingComponents (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 BTanks (Cycled Pressure Boundary Aluminum Alloy Air- Outdoor (External)
Loss of Material Aboveground Metallic VIII.E.SP-139 3.4.1-31 ACondensate Tanks (B.2.1.18)
Storage Tank) None None VIII.E.SP-139 3.4.1-31 I, 3Concrete (External)
Loss of Material Aboveground Metallic VIII.E.SP-139 3.4.1-31 ATanks (B.2.1.18)
None None VIII.E.SP-139 3.4.1-31 I, 3Condensation (Internal)
Loss of Material Aboveground Metallic VIII.E.SP-139 3.4.1-31 ATanks (B.2.1.18)
None None VIII.E.SP-139 3.4.1-31 I, 3Soil (External)
Loss of Material Aboveground Metallic VIII.E.SP-139 3.4.1-31 ATanks (B.2.1.18)
None None VIII.E.SP-139 3.4.1-31 I, 3Treated Water (Internal)
Loss of Material Aboveground Metallic VIII.E.S-405 3.4.1-62 ATanks (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 AUncontrolled (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 BCopper Alloy with Air -Indoor None None VIII.I.SP-6 3.4.1-54 Aless than 15% Uncontrolled (External)
ZincLaSalle Countyfton, Units 1 and 2License Rene W lication0 Page 3.4-32 0eSection 3 -Aging Management Review ResultsTable 3.4.2-1 Condensate System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve Body Leakage Boundary Copper Alloy with Treated Water (Internal)
Loss of Material One-Time Inspection VIII.A.SP-101 3.4.1-16 Aless than 15% (B.2.1.21)
Zinc Water Chemistry (B.2.1.2)
VIII.A.SP-101 3.4.1-16 BPressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 AUncontrolled (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 AMonitoring of Mechanical VIII.E.S-402 3.4.1-63 AComponents (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 BStainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 AUncontrolled (External) iAir -Outdoor (External)
Cracking External Surfaces VIII.E.SP-1 18 3.4.1-2 AMonitoring of Mechanical VIII.E.S-402 3.4.1-63 AComponents (B.2.1.24)
VIE-2.13Loss of Material External Surfaces VIII.E.SP-127 3.4.1-3 AMonitoring of Mechanical VIII.E.S-402 3.4.1-63 AComponents (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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-33 Section 3 -Aging Management Review ResultsTable 3.4.2-1 Condensate System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 pipingwill 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 MetallicTanks (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 thealuminum alloy chemical composition includes greater than 12% zinc or greater than 6% magnesium (ref. EPRI Report 1010639, Non-Class 1Mechanical Implementation Guideline and Mechanical Tools, Revision 4 dated January 2006). The cycled condensate storage tank is constructed ofASTM B209 alloy 5454 plates and ASTM B308 alloy 6061-T6 structural members and piping. Both these alloys contain less than 12% zinc and lessthan 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 gapsin insulation, condensation can occur underneath the insulation on components when the operating temperature of the component is below the dewpoint of the air on the external surfaces of the insulation.
LaSalle County,@Kon, Units 1 and 2 _ Page 3.4-34License Rene~ Wplication Section 3 -Aging Management Review ResultsTable 3.4.2-2Condenser and Air Removal SystemSummary of Aging Management Evaluation Table 3.4.2-2 Condenser and Air Removal SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table 1 Item Notespe Function Requiring Programs Itemt 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VIII.H.SP-83 3.4.1-10 ABoltingHeat 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 BWall Thinning Flow-Accelerated VIII.D2.S-408 3.4.1-60 CCorrosion (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 Acomponents, 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, 1DamageLoss 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 BWall Thinning Flow-Accelerated VIII.E.S-16 3.4.1-5 ACorrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 AUncontrolled (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 2License Renewal Application Page 3.4-35 Section 3 -Aging Management Review ResultsTable 3.4.2-2 Condenser and Air Removal System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 Bcomponents, andpiping elementsValve Body Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 AUncontrolled (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 BWall Thinning Flow-Accelerated VIII.E.S-16 3.4.1-5 ACorrosion (B.2.1.10)
-1LaSalle County~on, Units 1 and 2License Rene~Vlication
.Page 3.4-36 Section 3 -Aging Management Review ResultsTable 3.4.2-2 Condenser and Air Removal System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 2License Renewal Application Page 3.4-37 Section 3 -Aging Management Review ResultsTable 3.4.2-3Feedwater SystemSummary of Aging Management Evaluation Table 3.4.2-3 Feedwater SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VIII.H.SP-83 3.4.1-10 ABoltingPiping, piping Leakage Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 Acomponents, 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, 1DamageLoss 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 BWall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 ACorrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 AUncontrolled (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 BTreated 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 BCumulative Fatigue TLAA VII.E3.A-62 3.3.1-2 A, 1DamageLoss of Material One-Time Inspection VIII.D2.SP-87 3.4.1-16 AF_ (B.2.1.21)
LaSalle CountA tion, Units 1 and 2License ReneV plication
.Page 3.4-38 Section 3 -Aging Management Review ResultsTable 3.4.2-3 Feedwater System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 Bcomponents, and (Internal) piping elements Pressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 AUncontrolled (External)
Monitoring of Mechanical Components (B.2.1.24)
Treated Water (Internal)
Cumulative Fatigue TLAA VIII.D2.S-11 3.4.1-1 A, 1DamageLoss 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 BWall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 ACorrosion (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 AUncontrolled (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 BWall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 ACorrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 AUncontrolled (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 BPressure Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 AUncontrolled (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 BLaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-39 Section 3 -Aging Management Review ResultsTable 3.4.2-3 Feedwater System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Valve Body Pressure Boundary Carbon Steel Treated Water (Internal)
Wall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 AI I ~~Corrosion (B.2.1.10)
ILaSalle Country~ion, Units 1 and 2License ReneWv plication 0 Page 3.4-40 Section 3 -Aging Management Review ResultsTable 3.4.2-3 Feedwater System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 2License Renewal Application Page 3.4-41 Section 3 -Aging Management Review ResultsTable 3.4.2-4Main Steam SystemSummary of Aging Management Evaluation Table 3.4.2-4 Main Steam SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 AAlloy Steel Uncontrolled (External)
Loss of Preload Bolting Integrity (B.2.1.11)
VIII.H.SP-83 3.4.1-10 ABoltingPiping, piping Leakage Boundary Carbon Steel Air- Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 Acomponents, 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 BWall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 ACorrosion (B.2.1.10)
Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 AUncontrolled (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 ASurfaces in Miscellaneous Piping and DuctingComponents (B.2.1.25)
Steam (Internal)
Cumulative Fatigue TLAA VIII.B2.S-08 3.4.1-1 A, 1DamageLoss 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 BWall Thinning Flow-Accelerated VIII.B2.S-15 3.4.1-5 ACorrosion (B.2.1.10)
LaSalle Countvfion, Units 1 and 2License Rene1Plication O Page 3.4-42 Section 3 -Aging Management Review ResultsTable 3.4.2-4 Main Steam System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement Piping, pipingcomponents, andpiping elementsPressure BoundaryCarbon SteelTreated Water(External)
Cumulative FatigueDamageTLAAVIII.B2.S-08 3.4.1-1A, 1Loss of MaterialOne-Time Inspection (B.2.1.21)
VIII.B2.SP-73 3.4.1-14AWater Chemistry (B.2.1.2)
VIII.B2.SP-73 3.4.1-14BTreated Water (Internal)l Cumulative FatigueDamageTLAAVIII.B2.S-08 3.4.1-1A, ILoss 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 BWall ThinningFlow-Accelerated Corrosion (B.2.1.10)
VIII.D2.S-16 3.4.1-5AStainless SteelAir -IndoorUncontrolled (External)
NoneNoneVIII.I.SP-12 3.4.1-58ASteam (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 BLoss 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 BTreated 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 BTreated 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 BTreated Water > 140 F(Internal)
CrackingOne-Time Inspection (B.2.1.21)
VIII.C.SP-88 3.4.1-11AWater Chemistry (B.2.1.2)
VIII.C.SP-88 3.4.1-11B+ -. __________
_________
Loss of MaterialOne-Time Inspection (B.2.1.21)
VIII.C.SP-87 3.4.1-16ALaSalle County Station, Units 1 and 2License Renewal Application Page 3.4-43 Section 3 -Aging Management Review ResultsTable 3.4.2-4 Main Steam System (Continued)
Component Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 Bcomponents, and (Internal) piping elementsValve Body Pressure Boundary Carbon Steel Air -Indoor Loss of Material External Surfaces VIII.H.S-29 3.4.1-34 AUncontrolled (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 BWall Thinning Flow-Accelerated VIII.D2.S-16 3.4.1-5 ACorrosion (B.2.1.10)
Stainless Steel Air- Indoor None None VIII.I.SP-12 3.4.1-58 AUncontrolled (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 BLoss 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 BLaSalle CountKtion, Units 1 and 2License ReneW plication 0 Page 3.4-44 Section 3 -Aging Management Review ResultsTable 3.4.2-4 Main Steam System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 2License Renewal Application Page 3.4-45 Section 3 -Aging Management Review ResultsTable 3.4.2-5Main Turbine and Auxiliaries SystemSummary of Aging Management Evaluation Table 3.4.2-5 Main Turbine and Auxiliaries SystemComponent Intended Material Environment Aging Effect Aging Management NUREG-1801 Table I Item NotesType Function Requiring Programs ItemManagement 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 DWall Thinning Flow-Accelerated VIII.E.S-16 3.4.1-5 C____. _Corrosion (B.2.1.10)
LaSalle Countydilon, Units I and 2License Renevw lication.Page 3.4-46 Section 3 -Aging Management Review ResultsTable 3.4.2-5 Main Turbine and Auxiliaries System (Continued)
Notes Definition of NoteA 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 withNUREG-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 orNUREG-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 2License Renewal Application Page 3.4-47 This Page Intentionally Left Blank