ML100250654

Columbia Generating Station - License Renewal Application, Technical Information, Pages 3.4-1 to D-2

ML100250654
Person / Time
Site:	Columbia
Issue date:	01/19/2010
From:	Oxenford W S Energy Northwest
To:	Office of Nuclear Reactor Regulation
References
GO2-10-011
Download: ML100250654 (618)

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3.4 AGING

MANAGEMENT OF STEAM AND POWER CONVERSION SYSTEMS 3.4.1 Introduction Section 3.4 provides the results of the aging management reviews (AMRs) for those components identified in Section 2.3.4, Steam and Power Conversion Systems,. as subject to AMR. The systems or portions of systems are described in the indicated sections of the Application.

• Auxiliary Steam System (Section 2.3.4.1)* Condensate (Auxiliary)

System (Section 2.3.4.2)* Condensate (Nuclear) System (Section 2.3.4.3)* -Main Steam System (Section 2.3.4.4)* Main Steam Leakage Control System (Section 2.3.4.5)

• Miscellaneous Drain System (Section 2.3.4.6)* Reactor Feedwater System (Section 2.3.4.7)Table 3.4.1, Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801, provides the summary of the programs evaluated in NUREG-1801 that are applicable to component and commodity groups in this section. Text addressing summary items requiring further evaluation is provided in Section 3.4.2.2.

3.4.2 Results

The following tables summarize the results of the AMR for the Steam and Power Conversion Systems.Table 3.4.2-1 Aging Management Review Results -Auxiliary Steam SystemTable 3.4.2-2 Aging Management Review Results -Condensate (Auxiliary) SystemTable 3.4.2-3 Aging Management Review Results -Condensate (Nuclear) SystemTable 3.4.2-4 Aging Management Review Results -Main Steam System Table 3.4.2-5 Aging Management Review Results -Main Steam Leakage Control SystemTable 3.4.2-6 Aging Management Review Results -Miscellaneous Drain System Table 3.4.2-7 Aging Management Review Results -Reactor Feedwater SystemAgin MaageentReviw Rsuls Pge 34-1Janary201 Aging Management Review Results Page 3.4-1 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information

3.4 AGING

MANAGEMENT OF STEAM AND POWER CONVERSION SYSTEMS 3.4.1 Introduction Section 3.4 provides the results of the aging management reviews (AMRs) for those components identified in Section 2.3.4, Steam and Power Conversion Systems,. as subject to AMR. The systems or portions of systems are described in the indicated sections of the Application.

• Auxiliary Steam System (Section 2.3.4.1)
• Condensate (Auxiliary)

System (Section 2.3.4.2)

• Condensate (Nuclear)

System (Section 2.3.4.3) * ,Main Steam System (Section 2.3.4.4)

• Main Steam Leakage Control System (Section 2.3.4.5)
• Miscellaneous Drain System (Section 2.3.4.6)
• Reactor Feedwater System (Section 2.3.4.7) Table 3.4.1, Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801, provides the summary of the programs evaluated in NUREG-1801 that are applicable to component and commodity groups in this section. Text addressing summary items requiring further evaluation is provided in Section 3.4.2.2. 3.4.2 Results The following tables summarize the results of the AMR for the Steam and Power Conversion Systems. Table 3.4.2-1 . Aging Management Review Results -Auxiliary Steam System Table 3.4.2-2 Aging Management Review Results -Condensate (Auxiliary)

System Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear) System Table 3.4.2-4 Aging Management Review Results -Main Steam System Table 3.4.2-5 Aging Management Review Results -Main Steam Leakage Control System Table 3.4.2-6 Aging Management Review Results -Miscellaneous Drain System Table 3.4.2-7 Aging Management Review Results -Reactor Feedwater System Aging Management Review Results Page 3.4-1 January 2010 Columbia Generating Station License Renewal Application Technical Information 3.4.2.1 Materials, Environments, Aging Effects Requiring Management, and Aging Management Programs The materials from which specific components and commodities are fabricated, the environments to which they are exposed, the aging effects requiring management, and the aging management programs used to manage these aging effects are provided for each of the above systems in the following sections.3.4.2.1.1 Auxiliary Steam System Materials The materials of construction for subject mechanical components of the Auxiliary Steam System are: " Gray cast iron" Stainless steel , Steel Environments Subject mechanical components of the Auxiliary Steam System are.exposed to the following normal operating environments:

• Air-indoor uncontrolled
• Air-outdoor , Steam Aging Effects Requiring Management The following aging effects require management for the subject mechanical components of the Auxiliary Steam System: " Cracking* Loss of material" Loss of pre-load Aging Management Programs The following aging management programs manage the aging effects for subject mechanical components of the Auxiliary Steam System: " Bolting Integrity Program* BWR Water Chemistry Program Aging Management Review Results Page 3.4-2 January 2010 Columbia Generating Station License Renewal Application Technical Information 3.4.2.1 Materials, Environments, Aging Effects Requiring Management, and Aging Management Programs . The materials from which specific components and commodities are fabricated, the environments to which they are exposed, the aging effects requiring management, and the aging management programs used to manage these aging effects are provided for each of the above systems in the following sections.

3.4.2.1.1 Materials Auxiliary Steam Sys.tem The materials of construction for subject mechanical components of the Auxiliary Steam System are:

• Gray cast iron
• Stainless steel
• Steel Environments Subject mechanical components of the Auxiliary Steam System are. exposed to the
• following normal operating environments:
• Air-indoor
• Air-outdoor
• Steam Aging Effects Requiring Management The following aging effects require management for the subject mechanical components of the Auxiliary Steam System:
• Cracking
• Loss of material
• Loss of pre-load Aging Management Programs The following aging management programs manage the aging effects for subject mechanical components of the Auxiliary Steam System:
• Bolting Integrity Program
• BWR Water Chemistry Program Aging Management Review Results Page 3.4-2 January 2010
• Columbia Generating Station License Renewal Application Technical Information" Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program* Flow-Accelerated Corrosion (FAC) Program* Selective Leaching Inspection 3.4.2.1.2 Condensate (Auxiliary)

System Materials The materials of construction for subject mechanical components of the Condensate (Auxiliary) System are: " Gray cast iron* Steel Environments Subject mechanical components of the Condensate (Auxiliary) System are exposed to the following normal operating environments:

• Air-indoor uncontrolled
• Air-outdoor
• Treated water

> 60 OC (140 OF)Aging Effects Requiring Management The following aging effects require management for the subject mechanical components of the Condensate (Auxiliary) System:* Loss of material* Loss of pre-load Aging Management Programs The following aging management programs manage the aging effects for subject mechanical components of the Condensate (Auxiliary) System: (* Bolting Integrity Program* BWR Water Chemistry Program* Chemistry Program Effectiveness Inspection

• External Surfaces Monitoring Program Aging Management Review Results Page 3.4-3 January 2010* * *
• Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program
• Flow-Accelerated Corrosion (FAC) Program
• Selective Leaching Inspection 3.4.2.1.2 Materials Condensate (Auxiliary)

System Columbia Generating Station License Renewal Application Technical Information The materials of construction for subject mechanical components of the Condensate (Auxiliary) System are:

• Gray cast iron
• Steel Environments Subject mechanical components of the Condensate (Auxiliary)

System are exposed to the following normal operating environments:

• Air-indoor uncontrolled
• Air-outdoor
• Treated water> 60 °C (140 of) Aging Effects Requiring Management The following aging effects require management for the subject mechanical components
• of the Condensate (Auxiliary)

System: '

• Loss of material
• Loss of pre-load Aging Management Programs The following aging management programs manage the aging effects for subject mechanical components of the Condensate (Auxiliary)

System: I * . Bolting Integrity Program

• BWR Water Chemistry Program
• Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program Aging Management Review Results Page 3.4-3 January 2010 Columbia Generating Station License Renewal Application Technical Information 3.4.2.1.3 Condensate (Nuclear)

System Materials The materials of construction for the subject mechanical components of the Condensate (Nuclear) System are:* Cast austenitic stainless steel (CASS)" Stainless steel* Steel Environments The subject mechanical components of the Condensate (Nuclear) System are exposed to the following normal operating plant environments:

• Air-indoor uncontrolled" Air-outdoor
• Condensation
• Moist air* Soil* Treated water Aging Effects Requiring Management The following aging effects require management for the subject mechanical components of the Condensate (Nuclear)

System: " Cracking* Loss of material* Loss of pre-load Aging Management Programs The following aging management programs manage the aging effects for the subject mechanical components of the Condensate (Nuclear) System: " Aboveground Steel Tanks Inspection

• Bolting Integrity Program* Buried Piping and Tanks Inspection Program" BWR Water Chemistry Program Aging Management Review Results Page 3.4-4 January 2010 3.4.2.1.3 Materials Condensate (Nuclear)

System Columbia Generating Station License Renewal Application Technical Information The materials of construction for the subject mechanical components of the Condensate (Nuclear) System are: .

• Cast austenitic stainless steel (CASS)
• Stainless steel
• Steel Environments The subject mechanical components of the Condensate (Nuclear)

System are exposed to the following normal operating plant environments:

• Air-indoor uncontrolled
• Air-outdoor
• Condensation
• Moist air
• Soil
• Treated water Aging Effects, Requiring Management The following aging effects require management for the subject mechanical components of the Condensate (Nuclear)

System:

• Cracking
• Loss of material
• of pre-load Aging Management Programs The following aging management programs manage the aging effects for the subject mechanical components of the Condensate (Nuclear)

System:

• Aboveground Steel Tanks Inspection
• Bolting Integrity Program
• Buried Piping and Tanks Inspection Program
• BWR Water Chemistry Program Aging Management Review Results Page 3.4-4 January 2010 * *
• Columbia Generating StationLicense Renewal Application Technical Information
• ChemistryProgram Effectiveness Inspection 0 External Surfaces Monitoring Program 0 Flow-Accelerated Corrosion (FAC) Program* Supplemental Piping/Tank Inspection 3.4.2.1.4 Main Steam System'Materials The materials of construction for subject mechanical components of the Main Steam System are:* Aluminum" Gray cast iron" Stainless steel* Steel Environments Subject mechanical components of the Main Steam System are exposed to the following normal operating environments:
• Air-indoor uncontrolled
• Dried air* Moist air* Steam* Treated water
• Treated water > 60 OC (140 OF)Aging Effects Requiring Management The following aging effects require management for the subject mechanical components of the Main Steam System: o Cracking* Loss of material* Loss of pre-load Aging Management Review Results Page 3.4-5 January 2010* * *
• Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program
• Flow-Accelerated Corrosion (F AC) Program
• Supplemental Piping/Tank Inspection 3.4.2.1.4 Materials Main Steam System* Columbia Generating Station License Renewal Application Technical Information The materials of construction for subject mechanical components of the Main Steam System are:
• Aluminum
• Gray cast iron
• Stainless steel
• Steel Environments Subject mechanical components of the Main Steam System are exposed to the following normal operating environments:
• Air-indoor uncontrolled
• Dried air
• Moist air
• Steam
• Treated water
• Treated water> 60 °C (140 OF) . Aging Effects Requiring Management The following aging effects require management for the subject m.echanical components of the Main Steam System:
• Cracking
• Loss of material
• Loss of pre...:load Aging Management Review Results Page 3.4-5 January 2010 Columbia Generating Station License Renewal Application Technical Information Aging Management.Programs The following aging management programs manage the aging effects for subject mechanical components of the Main Steam System:* Bolting Integrity Program" BWR Water Chemistry Program* Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program" Flow-Accelerated Corrosion (FAC) Program" Selective Leaching Inspection
• Supplemental Piping/Tank Inspection 3.4.2.1.5 Main Steam Leakage Control System Materials The materials

'of construction for subject mechanical components of the. Main Steam Leakage Control System are:* Gray cast iron* Stainless steel* Steel Environments Subject mechanical components of the Main Steam Leakage Control System are exposed to the following normal operating environments:

• Air-indoor uncontrolled
• Steam Aging Effects Requiring Management The following aging effects require management for the subject mechanical components of the Main Steam Leakage Control System: " Loss of material* Loss of pre-load Aging Management Review Results Page 3.4-6 January 2010 Aging Management-Programs Columbia Generating Station License Renewal Application Technical Information The following aging management programs manage the aging effects for subject mechanical cOmponents of the Main Steam System:
• Bolting Integrity Program
• BWR Water Chemistry Program
• Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program
• Flow-Accelerated Corrosion (FAC) Program
• Selective Leaching Inspection
• Supplemental Piping/Tank Inspection 3.4.2.1.5 Materials Main Steam Leakage Control System The materials

'of construction for subject mechanical components of the* Main Steam Leakage Control System are:

• Gray cast iron
• Stainless steel
• Steel Environments Subject mechanical components of the Main Steam Leakage Control System are exposed to the following normal operating environments:
• Air-indoor uncontrolled
• Steam Aging Effects Requiring Management The following aging effects require management for the subject mechanical components of the Main Steam Leakage Control System: .
• Loss of material
• Loss of pre-load Aging Management Review Results Page 3.4-6 January 2010 * *
• Columbia Generating Station License Renewal Application Technical Information Aging Management Programs The following aging management programs manage the aging effects for subject mechanical components of the Main Steam Leakage Control System: " Bolting Integrity Program* BWR Water Chemistry Program" Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program3.4.2.1.6 Miscellaneous Drain System Materials The materials of construction for subject mechanical components of the Miscellaneous Drain System are: " Stainless steel" Steel Environments Subject mechanical components of the Miscellaneous Drain System are exposed to the following normal operating environments:
• Air-indoor uncontrolled

.Moist air* Steam Aging Effects Requiring Management The following aging effects requite management for the subject mechanical components of the Miscellaneous Drain System: " Cracking" Loss of material 0 Loss of pre-load Aging Management Review Results Page 3.4-7 January 2010* *

• Aging Management Programs Columbia Generating Station License Renewal Application Technical Information The following aging management programs manage the aging effects for subject* mechanical components of the Main Steam Leakage Control System:
• Bolting Integrity Program
• BWR Water Chemistry Program
• Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program 3.4.2.1.6 Materials Miscellaneous Drain System The materials of construction for subject mechanical components of the Miscellaneous Drain System are:
• Stainless steel
• Steel* Environments Subject mechanical components of the Miscellaneous Drain System are exposed to the following normal operating environments:* .
• Air-indoor uncontrolled

'. Moist air

• Steam Aging Effects Requirill1g Management The following aging require management for the subject mechanical components of the Miscellaneous Drain System:
• Cracking
• Loss of material
• Loss of pre-load Aging Management Review Results Page 3.4-7 January 2010 Columbia Generating Station License Renewal Application Technical Information Aging Management Programs The following aging management programs manage the aging effects for subject mechanical components of the Miscellaneous Drain System:* Bolting Integrity Program* BWR Water Chemistry Program" Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program* Flow-Accelerated Corrosion (FAC) Program* Supplemental Piping/Tank Inspection 3.4.2.1.7 Reactor Feedwater System Materials The materials of construction for the subject mechanical components of the Reactor Feedwater System are: " Stainless steel* Steel Environments The subject mechanical components of the Reactor Feedwater System are exposed to the following normal plant operating environments: " Air-indoor uncontrolled
• Trea ted water > 60 °C (140 OF)Aging Effects Requiring Management The following aging effects require management for the subject mechanical components of the Reactor Feedwater System:* Cracking* Loss of material* Loss of pre-load Aging Management Review Results Page 3.4-8 January 2010 Aging Management Review Results Page 3.4-8 January 2010 Aging Management Programs , Columbia Generating Station License Renewal Application Technical Information The following aging management programs manage the aging effects for subject mechanical components of the Miscellaneous Drain System:
• Bolting Integrity Program
• BWR Water Chemistry Program
• Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program
• Flow-Accelerated Corrosion (FAC) Program
• Supplemental Piping/Tank Inspection 3.4.2.1.7 Materials Reactor Feedwater System The materials of construction for the subject mechanical components of the Reactor Feedwater System are:
• Stainless steel
• Steel Environments The subject mechanical components of the Reactor Feedwater System are exposed to the following normal plant operating environments:
• Air-indoor uncontrolled
• Trea1ted water> 60 °C (140 OF) Aging Effects Requiring Management The following aging effects require management for the subject mechanical components of the Reactor Feedwater System:
• Cracking
• Loss of material
• Loss of pre-load Aging Management Review Results Page 3.4-8 January 2010 * *
• Columbia Generating Station License Renewal Application Technical Information Aging Management Programs The following aging management programs manage the aging effects for the subject mechanical components of the Reactor Feedwater System:* Bolting Integrity Program* BWR Water Chemistry Program* Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program* Flow-Accelerated Corrosion (FAC) Program3.4.2.2 Further Evaluation of Aging Management as Recommended by NUREG-1801 For the Steam and Power Conversion systems, those items requiring further evaluation are addressed in the following sections.3.4.2.2.1 Cumulative Fatigue Damage Fatigue is a time-limited aging analysis, as defined in 10 CFR 54.3. Time-limited aging analyses are required to be evaluated in accordance with 10 CFR 54.21(c).

Time-limited aging analyses identified for fatigue in the Steam and Power Conversion systems are evaluated in Section 4.3.4. 3.4.2.2.2 Loss of Material due to General, Pitting, and Crevice Corrosion 3.4.2.2.2.1 Piping, Piping Components, Piping Elements, Tanks, and Heat Exchangers Loss of material d.ue to general, pitting,, and crevice corrosion for steel piping components and tanks exposed to treated water (including steam) in the Steam andPower Conversion systems is managed by the BWR Water Chemistry Program. The BWR Water Chemistry Program manages aging effects through periodic monitoring and control of contaminants. The Chemistry Program Effectiveness Inspection will provide a verification of the effectiveness of the BWR Water Chemistry Program to manage loss of material due to general, pitting, and crevice corrosion through examination of steel piping components and tanks exposed to treated water.3.4.2.2.2.2 Piping, Piping Components, and Piping Elements -Lubricating Oil As described in Table 3.4.1, there are no components compared to item number 3.4.1-07. There are no steel components exposed to a lubricating oil environment that are subject to AMR for the Steam and Power Conversion systems.Aging Management Review Results Page 3.4-9 January 2010* *

• Aging Management Programs \ Columbia Generating Station License Renewal Application Technical Information The following aging management programs manage the aging effects for the subject mechanical components of the Reactor Feedwater System:
• Bolting Integrity Program
• BWR Water Chemistry Program
• Chemistry Program Effectiveness Inspection
• External Surfaces Monitoring Program
• Flow-Accelerated Corrosion (FAC) Program 3.4.2.2 Further Evaluation of Aging Management as Recommended by NUREG-1801 For the Steam and. Power Conversion systems, those items requiring further evaluation are addressed in the following sections. . 3.4.2.2.1 Cumulative Fatigue Damage Fatigue is a time-limited aging analysis, as defined in 10 CFR 54.3. Time-limited aging analyses are required to be evaluated in accordance with 10 CFR 54.21 (c). limited aging analyses identified for fatigue in the Steam and Power Conversion systems are evaluated in Section 4.3.4. 3.4.2.2.2 Loss of Material due to General, Pitting, and Crevice Corrosion 3.4.2.2.2.1 Piping, Piping Components, Piping Elements, Tanks, and Heat Exchangers Loss of material due to general, pitting,*

and crevice corrosion for steel piping components and tanks exposed to treated water (including steam) in the Steam and Power Conversion systems is managed by the BWR Water Chemistry Program. The BWR Water Chemistry Program manages aging effects through periodic monitoring and control of contaminants. The Chemistry Program Effectiveness Inspection will provide a verification of the effectiveness of the BWR Water Chemistry Program to manage loss , of material due to general, pitting, and crevice corrosion through examination of steel piping components and tanks exposed to treated water. 3.4.2.2.2.2 Piping, Piping Components, and Piping Elements -Lubricating Oil As described in Table 3.4.1, there are no components compared to item number 3.4.1-07. There are no steel components exposed to a lubricating oil environment that are subject to AMR for the Steam and Power Conversion systems . Aging Management Review Results Page 3.4-9 January 2010 Columbia Generating Station License Renewal Application Technical Information 3.4.2.2.3 Loss of Material due to General, Pitting, Crevice, and Microbiologically Influenced Corrosion (MIC), and Fouling As described in Table 3.4.1, there are no components compared to item number 3.4.1-08. There are no steel Steam and Power Conversion systems components exposed to raw-water and subject to AMR 3.4.2.2.4 Reduction of Heat Transfer due to Fouling 3.4.2.2.4.1 Heat Exchanger Tubes -Treated Water As described in Table 3.4.1, there are no components compared to item number 3.4.1-09. There are no heat exchanger tubes subject to AMR in the Steam and Power Conversion systems.3.4.2.2.4.2 Heat Exchanger Tubes -Lubricating Oil As described in Table 3.4.1, there are no components compared to item number 3.4.1-10. There are no heat exchanger tubes exposed to lubricating oil and subject to AMR in the Steam and Power Conversion systems.3.4.2.2.5 Loss of Material due to General, Pitting, Crevice, and Microbiologically Influenced Corrosion 3.4.2.2.5.1 Piping, Piping Components, and Piping Elements -Soil Loss of material due to general, pitting, and crevice corrosion and MIC for steel piping components with coatings and buried in soil is managed by the Buried Piping and Tanks Inspection Program.3.4.2.2.5.2 Heat Exchanger Components -Lubricating Oil As described in Table 3.4.1, there are no components compared to item number 3.4.1-12. There are no steel heat exchanger components exposed to lubricating oil and subject to AMR in the Steam and Power Conversion systems.3.4.2.2.6 Cracking due to Stress Corrosion Cracking (SCC)Cracking due to SCC for stainless steel piping components exposed to treated water or steam in the Steam and Power Conversion systems is managed by the BWR Water Chemistry Program. The BWR Water Chemistry Program manages aging effects through periodic monitoring and control of contaminants. The Chemistry Program Effectiveness Inspection will provide a verification of the effectiveness of the BWR Water Chemistry Program to manage cracking due to SCC through examination of stainless steel piping components exposed to treated water or steam.In the case of stainless steel bolting submerged in the suppression pool and exposed to treated water, the Bolting Integrity Program is credited with management of cracking.Aging Management Review Results Page 3.4-10 January 2010 Columbia Generating Station License Renewal Application Technical Information 3.4.2.2.3 Loss of Material due to General, Pitting, Crevice, and Microbiologically Influenced Corrosion (MIC), and Fouling As described in Table 3.4.1, there are no components compared to item number 3.4.1-08. There are no steel Steam and Power Conversion systems components exposed to raw water and subject to AMR 3.4.2.2.4 Reduction of Heat Transfer due to Fouling 3.4.2.2.4.1 Heat Exchanger Tubes -Treated Water As described in Table 3.4.1, there are no components compared to item number 3.4.1-09. There are no heat exchanger tubes subject to AMR in the Steam and Power Conversion systems. 3.4.2.2.4.2 Heat Exchanger Tubes -Lubricating Oil As described in Table 3.4.1, there are no components compared to item number 3.4.1-10. There are no heat exchanger tubes exposed to lubricating oil and subject to AMR in the Steam and Power Conversion systems. 3.4.2.2.5 Loss of Material due to General, Pitting, Crevice, and Microbiologically Influenced Corrosion . 3.4.2.2.5.1 Piping, Piping Components, and Piping Elements -Soil Loss of material due to general, pitting, and crevice corrosion and MIC for steel piping components with coatings and buried in soil is managed by the Buried Piping and Tanks Inspection Program. 3.4.2.2.5.2 Heat Exchanger Components -Lubricating Oil As described in Table 3.4.1, there are no components compared to item number 3.4.1-12. There are no steel heat exchanger components exposed to lubricating oil and subject to AMR in the Steam and Power Conversion systems. 3.4.2.2.6 Cracking due to Stress Corrosion Cracking (SCC) Cracking due to SCC for stainless steel piping components exposed to treated water or steam in the Steam and Power Conversion systems is managed by the BWR Water Chemistry Program. The BWR* Water Chemistry Program manages aging effects through periodic monitoring and control of contaminants.* The Chemistry Program Effectiveness Inspection will provide a verification of the effectiveness of the BWR Water Chemistry Program to manage cracking due to SCC through examination of stainless steel piping components exposed to treated water or steam. In the case of stainless steel bolting submerged in the suppression pool and exposed to treated water, the Bolting Integrity Program is credited with management of cracking. Management Review Results Page 3.4-10 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information The Bolting Integrity Program includes the periodic inspection of bolting for indications of degradation.

3.4.2.2.7 Loss of Material due to Pitting and Crevice Corrosion 3.4.2.2.7.1 Piping, Piping Components, Piping Elements, Tanks, and Heat Exchanger Components There are no aluminum components, no copper alloy components, no stainless steel tanks, and no stainless steel heat exchanger components exposed to treated water and subject to AMR in the Steam and Power Conversion systems.Loss of material due to pitting and crevice corrosion for stainless steel piping components and loss of material for steel tanks exposed to treated water in the Steam and Power Conversion systems is managed by the BWR Water Chemistry Program.The BWR Water Chemistry Program manages aging effects through periodic monitoring and control of contaminants. The Chemistry Program Effectiveness Inspection will provide a verification of the effectiveness of the BWR Water Chemistry Program to manage loss of material through examination of stainless steel piping components and steel tanks exposed to treated water.In the case of stainless steel bolting exposed to treated water, the Bolting Integrity Program is credited with management of loss of material. The Bolting Integrity Program includes the periodic inspection of bolting for indications of degradation. 3.4.2.2.7.2 Piping, Piping Components, Piping Elements -Soil As described in Table 3.4.1, there are no components compared to item number 3.4.1-17. There are no stainless steel piping components in the Steam and Power Conversion systems that are exposed to soil.3.4.2.2.7.3 Piping, Piping Components, Piping Elements -Lubricating Oil As described in Table 3.4.1, there are no components compared to item number 3.4.1-18. There are no copper alloy piping components exposed to lubricating oil and subject to AMR in the Steam and Power Conversion systems.3.4.2.2.8 Loss of Material due to Pitting, Crevice, and Microbiologically Influenced Corrosion As described in Table 3.4.1, there are no components compared to item number 3.4.1-19. There are no stainless steel piping or heat exchanger components exposed to lubricating oil and subject to AMR in the Steam and Power Conversion systems.3.4.2.2.9 Loss of Material due to General, Pitting, Crevice; and Galvanic, Corrosion Loss of material due to general, galvanic, pitting, and crevice corrosion for steel heatexchanger components (main condenser shell) exposed to treated water in the Steam Aging Management Review Results Page 3.4-11 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information The Bolting Integrity Program includes the periodic inspection of bolting for indications of degradation.

Loss of Material due to Pitting and Crevice Corrosion 3.4.2.2.7 3.4.2.2.7.1 Piping, Piping Components, Piping Elements, Tanks, and Heat Exchanger Components There are no aluminum components, no copper alloy components, no stainless steel tanks, and no stainless steel heat exchanger components exposed to treated water and I subject to AMR in the Steam and Power Conversion systems. Loss of material due to pitting and crevice corrosion for stainless steel piping components and loss of material for steel tanks exposed to treated water in the and Power Conversion systems is managed by the BWR Water Chemistry Program. The BWR Water Chemistry Program manages aging effects through periodic monitoring and control of contaminants. The Chemistry Program Effectiveness Inspection will provide a verification of the effectiveness of the BWR Water Chemistry Program to manage loss of material through examination of stainless steel piping components and steel tanks exposed to treated water. In the case of stailliesis steel bolting exposed to' treated water, the Bolting Integrity Program is credited with management of loss of material. The Bolting Integrity Program includes the periodic inspection of bolting for indications of degradation. 3.4.2.2.7.2 Piping, Piping Components, Piping Elements -Soil As described in Table 3.4.1, there are no components compared to item number 3.4.1-17. There are no s.tainless steel piping components in the Steam and Power Conversion systems that are exposed to soil. 3.4.2.2.7.3 Piping, Piping Components, Piping Elements -Lubricating Oil As described in Table 3.4.1, there are no components compared to item number 3.4.1-18. There are no copper alloy piping components exposed to lubricating oil and subject to AMR in the Steam and Power Conversion systems. 3.4.2.2.8 Loss of Material due to Pitting, Crevice, and Microbiologically Influenced . Corrosion As described in Table 3.4.1, there are no components compared to item number 3.4.1-19. There are no stainless steel piping or heat exchanger components exposed to lubricating oil and subjelct to AMRin the Steam and Power Conversion systems. 3.4.2.2.9 Loss of Material due to General, Pitting, Crevice,* and Galvanic, Corrosion Loss of material due to general, galvanic, pitting, and crevice corrosion for steel heat exchanger components (main condenser shell) exposed to treated water in the Steam Aging Management Review Results Page 3.4-11 January 2010 Columbia Generating Station License Renewal Application Technical Informationand Power Conversion systems is managed by the BWR Water Chemistry Program.The BWR Water Chemistry Program manages aging effects through periodic monitoring and control of contaminants. The Chemistry Program Effectiveness Inspection will provide a verification of the effectiveness of the BWR Water Chemistry Program to manage loss of material through examination of steel heat exchanger components exposed to treated water.3.4.2.2.10 Quality Assurance for Aging Management of Non-safety Related Components Quality Assurance provisions applicable to license renewal are discussed in Appendix B, Section B.1.3.3.4.2.3 Time-Limited Aging Analyses The time-limited aging analysis identified below are associated with the Steam andPower Conversion Systems components. The section of the application that contains the time-limited aging analysis review results is indicated in parentheses.

• Metal Fatigue (Section 4.3, Metal Fatigue)3.4.3 Conclusions The Steam and Power Conversion Systems components and commodities subject to AMR have been identified in accordance with 10 CFR 54.21. The aging management programs selected to manage the effects of aging for the mechanical components and commodities are identified in the following tables and Section 3.4.2.1. A description of the aging management programs is provided in Appendix B, along with the demonstration that the identified aging effects will be managed for the period of extended operation.

Therefore, based on the demonstration provided in Appendix B, the effects of aging associated with the Steam and Power Conversion Systems components and commodities will be managed so that there is reasonable assurance that the intended functions will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Review Results Page 3.4-12 January 2010 Columbia Generating Station License Renewal Application Technical Information and Power Conversion systems is managed by the BWR Water Chemistry Program. The BWR Water Chemistry Program manages aging effects through periodic monitoring and control of contaminants. The Chemistry Program Effectiveness Inspection will provide a verification of the effectiveness of the BWR Water Chemistry Program to manage loss of material through examination of steel heat exchanger components exposed to treated water. 3.4.2.2.10 Quality Assurance for Aging Management of Non-safety Related Components Quality Assurance provisions applicable to ficense renewal are discussed in Appendix B, Section B.1.3. 3.4.2.3 Time-Limited Aging Analyses . The time-limited aging analysis identified below are associated with the Steam and Power Conversion Systems components. The section of the application that contains the time-limited aging analysis review results is indicated in parentheses.

• Metal Fatigue (Section 4.3, Metal Fatigue) 3.4.3 Conclusions The Steam and Power Conversion Systems components and commodities subject to AMR have been identified in accordance with 10 CFR 54.21. The aging management programs selected to manage the effects of aging for the mechanical components and commodities are identified in the following tables and Section 3A2.1. A description of the aging management programs . is provided in Appendix B, along. with the demonstration that* the identified aging effects will be managed for the period of extended operation.

Therefore, based on the demonstration provided in Appendix B, the effects of aging associated with the Steam and Power Conversion Systems components and commodities will be managed so that there is reasonable assurance that the intended functions will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Review Results Page 3.4-12 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1.801 Item IAging Effect/ Aging Management Further Number Component/Commodity M echanams Evaluation Discussion Number CMechanism Programs Recommended 3.4.1-01 'Steel piping, piping components, Cumulative fatigue -T1LAA, evaluated in Yes, TLAA Fatigue is a TLAA.and piping elements exposed to damage accordance with steam or treated water 10 CFR 54.21(c) Refer to Section 3.4.2.2.1 for further information.

3.4.1-02 Steel piping, piping components, Loss of material due Water Chemistry and Yes, detection of Consistent with NUREG-1 801.and piping elements exposed to to general, pitting One-Time Inspection aging effects is steam and crevice to be evaluated The BWR Water Chemistry corrosion .Program, in conjunction with the Chemistry Program Effectiveness Inspection, is credited to manage loss of material for steel piping, piping components, and piping elements in the steam and power conversion systems exposed to steam.Refer to Section 3.4.2.2.2.1 for further information. 3.4.1-03 PWR Only Aging Management Review Results Page 3.4-13 January 2010 Aging Management Review Results Page 3.4A13 January 2010* *

• Columbia Generating Station . License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1.801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-01 Steel piping, piping components, Cumulative fatigue TlAA, evaiuated in Yes, TlAA Fatigue is a TLAA. and piping elements exposed to damage accordance with steam or treated water 10 CFR 54.21 (c) Refer to Section 3.4.2.2.1 for further information.

3.4.1-02 Steel piping, piping components, Loss of material due Water Chemistry and Yes, detection of Consistent with NUREG-1801. and piping elements exposed to to general, pitting One-Time Inspection aging effects is -steam and crevice to be evaluated The BWR Water Chemistry corrosion Program, in conjunction with the Chemistry Program Effectiveness Inspection, is credited to manage loss of material for steel piping, piping components, and piping elements in the steam and power conversion systems exposed to steam. Reifer to Section 3.4.2.2.2.1 for further inforniation. 3.4.1-03 PWROnly . Aging Management Review Results Page 3.4'-13 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1 801 Further Item Component/Commodity Aging Effect/ Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-04 Steel piping, piping components, Loss of material due Water Chemistry and Yes, detection of Consistent with NUREG-1 801.and piping elements exposed to to general, pitting One-Time Inspection aging effects is treated water and crevice to be evaluated The BWR Water Chemistry corrosion Program, in conjunction with the Chemistry Program Effectiveness Inspection, is credited to manage loss of material for steel piping, piping components, and piping elements in the steam and power conversion systems exposed to treated water, including treated water >60 C (140 'F).Refer to Section 3.4.2.2.2.1 for further information. Aging Management Review Results Page 3.4-14 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-04 Steel piping, piping components, Loss of material due Water Chemistry and Yes, detection of Consistent with NUREG-1801. and piping elements exposed to to general, pitting One-Time Inspection aging effects is treated water and crevice to be evaluated The BWR Water Chemistry corrosion Program, in conjunction with the Chemistry Program Effectiveness Inspection, is credited to manage loss of material for steel piping, piping components, and piping elements in the steam and power conversion systems exposed to treated water, including treated water >60 C (140 OF). Refer to Section 3.4.2.2.2.1 for -further information. Aging Management Review Results Page 3.4-14 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 I Further Item Aging Effect/ Aging Management Evaluation Discussion Number Component/Commodity Mechanism Programs Ecommended

~Recommended 3.4.1-05 Steel heat exchanger Loss of material due Water Chemistry and [Yes, detection of 1 Consistent with NUREG-1 801.components exposed to treated to general, pitting, %One-Time Inspection aging effects is water crevice, and to be evaluated The BWR Water Chemistry , galvanic corrosion Program, in conjunction with the Chemistry Program Effectiveness Inspection, is credited to manage loss of material for steel heat exchanger components of the main condenser (the waterbox, the hotwell, and the steam space)exposed to treated water.Refer to Section 3.4.2.2.9 for further information. Aging Management Review Results Page 3.4-15 January 2010.Aging Management Review Results Page 3.4-15 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for: Steam and Power Conversion Systems 'Evaluated'in Chapter VIII of NUREG-1801 Item Aging Effect/ Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-05 Steel heat exchanger Loss of material due Water Chemistry and Yes, detection of Consistent with NUREG-1801.

components exposed to treated to general, pitting, On6-Time Inspection aging effects is water crevice, and to be evaluated The BWR Water Chemistry

• galvanic corrosion Program, in conjunction with the Chemistry Program Effectiveness Inspection, is credited to manage loss of material for steel heat exchanger

.-components of the main ) condenser (the waterbox, the hotwel!, and the steam space) exposed to treated water. Refer to Section 3.4.2.2.9 for further information. Aging Management Review Results Page 3.4-15 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Further Item Aging Effect/ Aging Management Evaluation Discussion Number ComponentlCommodity Mechanism Programs Recommended Discus____ 3.4.1-06 Steel and stainless steel tanks Loss of material due Water Chemistry and Yes, detection of Consistent with NUREG-1 801.exposed to treated water to general (steel One-Time Inspection aging effects is only) pitting and to be evaluated The BWR Water Chemistrycrevice corrosion Program, in conjunction with the Chemistry Program Effectiveness Inspection, is credited to manage loss of material for steel tanks in the steam and power conversion systems exposed to treated water. There are no stainless steel tanks in the steam and power conversion systems exposed to treated water.Refer to Sections 3.4.2.2.2.1 and 3.4.2.2.7.1 for further information. 3.4.1-07 Steel piping, piping components, Loss of material due Lubricating Oil Analysis Yes, detection of Not applicable. and piping elements exposed to to general, pitting and One-Time aging effects is lubricating oil and crevice Inspection to be evaluated There are no steel piping, piping corrosion components, or piping elements in the steam and power conversion systems exposed to lubricating oil.Refer to Section 3.4.2.2.2.2 for further information. Aging Management Review Results Page 3.4-16 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-06 Steel and stainless steel tanks Lossof material due Water Chemistry and Yes, detection of Consistent with NUREG-1801. exposed to treated water to general (steel One-Time Inspection aging effects is only) pitting and to be evaluated The BWR Water Chemistry crevice corrosion Program, in conjunction with the , Chemistry Program Effectiveness Inspection, is -credited to manage loss of material for steel tanks in the steam and power conversion systems exposed to treated . , water. There are no stainless steel tanks in the steam and power conversion systems exposed to treated water. Refer to Sections 3.4.2.2.2.1 and 3.4.2.2.7.1 for further information. 3.4.1-07 Steel piping, piping components, Loss of material due Lubricating Oil Analysis Yes, detection of Not applicable. and piping elements exposed to to general, pitting and One-Time aging effects is , lubricating oil and crevice Inspection to be evaluated There are no steel piping, piping corrosion components, or piping elements in the steam and power conversion systems exposed to lubricating oil. Refer to Section 3.4.2.2.2.2 for further information. Aging Management Review Results Page 3.4-16 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Further Item Component/Commodity Aging Effect Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-08 Steel piping, piping components, Loss of material due Plant specific Yes, plant INot applicable.

and piping elements exposed to to general, pittsping,ecif"" raw water crevice, and There are no steel piping, piping microbiologically components, or piping elements influenced corrosion, in the steam and power and fouling conversion systems exposed to raw water.Refer to Section 3.4.2.2.3 for further information. 3.4.1-09 Stainless steel and copper alloy Reduction of heat Water Chemistry and Yes, detection of Not applicable.heat exchanger tubes exposed transfer due to One-Time Inspection aging effects is to treated water fouling to be evaluated There are no stainless steel or copper alloy heat exchanger tubes in the steam and power conversion systems exposed to treated water.Refer to Section 3.4.2.2.4.1 for further information. Agin Maageent eviw Rsult Pae 34-17Janary201 Aging Management Review Results Page 3.4-17 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG*1801 Item Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs Recomm"ended 3.4.1-08 Steel piping, piping components, Loss of material due Plant specific Yes, plant Not applicable.

and piping eiemenis exposed to to general, pitting, sno,..;F;,.. t-'''''III ..... raw water crevice, and There are no steel piping, piping \ microbiologically components, or piping elements influenced corrosion, in the steam and power and fouling conversion systems exposed to raw water. --Refer to Section 3.4.2.2.3 for further information. 3.4.1-09 Stainless steel and copper alloy Reduction of heat Water Chemistry and Yes, detection of Not applicable. heat exchanger tubes exposed transfer due to One-Time Inspection aging effects is to treated water fouling to be evaluated There are no stainless steel or copper alloy heat exchanger tubes in the steam and power conversion systems exposed to . treated water. Refer to Section 3.4.2.2.4.1 for further information. Aging Management Review Results Page 3.4-17 January 2010 Columbia Generating Station-License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1 801 I Further Item i Aging Effectl Aging Management Evaluation Discussion Number Component/Commodity Mechanism Programs Recommended 3.4.1-10 Steel, stainless steel, and copper Reduction of heat Lubricating Oil Analysis Yes, detection of Not applicable. alloy heat exchanger tubes transfer due to and One-Time aging effects is exposed to lubricating oil fouling Inspection to be evaluated There are no steel, stainless steel, or copper alloy heat exchanger tubes in the steam and power conversion systems exposed to lubricating oil.Refer to Section 3.4.2.2.4.2 for further information. 3.4.1-11 Buried steel piping, piping Loss of material due Buried Piping and Tanks No Not applicable. components, piping elements, to general, pitting, Surveillance and tanks (with or without crevice, and The Buried Piping and Tanks coating or wrapping) exposed to microbiologically Surveillance is not credited for soil influenced corrosion aging management. Or Buried Piping and Tanks Yes, detection of Consistent with NUREG-1 801.Inspection aging effects and operating The Buried Piping and Tanks experience are Inspection Program is credited to to be further manage loss of material for evaluated buried steel piping in the steam and power conversion systems exposed to soil.Refer to Section 3.4.2.2.5.1 for further information. Aging Management Review Results Page 3.4-18 January 2010 Columbia Generating Station -License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-10 Steel, stainless steel, and copper Reduction of heat Lubricating Oil Analysis Yes, detection of Not applicable. alloy heat exchanger tubes transfer due to and One-Time aging effects is exposed to lubricating oil fouling Inspection to be evaluated There are no steel, stainless steel, or copper alloy heat . exchanger tubes in the steam and power conversion systems exposed to lubricating oil. Refer to Section 3.4.2.2.4.2 for further information. 3.4.1-11 Buried steel piping, piping Loss of material due Buried Piping and Tanks No Not applicable. components, piping elements, to general, pitting, Surveillance and tanks (with or without crevice, and The Buried Piping and Tanks coating or wrapping) exposed to microbiologically Surveillance is not credited for soil influenced corrosion aging management. Or Buried Piping and Tanks Yes, detection of Consistent with NUREG-1801. Inspection aging effects and operating The Buried Piping and Tanks experience are Inspection Program is credited to to be further manage loss of material for evaluated buried steel piping in the steam and power conversion systems exposed to soil. Refer to Section 3.4.2.2.5.1 for further information. Aging Management Review Results Page 3.4-18 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effect/I Aging Management Further Number Component/Commodity Mechanism E Programs Evaluation Discussion Number ____ _ Mehais ProgramsRecommended 3.4.1-12 Steel heat exchanger Loss of material due {Lubricating Oil Analysis Yes, detection of Not applicable.components exposed to to general, pitting, and One-Time aging effects is lubricating oil crevice, and Inspection to be evaluated There are no steel heat.microbiologically exchanger components in theinfluenced corrosion steam and power conversionsystems exposed to lubricating oil.Refer to Section 3.4.2.2.5.2 for further information.

3.4.1-13 Stainless steel piping, 'piping Cracking due to Water Chemistry and Yes, detection of Consistent with NUREG-1801. components, piping elements stress corrosion One-Time Inspection aging effects is exposed to steam cracking to be evaluated The BWR Water Chemistry Program, in conjunction with the Chemistry Program Effectiveness Inspection, iscredited to manage cracking forstainless steel piping, piping components, and piping elements in the steam and power conversion systems exposed to steam.Refer to Section 3.4.2.2.6 for further information. Aging Management Review Results Page 3.4-19 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommod ity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-12 Steel heat exchanger Loss of material due Lubricating Oil Analysis Yes, detection of Not applicable.

components exposed to to general, pitting, and One-Time aging effects is lubricating oil crevice, and Inspection to be evaluated There are no steel heat microbiologically exchanger components in the influenced corrosion steam and power conversion systems exposed to lubricating oil. Refer to Section 3.4.2.2.5.2 for further information. 3.4.1-13 Stainless steel piping, 'piping Cracking due to Water Chemistry and Yes, detection of Consistent with NUREG,.1801. components, piping elements stress corrosion One-Time Inspection aging effects is exposed to steam cracking to be evaluated The BWR Water Chemistry Program, in conjunction with the Chemistry Program Effectiveness Inspection, is credited to manage cracking for stainless steel piping, piping components, and piping* ---elements in the steam and power conversion systems exposed to steam. Refer to Section 3.4.2.2.6 for further information. Aging Management Review Results Page 3.4-19 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 e AFurther Item Component/Commodity AgiMg Effech Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-14 Stainless steel piping, piping Cracking due to Water Chemistry and Yes, detection of Consistent with NUREG-101. components, piping elements, stress corrosion One-Time Inspection aging effects is tanks, and heat exchanger cracking to be evaluated The BWR Water Chemistry components exposed to treated Program, in conjunction with the water >60 'C (>140 -F) Chemistry ProgramEffectiveness Inspection, is credited to manage cracking for stainless steel piping, piping components, and piping elements in the steam and power conversion systems exposed to treated water >60 OC (140 -F).This item is also applied to stainless steel bolting associated with the main steam quenchers submerged in, and exposed to the treated water environment of,the suppression pool. The Bolting Integrity Program is credited to manage cracking of this bolting. A Note E is applied.Refer to Section 3.4.2.2.6 for further information. Aging Management Review Results Page 3.4-20 January 2010 Aging Management Review Results Page 3.4-20 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Agirig Effectl Aging Management Further Com ponentiCommod ity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-14 Stainless steel piping, piping Cracking due to Water Chemistry and Yes, detection of Consistent with NUREG-101. components, piping elements, stress corrosion One-Time Inspection aging effects is tanks, and heat exchanger cracking to be evaluated The BWR Water Chemistry components exposed to treated Program, in conjunction with the water >60 °C (>140 OF) Chemistry Program Effectiveness Inspection, ,is credited to manage cracking for t stainless steel piping, piping components, and piping elements in the steam and -power conversion systems exposed to treated water >60 DC (140 OF). This item is also applied to stainless steel bolting associated with the main steam quenchers submerged in, and exposed to the treated water environment of, the suppression pool. The Bolting Integrity Program is credited to manage cracking of this bolting. A Note E is applied. Refer to Section 3.4.2.2.6 for further information. Aging Management Review Results Page 3.4-20 January 2010 * *

• 0 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 1 Further Item Aging Effect/ Aging Management Evaluation Discussion Number Component/Commodity Mechanism Programs Recommended 3.4.1-15 Aluminum and copper alloy Loss of material due Water Chemistry and fYes, detection of Not applicable.

piping, piping components, and to pitting and crevice One-Time Inspection aging effects is piping elements exposed to corrosion to be evaluated There are no aluminum or treated water copper alloy piping, piping components, or piping elements in the steam and power conversion systems exposed to treated water.Refer to Section 3.4.2.2.7.1 for further information. Aging Management Review Results Page 3.4-21 January 2010 Aging Management Review Results Page 3.4-21 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of. NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-15 Aluminum apd copper alloy Loss of material due Water Chemistry and Yes, detection of Not applicable.

piping, piping components, and to pitting and crevice One-Time Inspection aging effects is piping elements exposed to corrosion to be evaluated There are no aluminum or treated water copper alloy piping, piping components, or piping elements in the steam and power -conversion systems exposE;ld to treated water. Refer to Section 3.4.2.2.7.1 for further information. Aging Management Review Results Page 3.4-21 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1 801 I Further 1 Item Aging Effect/ Aging Management Evaluation Discussion Number Component/Commodity Mechanism Programs Recommended 3.4.1-16 Stainless steel piping, piping Loss of material due Water Chemistry and Yes, detection of Consistent with NUREG-1801. components, and piping to pitting'and crevice One-Time Inspection aging effects is elements; tanks, and heat corrosion to be evaluated The BWR Water Chemistry exchanger components exposed Program, in conjunction with the to treated water Chemistry Program Effectiveness Inspection, is credited to manage loss of material for stainless steel piping, piping components, and piping elements in the steam and power conversion systems exposed to treated water, including treated water >60 C (140 OF). There are no stainless steel tanks or heat exchanger components in the steam and power conversion systems exposed to treated water.This item is also applied to -stainless steel bolting associated with the main steam quenchers submerged in, and exposed to the treated water environment of, the suppression pool. The Bolting Integrity Program is credited to manage loss of material. A Note E is applied.Refer to Section 3.4.2.2.7.1 for further information. Aging Management Review Results Page 3.4-22 January 2010 Aging Management Review Results Page 3.4-22 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 i Further Item ComponentiCommodity Aging Effectl Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-16 Stainless steel piping, piping Loss of material due Water Chemistry and Yes, detection of Consistent with NUREG-1801. components, and piping to pitting' and crevice One-Time Inspection aging effects is The BWR Water Chemistry elements; tanks, and heat corrosion to be evaluated exchanger components exposed Program, in conjunction with the totreated water Chemistry Program Effectiveness Inspection, is credited to manage loss of material for stainless steel piping, piping components, and piping elements in the steam and power conversion systems exposed to treated water, including treated water >60 C (140 OF). There are no stainless steel tanks or heat exchanger components in the steam and power conversion systems exposed to treated water. This item is also applied to -stainless steel bolting associated with the main steam quenchers submerged in, and exposed to the treated water environment of, the suppression pool. The Bolting Integrity Program is credited to manage loss of material. A Note E is applied. Refer to Section 3.4.2.2.7.1 for further information. Aging Management Review Results Page 3.4-22 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item ComponentCommodit Aging Effect. Aging Management Further Numberechanis Progm Evaluation Discussion Number Mechanism Programef Recommended 3.4.1-17 [Stainless steel piping, piping Loss of material due JPlant specific Yes, plant Not applicable.

components, and piping to pitting and crevice specific,,elements exposed to soil corrosion There are no stainless steel piping, piping components, or piping elements in the steam and power conversion systems exposed to soil.Refer to Section 3.4.2.2.7.2 for further information. 3.4.1-18 Copper alloy piping, piping Loss of material due Lubricating Oil Analysis Yes, detection of Not applicable. components, and piping to pitting and crevice and One-Time aging effects is elements exposed to lubricating corrosion Inspection to be evaluated There are no copper alloy piping, oil piping components, or piping elements in the steam and power conversion systems exposed to lubricating oil.Refer to Section 3.4.2.2.7.3 for further information. Aging Management Review Results Page 3.4-23 January 2010* -.

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effect/ . Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-17 Stainless steel piping, piping Loss of material due Plant specific Yes, plant Not applicable.

components, and piping to pitting and crevice specific elements exposed to soil corrosion There are no stainless steel piping, piping components, or piping elements in the steam and power conversion systems exposed to soil. Refer to Section 3.4.2.2.7.2 for further information. 3.4.1-18 Copper alloy piping, piping Loss of material due Lubricating Oil Analysis Yes, detection of Not applicable. components, and piping to pitting and crevice and One-Time aging effects is elements exposed to lubricating corrosion Inspection to be evaluated There are no copper alloy piping, oil piping components, or piping , elements in the steam and power conversion systems exposed to lubricating oil. Refer to Section 3.4.2.2.7.3 for further information. Aging Management Review Results Page 3.4-23 January 2010 Columbia Generating Station License Renewal Application Technical Information C Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801e AFurther Item Component/Commodity Aging Effect Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-19 Stainless steel piping, piping Loss of material due Lubricating Oil Analysis Yes, detection of Not applicable. components, piping elements, to pitting, crevice, and One-Time aging effects is and heat exchanger components and microbiologically Inspection to be evaluated There are no stainless steel exposed to lubricating oil influenced corrosion piping, piping components, piping elements, or heat exchanger components in the steam and power conversionsystem exposed to lubricating oil.Refer to Section 3.4.2.2.8 for further information. 3.4.1-20 Steel tanks exposed to air- Loss of material/ Aboveground Steel No Consistent with NUREG-1 801, outdoor (external) general, pitting, and Tanks with exceptions. crevice corrosion The Aboveground Steel Tanks Inspection will detect and characterize loss of material where the base of the steel condensate storage tank (CST)is in contact with the tank foundation and exposed to air-outdoor. The design of the CST foundation allows potential water pooling at the bottom of the tanks due to exposure to precipitation (e.g., rain, snow).Refer also to Item Number 3.4.1-28 below.Aging Management Review Results Page 3.4-24 January 2010 Aging Management Review Results Page 3.4-24 January 2010 ( Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effect/ Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-19 Stainless steel piping, piping Loss of material due Lubricating Oil Analysis Yes, detection of Not applicable. components, piping elements, to pitting, crevice, and One-Time aging effects is and heat exchanger components and microbiologically Inspection to be evaluated There are no stainless steel exposed to lubricating oil influenced corrosion piping, piping components, piping elements, or heat exchanger components in the steam and power conversion system exposed to lubricating oil. Refer to Section 3.4.2.2.8 for further information. 3.4.1-20 Steel tanks exposed to air-Loss of material! Aboveground Steel No Consistent with NUREG-1801, outdoor (external) general, pitting, and Tanks with exceptions. crevice corrosion The Aboveground Steel Tanks Inspection will detect and characterize loss of material where the base of the steel condensate storage tank (CST) is in contact with the tank foundation and exposed to air-outdoor. The design of the CST foundation allows potential water pooling at the bottom of the tanks due to exposure to precipitation (e.g., rain, snow). Refer also to Item Number 3.4.1-28 below. Aging Management Review Results Page 3.4-24 January 2010 * *

• Columbia Generating Station License Renewal.Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effect/ Aging Management Further Number Component/Commodit Mechanism Programs Ecommended Recommended 3.4.1-21 High-strength steel closure Cracking due to Bolting Integrity No Not applicable.

bolting exposed to air with steam cyclic loading, stress or water leakage corrosion cracking There is no high-strength steel bolting in the steam and power conversion systems exposed to air with steam or water leakage.3.4.1-22 Steel bolting and closure bolting Loss of material due Bolting Integrity No Consistent with NUREG-1801, exposed to air with steam or to general, pitting with exceptions. water leakage, air -outdoor and crevice.(external) or air- indoor corrosion; loss of The Bolting Integrity Program isuncontrolled (external); preload due to credited to manage loss ofthermal effects, material and loss of pre-load for gasket creep, and steel bolting in the steam and self-loosening power conversion systems exposed to air-indoor uncontrolled (external) or air-outdoor (external). Some bolting in the Condensate (Auxiliary) System has an external surface temperature exceeding 212 'F; therefore, loss of material is not an aging effect requiring management. A Note I is applied Aging Management Review Results Page-3.4-25 January 2010* *

• Columbia Generating Station License Renewal.Application Technical Information Table 3.4.1 Summary of Aging Management Programsfor Steam and Power* Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-21 High-strength steel closure Cracking due to Bolting Integrity No Not applicable.

boiting exposed to air with steam cyclic loading, stress or water leakage corrosion cracking There is no high-strength steel bolting in the steam and power conversion systems exposed to -air with steam or water leakage. 3.4.1-22 Steel bolting and closure bolting Loss of material due Bolting Integrity No Consistent with NUREG-1801, exposed to air with steam or to general, pitting . with exceptions. water leakage, air...:.. outdoor and crevice. (external) or .air -indoor corrosion; loss of The Bolting Integrity Program is uncontrolled (external); preload due to credited to manage loss of thermal effects, material and loss of pre-load for creep, and steel bolting in the steam and .-self-loosening power conversion systems exposed to air-indoor uncontrolled (external) or air-outdoor (external). -Some bolting in the Condensate -(Auxiliary) System has an external surface temperature exceeding 212 OF; therefore, loss of material is not an aging effect requiring management. A Note I is applied Aging Management Review January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 T j ~ ~FurtherDsuso Item Aging Effect/ Aging Management Evaluation Numbr Mchaism rogamsRecommended 3.4.1-23 Stainless steel piping,.piping Cracking due to Closed-Cycle Cooling No Not applicable. components, and piping stress corrosion Water Systemelements exposed to closed- cracking There are no stainless steel cycle cooling water >60 'C piping, piping components, or (>140 'F) piping elements in the steam and power conversion systems exposed to closed cycle cooling water >60 C (140 'F).3.4.1-24 Steel heat exchanger Loss of material due Closed-Cycle Cooling No Not applicable.components exposed to closed to general, pitting, Water System cycle cooling water crevice, and There are no steel heat galvanic corrosion exchanger components in the steam and power conversion systems exposed to closed cycle cooling water.3.4.1-25 Stainless steel piping, piping Loss of material due Closed-Cycle Cooling No Not applicable. components, piping elements, to pitting and crevice Water System and heat exchanger components corrosion There are no stainless steel exposed to closed cycle cooling piping, piping components, water piping elements, or heat exchanger components in the steam and power conversion systems exposed to closed cycle cooling water.Aging Management Review.Results Page 3.4-26 January 2010 Columbia 'Generating Station License Renewal Application Technical Information Table 3.4.1. Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effectl Aging Management Further COIJlPonentiCommod ity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-23 Stainless steel piping,. piping Cracking due to Closed-Cycle Cooling No Not applicable. components, and piping stress corrosion Water System elements exposed to closed-cracking There are no stainless steel cycle cooling water >60 °C piping, piping components, or (>140 OF) piping elements in the steam and power conversion systems exposed to closed cycle cooling water >60 C (140 OF). 3.4.1-24 Steel heat exchanger Loss of material due Closed-Cycle Cooling No Not applicable. components exposed to closed to general, pitting, Water System cycle cooling water crevice, and There are no steel heat galvanic corrosion , exchanger components in the steam and power conversion .-systems exposed to closed cycle cooling water. 3.4.1-25 Stainless steel piping, piping Loss of material due Closed-Cycle Cooling No Not applicable. components, piping elements, to pitting and crevice Water System and heat exchanger components corrosion There are no stainless steel exposed to closed cycle cooling piping, piping components, water piping elements, or heat exchanger components in the steam and power conversion systems exposed to closed cycle cooling water. Aging Management Review Results Page 3.4-26 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1 801 Further Item Component/Commodity Aging Effect/ Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-26 Copper alloy piping, piping Loss of material due Closed-Cycle Cooling No Not applicable.

components, and piping to pitting, crevice, Water System elements exposed to closed and galvanic There are no copper alloy piping,cycle cooling water corrosion piping components, or piping elements in the steam and power conversion systems exposed to closed cycle cooling water.3.4.1-27 Steel, stainless steel, and copper Reduction of heat Closed-Cycle Cooling No Not applicable. alloy heat exchanger tubes transfer due to Water System exposed to closed cycle cooling fouling There are no steel, stainless water steel, or copper alloy heat exchanger tubes in the steam and power conversion systems exposed to closed cycle cooling-water.Aging.Management Review Results Page 3.4-27 January 2010* *

• Columbia Generating Station License Renewal Application . Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effect! Aging Management Further Com ponent!Commod ity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-26 Copper alloy piping, piping Loss of material due Closed-Cycle Cooling No Not applicable.

components, and piping to pitting, cievice, Water System elements exposed to closed and galvanic There are no copper alloy piping, cycle cooling water corrosion piping components, or piping elements in the steam and power conversion systems exposed to closed cycle cooling water. 3.4.1-27 Steel, stainless steel, and copper Reduction of heat Closed-Cycle Cooling No Not applicable. alloy heat exchanger tubes transfer due to Water System exposed to closed cycle cooling fouling There are no steel, stainless water steel, or copper alloy heat exchanger tubes in the steam and power conversion systems exposed to closed cycle cooling -water. Aging Management Review Results Page 3.4-27 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1 801 I Further Item Aging Effect/ Aging Management Evaluation Discussion Number ComponentlCommodity Mechanism Programs Recommended3.4.1-28 Steel external surfaces exposed Loss of material due External Surfaces No Consistent with NUREG-1 801.to air- indoor uncontrolled to general corrosion Monitoring (external), condensation Except as noted below, the (external) or air outdoor External Surfaces Monitoring (external) Program is credited to manage loss of material for steel external surfaces in the steam and power conversion systems exposed toair-indoor uncontrolled (external), condensation (external) or air-outdoor (external). This includes the external surfaces of each CST not in contact with, the tank foundation (refer to Item Number 3.4.1-20).This item, is also applied to steel turbine casings exposed to air-indoor uncontrolled (external); and to steel internal surfaces exposed to air-indoor uncontrolled (internal) where it has been demonstrated that the internal environment is the same as the external environment. The External Surfaces Monitoring Program is credited.A Note C is applied in these cases.Aging Management Review Results Page 3.4-28 January 2010 Aging Management Review Results Page 3.4-28 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems "-Evaluated in Chapter VIII of NUREG-1801 Item Aging Effectl Aging Management Further Com ponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-28 Steel external surfaces exposed Loss of material due External Surfaces No Consistent with NUREG-1801. to air -indoor uncontrolled to general corrosion Monitoring (external), condensation Except as noted below, the (external) or air outdoor \ External Surfaces Monitoring (external) Program is credited to manage loss of material for steel external surfaces in the steam and power conversion systems exposed to air-indoor uncontrolled (external), condensation (external) orair-outdoor r" (external). This includes the external surfaces of each CST not in contact with the tank foundation (refer to Item Number 3.4.1-20). /' This item is also applied to steel turbine casings exposed to air-indoor uncontrolled (external); and to steel internal surfaces exposed to air-indoor . uncontrolled (internal) where it has been demonstrated that the internal environment is the same as the external environment. The External Surfaces Monitoring Program is credited. A Note C is applied in these cases. Aging Management Review Results Page 3.4-28 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Further Item Component/Commodity Aging Effect/ Aging Management Evaluation Discussion Number Mechanism Programs evauainDs i 3.4.1-28 1 This item is also applied to air-(cont'd) water interfaces for steel components that penetrate the surface of the suppression pool (subject to alternate wetting and drying). The Supplemental Piping/Tank Inspection is credited to detect and characterize loss of material.

A Note E is applied.This item is also applied to steel bolting exposed to condensation (external). The Bolting Integrity Program is credited to manage loss of material. A Note E is applied.This item is also applied to steel piping from each CST that is enclosed in a guard pipe, which is evaluated as exposed to an air-indoor uncontrolled (external) environment. The guard pipe is buried. The Buried Piping and Tanks Inspection Program is credited to manage loss of material. A Note E is applied.Aging Management Review Results Page 3.4-29 January 2010 Aging Management Review Results Page 3.4-29 January 2010* *

• Columbia Generating Station license Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effectl Aging Management Further Number . ComponentlCommodity Mechanism Programs Evaluation Discussion Recommended 3.4.1-28 This item is also applied to air-(cont'd) water interfaces for steel components that penetrate the surface of the suppression pool (subject to alternate wetting and / , drying). The Supplemental PipinglTank Inspection is credited to detect and " characterize loss of material.

A Note E is applied. This item is also applied to steel bolting exposed to condensation "-(external). The Bolting Integrity Program is credited to manage loss of material. A Note E is applied. This item is also applied to steel piping from each CST that is -enclosed in a guard pipe, which is evaluated as exposed to an air-indoor uncontrolled (external) environment. The guard pipe is buried. The Buried Piping and -Tanks Inspection Program is credited to manage loss of material. A Note E is applied. Aging Management Review Results Page 3.4-29 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Further Item Component/Commodity Aging Effect/ Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-28 The temperatures of some steel (cont'd) external surfaces exposed to air-indoor uncontrolled (external) inthe Condensate (Auxiliary) System exceed 212 IF;therefore, loss of material is not an aging effect requiring management. A Note I is applied.3.4.1-29 Steel piping, piping components, Wall thinning due to Flow-Accelerated No Consistent with NUREG-1801. and piping elements exposed to flow-accelerated Corrosion steam or treated water corrosion The Flow-Accelerated Corrosion (FAC) Program is credited to manage loss of material (wall thinning) due to FAC for steel piping, piping components, and piping elements in the steam and power conversion systems exposed to steam or treated water, including treated water>60 C (140 OF).This item is also applied to the main condenser shell and the high-pressure turbine casing, which are exposed to treated water and steam, respectively. The Flow-Accelerated Corrosion (FAC) Program is credited. A Note C is applied.Aging Management Review Results Page 3.4-30 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effect/ Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-28 The temperatures of some steel (cont'd) external surfaces exposed to air--indoor uncontrolled (external) in the Condensate (Auxiliary) System exceed 212 of; therefore, loss of material is not an aging effect requiring management. A Note I is -applied. 3.4.1-29 Steel piping, piping components, Wall thinning due to Flow-Accelerated No Consistent with NUREG-1801. and piping elements exposed to flow-accelerated Corrosion steam or treated water corrosion The Flow-Accelerated Corrosion (FAC) Program is credited to manage loss of material (wall thinning) due to FAC for steel piping, piping components, and piping elements in the steam and power conversion systems exposed to steam or treated . water; including treated water >60 C (140 OF). -This item is also applied to the main condenser shell and the high-pressure turbine casing, , which are exposed to treated water and steam, respectively. The Flow-Accelerated Corrosion (FAC) Program is credited. A Note C is applied. Aging Management Review Results Page 3.4-30 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 e AFurther item Component/Commodity Aging Effect Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-30 Steel piping, piping components, Loss of material due Inspection of Internal No This item is applied to steel and piping elements exposed to to general, pitting, Surfaces in piping in the Condensate air outdoor (internal) or and crevice Miscellaneous Piping (Nuclear)

System exposed to air-condensation (internal) corrosion and Ducting outdoor (internal). The External Components Surfaces Monitoring Program is credited to manage loss of material. A Note E is applied.3.4.1-31 Steel heat exchanger Loss of material due Open-Cycle Cooling No Not applicable. components exposed to raw to general, pitting, Water System water crevice, galvanic, There are no steel heat and microbiologically exchanger components in the influenced corrosion, steam and power conversion and fouling systems exposed to raw water.3.4.1-32 Stainless steel and copper alloy Loss of material due Open-Cycle Cooling No Not applicable.piping, piping components, and to pitting, crevice, Water System piping elements exposed to raw and microbiologically There are no stainless steel or water influenced corrosion copper alloy piping, piping components, or piping elements in the steam and power conversion systems exposed to raw water.3.4.1-33 Stainless steel heat-exchanger Loss of material due Open-Cycle Cooling No Not applicable. components exposed to raw to pitting, crevice, Water System water and. microbiologically There are no stainless steel heat influenced corrosion, exchanger components in the and fouling steam and power conversion I_ I systems exposed to raw water.Aging Management Review Results Page 3.4-31 January 2010* .---... *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801

-Item Aging Effectl Aging Management Further' Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-30 Steel piping, piping components, Loss of material due Inspection of Internal No This item is applied to steel and piping eiements exposed to to general, pitting, Suifaces in piping in the Condensate air outdoor (internal) or and crevice Miscellaneous Piping (Nuclear) System exposed to air-condensation (internal) corrosion and Ducting outdoor (internal). The External Components Surfaces Monitoring Program is credited to manage loss of material. A NoteE is applied. 3.4.1-31 Steel heat exchanger Loss of material due Open-Cycle Cooling No Not applicable. components exposed to raw to general, pitting, Water System water crevice, galvanic, There are no steel heat and microbiologically exchanger components in the influenced corrosion, steam and power conversion and fouling systems exposed to raw water. 3.4.1-32 Stainless steel and copper alloy Loss of material due Open-Cycle Cooling No Not applicable. piping, piping components, and to pitting, crevice, Water System piping elements exposed to raw and microbiologically There are no stainless steel or . water influenced corrosion copper alloy piping, piping components, or piping elements . in the steam and power conversion systems exposed to raw water. 3.4.1-33 Stainless steel heat.exchanger Loss of material due Open-Cycle Cooling No Not applicable. components exposed to raw to pitting, crevice, Water System water and microbiologically There are no stainless steel heat influenced corrosion, exchanger components in the and fouling steam and power conversion systems exposed to raw water. Aging Management Review Results Page 3.4-31 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1' Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1 801 I Further Item Aging Effect/ Aging Management Evaluation Discussion Number Component/Commodity Mechanism Programs Recommended 3.4.1-34 Steel, stainless steel, and copper Reduction of heat Open-Cycle Cooling No Not applicable. alloy heat exchanger tubes transfer due to Water System exposed to raw water fouling There are no steel, stainless steel, or copper alloy heat exchanger tubes in the steamand power conversion systems exposed to raw water.3.4.1-35 Copper alloy >15% Zn piping, Loss of material due Selective Leaching of No Not applicable. piping components, and piping to selective leaching Materialselements exposed to closed There are no copper alloy cycle cooling water, raw water or >15% Zn piping, piping treated water components, or piping elements in the steam and power conversion systems exposed to closed cycle cooling water, raw water, or treated water.3.4.1-36 Gray cast iron piping, piping Loss of material due Selective Leaching of No Not applicable. components, and piping to selective leaching Materialselements exposed to soil, treated There are no gray cast iron water or raw water piping, piping components, or piping elements in the steam and power conversion systems exposed to soil, treated water, or raw water.Aging Management Review Results Page 3.4-32 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1" Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effect/ Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended " 3.4.1-34 Steel, stainless steel, and copper Reduction of heat Open-Cycle Cooling No Not applicable. alloy heat exchanger tubes transfer due to Water System exposed to raw water fouling There are no steel, stainless steel, or copper alloy heat exchanger tubes in the steam and power conversion systems exposed to raw water. 3.4.1-35 Copper alloy >15% Zn piping, Loss of material due Selective Leaching of No Not applicable. piping components, and piping to selective leaching Materials elements exposed to closed There are no copper alloy cycle cooling water, raw water or >15% Zn piping, piping treated water components, or piping elements in the steam and power conversion systems exposed to closed cycle cooling water, raw water, or treated water. 3.4.1-36 Gray cast iron piping, piping Loss of material due Selective Leaching of No Not applicable. components, and piping to selective leaching Materials elements exposed to soil, treated There are no gray cast iron water or raw water piping, piping components, or piping elements in the steam and power conversion systems exposed to soil, treated water, or -raw water. Aging Management Review Results Page 3.4-32 January 2010 _ * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item [ Aging Effect/ Aging Management Further Number Component/Commodity Aginfec tManiragmet Evaluation Discussion Number m n mMechanism Programs Recommended 3.4.1-37 Steel, stainless steel, and nickel- Loss of material due Water Chemistry INo Consistent with NUREG-1 801.based alloy piping, piping to pifting and crevice components, and piping corrosion The BWR Water Chemistry elements exposed to steam Program is credited to manage loss of material for steel and stainless steel piping, piping components, and piping elements in the steam and power conversion systems exposed to steam. There are no nickel-based alloy piping, piping components, and piping elements in the steam and power conversion systems exposed to steam.Additionally, the Chemistry Program Effectiveness Inspection is credited to verify the effectiveness of the BWR Water Chemistry Program. A Note E is applied.This item is applied to the high-pressure turbine casing (MS-DT-HP) exposed to steam. A NoteC is applied.3.4.1-38 PWR Only 3.4.1-39 PWR Only Aging Management Review Results Page 3.4-33 January 2010* *
• Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-37 Steel, stainless steel, and nickel-Loss of material due Water Chemistry No Consistent with NUREG-1801.

based alioy piping, piping to pitting and crevice -components, and piping corrosion The BWR Water Chemistry -elements exposed to steam Program is credited to manage loss of material for steel and stainless steel piping, piping components, and piping elements in the steam and power conversion systems exposed to steam. There are no alloy piping, piping components, and piping elements in the steam and power conversion systems exposed to steam. -/ Additionally, the Chemistry Program Effectiveness Inspection is credited to verify the effectiveness of the BWR Water Chemistry Program. A Note E is applied. This item is applied to the high-, pressure turbine casing (MS-DT-HP) exposed to steam. A Note C is applied. 3.4.1-38 PWR Only 3.4.1-39 PWROnly Aging Management Review Results Page 3.4-33 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Further Item Aging Effect/ Aging Management Evaluation Number ComponentlCbmmodity Mechanism Programs Econded Recommended 3.4.1-40 Glass piping elements exposed None None NA -No AEM or Not applicable.to air, lubricating oil, raw water, AMPand treated water There are no glass piping elements in the steam and power conversion systems exposed to air, lubricating oil, raw water, or treated water.3.4.1-41 Stainless steel, copper alloy, and None None NA -No AEM or Consistent with NUREG-1 801.nickel alloy piping, piping AMP components, and piping No aging effects were identified elements exposed to air -indoor for stainless steel or copper alloy uncontrolled (external) piping, piping components, or piping elements in the steam and power conversion systems'exposed to air-indoor uncontrolled (external). This item is also applied to stainless steel internal surfaces exposed to air-indoor uncontrolled (internal) where it has been demonstrated that the internal environment is the same as the external environment. This item is also applied to stainless steel bolting exposed to air-indoor uncontrolled (external). A Note C is applied.Aging Management Review Results Page 3.4-34 January 2010. Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item Aging Effectl Aging Management Further Number ComponentiCommodity Mechanism Programs ? Evaluation Discussion Recommended 3.4.1-40 Glass piping elements exposed None None NA -NoAEM or Not applicable. to air, lubricating oil, raw water, AMP and treated water There are no glass piping elements in the steam and power conversion systems exposed to air, lubricating oil, raw water, or treated water. 3.4.1-41 Stainless steel, copper alloy, and None None NA -NoAEM or Consistent with NUREG-1801. nickel alloy piping, piping AMP components, and piping No aging effects were identified elements exposed to air -indoor for stainless steel or copper alloy uncontrolled (external) piping, piping components, or piping elements in the steam and power conversion systems' exposed to air-indoor uncontrolled (external). This item is also applied to -stainless steel internal surfaces exposed to air-indoor uncontrolled (internal) where it has been demonstrated that the internal environment is the same as the external environment. This item is also applied to -stainless steel bolting exposed to air-indoor uncontrolled (external) .. A Note C is applied. Aging Management Results Page 3.4-34 January 2010 * *

• 0 Columbia Generating Station License Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Further Item Component/Commodity Aging Effect/ Aging Management Fuather Number Mechanism Programs Recommended 3.4.1-42 Steel piping, piping components, None None NA -No AEM or Not applicable.

-and piping elements exposed to AMP air -indoor controlled (external) There are no steel piping, piping components,-or piping elements in the steam and power conversion systems exposed to air-indoor controlled (external). All air-indoor environments were conservatively evaluated as uncontrolled environments. 3.4.1-43 Steel and stainless steel piping, None None NA -No AEM or Not applicable. piping components, and piping AMP elements in concrete There are no steel or stainless steel piping, piping components, or piping elements in the steam and power conversion systems embedded in concrete.3.4.1-44 Steel, stainless steel, aluminum, None None NA -No AEM or Consistent with NUREG-1 801.and copper alloy piping, piping AMP components, and piping This item is applied to aluminum elements exposed to gas and stainless steel piping components in steam and power conversion systems exposed to dried air. Dried air is not an environment in NUREG-1801 Chapter VIII for aluminum or stainless steel; however, gas is evaluated as an equivalent environment. Aging Management Review Results Page 3.4-35 January 2010* *

• Columbia Generating Station license Renewal Application Technical Information Table 3.4.1 Summary of Aging Management Programs for Steam and Power Conversion Systems Evaluated in Chapter VIII of NUREG-1801 Item . Aging Effectl Aging Management Further Com ponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.4.1-42 Steel piping, piping components, None None NA-NoAEM or Not applicable.

-and piping eiements exposed to AMP' air -indoor controlled (external) There are no steel piping, piping components,or piping elements in the steam and power conversion systems exposed to . air-indoor controlled (external) . All air-indoor environments were conservatively evaluated as uncontrolled environments. 3.4.1-43 Steel and stainless steel piping, None None NA-NoAEM or Not applicable. piping components, and piping AMP elements in concrete There are no steel or stainless steel piping, piping components, or piping elements in the steam and power conversion systems embedded in concrete. . 3.4.1-44 Steel, stainless steel, aluminum, None None NA-NoAEM or Consistent with NUREG-1801. and copper alloy piping, piping AMP components, and piping This item is applied to aluminum elements exposed to gas and stainless steel piping components in steam and power conversion systems exposed to dried air. Dried air is not an environment in NUREG-1801 Chapter VIII for aluminum or stainless steel; however, gas is evaluated as an equivalent environment. Aging Management Review Results Page 3.4-35 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-1 Aging Management Review Results -Auxiliary Steam System Aging Effect NUREG-Row C Fntinds) Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Man age meng Program Volume I Item Management 2 Item Air-indoor Pressure Loss of 3.4.1-1 Bolting Pressure Steel uncontrolled Bolting Integrity VIII.H-4 B boundary(Eernal) material 22 Pressure Air-indoor Loss of 3.4.1-2 Bolting boundary Steel uncontrolled Losslofd Bolting Integrity VIII.H-5 3. B (External) pre-load 22 Structural Air-indoor Loss of 3.4.1-3 Bolting integrity Steel uncontrolled Lossrofl Bolting Integrity VIII.H-4 B (External) material 22 Structural Air-indoor Loss of 3.4.1-4 Bolting Steel uncontrolled Bolting Integrity VIII.H-5 B integrity (External) pre-load 22 5 Bolting Structural Steel Air-outdoor Loss of Bolting Integrity VIII.H-1 3.4.1- B integrity (External) material 22 Structural Steel Air-outdoor Loss of integrity (External) pre-load Air-indoor 7 i Structural Steel uncontrolled Loss of External Surfaces VIII.H-7 3.4.1- C integrity (Internal) material Monitoring 28 0404 Structural Steam Loss of BWR Water 3.4.1-iping integrity (Internal) material Chemistry 02 Structural Steam Loss of Chemistry Program 3.4.1-9 Piping y Steel Effectiveness VIII.C-4 A integrity (internal) material 02 Aging Management Review Results Page 3.4-36 January 2010 Table 3.4.2-1 Row Component Intended No. Type -Function(s) Pressure 1 Bolting boundary Pressure 2 Bolting boundary Structural 3 Bolting integrity Structural 4 Bolting integrity 5 Bolting Structural integrity 6 Bolting Structural integrity Structural 7 Piping integrity 8 Piping Structural integrity Structural 9 Piping integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Auxiliary Steam System j Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes Program Volume 1 Item Management 2 Item Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting Integrity VIILH-4 22 B (External)

Air-indoor Loss of 3.4.1-Steel uncontrolled pre-load Bolting Integrity VIILH-5 22 B (External) Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting Integrity VIILH-4 22 B (External) Air-indoor Loss of 3.4.1-Steel uncontrolled pre-load Bolting Integrity VIII.H-5 22 B (External) Steel Air-outdoor Loss of Bolting Integrity VIII.H-1 3.4.1-B (External) material 22 Steel Air-outdoor Loss of Bolting Integrity N/A N/A H (External) pre-load Air-indoor Loss of External Surfaces 3.4.1-C Steel uncontrolled material Monitoring VIILH-7 28 0404 (Internal) Steel Steam Loss of BWRWater VIILC-4 3.4.1-A (Internal) material Chemistry 02 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIILC-4 02 A Inspection Page 3.4-36 January 2010 *

• S Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-1 Aging Management Review Results -Auxiliary Steam System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s)

Management Program Volume 1 Item 2 Item I t Piping Structural Steel Steam Loss of Flow-Accelerated I v.C-5 3.4.1- A 1i en gri .Y, r al) material Corrosion (FAC) III. 29 A" .....e .. n Corrosion , 29 Structural Air-indoor Loss of External Surfaces 3.4.1-11 Piping integrity (External) material Monitoring 28 12 Piping Structural Steel Air-outdoor Loss of External Surfaces VIlI.H-8 3.4.1- A integrity (External) material Monitoring 28 Structural Steam Loss of BWR Water 3.4.1-13 Strainer Body integrity Steel (Internal) material Chemistry VIII.C-4 02 Structural Steam Loss of Chemistry Program 3.4.1-14 Strainer Body integructy Steel Effectiveness VIII.C-4 02A 14 Syintegrity (Internal) material inspection 02 15 Strainer Body Structural Steam Loss of Flow-Accelerated 3.4.1- A integrity (Internal) material Corrosion (FAC) 29 Structural Air-indoor Loss of External Surfaces 3.4.1-1StruaineuBod Steel uncontrolled VIII.H-7 A integrity uncontrolle material Monitoring 28________(External) 17 Strainer Body Structural Steel Air-outdoor Loss of External Surfaces VIII.H-8 3.4.1- A integrity (External) material Monitoring 28 18 Trap Body Structural Gray Cast Steam Loss of BWR Water VIII.C-4 3.4.1- A integrity Iron (Internal) material Chemistry 02 Aging Management Review Results Page 3.4-37 January 2010* Table 3.4.2-1 -Row Component Intended No. Type Function(s) 10 Piping Structural integiity Structural 11 Piping integrity 12 Piping Structural integrity 13 Strainer Body Structural integrity Structural 14 Strainer Body integrity 15 Strainer Body Structural integrity Structural 16 Strainer Body integrity . 17 Strainer Body Structural integrity 18 Trap Body Structural integrity. Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Auxiliary Steam System -NUREG-Aging Effect Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Steel Steam Loss of Flow-Accelerated VIILC-5 3.4.1-A (lnterna!)

material Corrosion (FAC) 29 Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIILH-7 28 A (External) Steel Air-outdoor Loss of External Surfaces VIILH-8 3.4.1-A (External) material Monitoring 28 Steel Steam Loss of BWRWater VIILC-4 3.4.1-A (Internal) material Chemistry 02 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIILC-4 02 A Inspection Steel Steam Loss of Flow-Accelerated VIILC-5 3.4.1-A (Internal) material Corrosion (FAC) 29 Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIILH-7 28 A (External) Steel Air-outdoor Loss of External Surfaces VIII.H-8 3.4.1-A (External) material Monitoring 28 Gray Cast Steam Loss of BWRWater VII L C-4 3.4.1-A Iron -(Internal) material Chemistry 02 Page 3.4-37 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-1 Aging Management Review Results -Auxiliary Steam System TAging Effect NUREG-Row Component Intended Material Environment Requiring1801 Table No. Type Function(s) Management Program Volume 1 Item M e2 Item Structural Gray Cast Steam Loss of Chemistry Program 3.4.1-19 Trap Body integrity Iron (Internal) material Effectiveness VIII.C-4 02A______Inspection 20 Trap Body Structural Gray Cast Steam Loss of Flow-Accelerated VIII.C-5 3.4.1-integrity Iron (Internal) material Corrosion (FAC) 29 A 21 Trap Body Structural Gray Cast Steam Loss of Selective Leaching N/A N/A G integrity Iron (Internal) material Inspection Air-indoor Structural Gray Cast Andor Loss of External Surfaces 3.4.1-oilntegerity Iron ( terold material Monitoring VIII.H-7 28 A 22 T ap B dy ntegity ron(External) 23 T Structural Gray Cast Air-outdoor Loss of External Surfaces 3.4.1-rap Body integrity Iron (External) material Monitoring VIII.H-8 28 A 24 Trap Body Structural Ste Air-outdoor Loss of External Surfaces VIIIH8 3.4.1- A integrity ee (External) material Monitoring 28 Structural Steam Loss of BWR Water 3.4.1-integrity Steel (Internal) material Chemistry 02 A Structural Steam Loss of Chemistry Program 3.4.1-26 Trap Body integrity Steel (Internal) material Effectiveness VIII.C-4 02A Inspection 27 Trap Body Structural Steam Loss of Flow-Accelerated VIII.C5 3.4.1-integrity (Internal) material Corrosion (FAC) 29 Aging Management Review Results Page 3.4-38 January 2010 Table 3.4.2-1 Row Component Intended No. Type Function(s) Structural 19 Trap Body* integrity 20 Trap Body Structural integrity 21 Trap Body Structural integrity Structural 22 Trap Body integrity 23 Trap Body Structural integrity 24 Trap Body -Structural integrity 25 Trap Body Structural integrity Structural 26 Trap Body integrity 27 Trap Body Structural integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Auxiliary Steam System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Gray Cast Steam Loss of Chemistry Program 3.4.1-Effectiveness VIII.C-4 A Iron (Internal) material Inspection 02 Gray Cast Steam Loss of Flow-Accelerated VIII.C-5 3.4.1-A Iron (Internal) material Corrosion (FAC) 29 Gray Cast Steam Loss of Selective Leaching N/A N/A G Iron (Internal) material Inspection Gray Cast Air-indoor Loss of External Surfaces 3.4.1-Iron uncontrolled material Monitoring VII I. H-7 28 A (External) , Gray Cast Air-outdoor Loss of External Surfaces VIII.H-8 3.4.1-A Iron (External) material Monitoring 28 Steel Air-outdoor Loss of External Surfaces VIII.H-8 3.4.1-A (External) material Monitoring 28 Steel Steam Loss of BWRWater VIII.C-4 . 3.4.1-A (Internal) material Chemistry 02 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VII I. C-4 02 A Inspection Steel Steam Loss of Flow-Accelerated VIII.C-5 3.4.1-A (Internal) material Corrosion (FAC) . 29 Page 3.4-38 January 2010 *
• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-1 Aging Management Review Results -Auxiliary Steam System Aging Effect NUREG-N. Tp Futin)IMAgnagEmfent AgProgramnVolmen10 TaItem Nte Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s)

Management Program Volume I Item 2 Item A ir-noo StutrlAir-indoor Loss of External Surfaces 3.4.1-28 Trap Body Steel uncontrolled s onitorinf VIII.H-7 34 A integrity (External)' 28 29 Tubing Structural Stainless Steam BWR Water 3.4.1- A integrity Steel (Internal) Cracking Chemistry VIII.B2-1 13 Structural Stainless Steam Chemistry Program 3.4.1-30 Tubing integrity Steel (internal) Cracking Effectiveness VIII.B2-1 13 A Inspection Structural Stainless Steam Loss of BWR Water 3.4.1-31 Tubing integrity Steel (Internal) material Chemistry VIII.B2-2 37A Structural Stainless Steam Loss of Chemistry Program 3.4.1- E 32 Tubing integrity Steel (Internal) material Insection Inspection Air-indoor 3.4.1-33 Tubing Structural Stainless uncontrolled None None VIII.I-10 A 33 T gintegrity Steel (External) 41 34 Valve Body Pressure Steel Steam Loss of BWR Water VIII.C-4 3.4.1- A boundary (Internal) material Chemistry 02 Pressure Steam Loss of Chemistry Program 3.4.1- A Steel (Internal) material Effectiveness VIII.C-4 02 35 ValveBody boundary (nenInspection 36 Valve Bd Pressure Ste Steam Loss of Flow-Accelerated VlllC5 3.4.1- A oy boundary (Internal) material Corrosion (FAC) 29 Aging Management Review Results page 3.4-39 January 2010* Table 3.4.2-1 Row Component IntencJed No. Type Function(s) Structural 28 Trap Body integrity 29 Tubing Structural integrity Structural 30 Tubing integrity 31 Tubing Structural integrity 32 Tubing integrity Structural 33 Tubing integrity 34 Valve Body Pressure boundary Pressure 35 Valve Body boundary 36 Valve Body Pressure boundary Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information . Aging Management Review Results -Auxiliary Steam System -NUREG-Aging Effect Aging Management 1801 Table Material Environment Requiring Notes Management Program Volume 1 Item 2 Item Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled materia! Monitoring VIII.H-7 28 A (Externair Stainless Steam Cracking ,BWRWater VIII.B2-1 3A1-". A Steel (Internal)

Chemistry 13 Stainless Steam Chemistry Program 3.4.1-Steel (Internal) Cracking Effectiveness VIII.B2-1 13 A Inspection . Stainless Steam Loss of BWRWater VIII.B2-2 3.4.1-A Steel (Internal) material Chemistry 37 Stainless Steam Loss of Chemistry Program 3.4.1-Effectiveness VIII.B2-2 E Steel (Internal) material Inspection

• 37 Stainless Air-indoor 3.4.1-Steel uncontrolled None None VII 1.1-1 0 41 A (External) . " Steel Steam Loss of BWRWater VII I. C-4 3.4.1-A (Internal) material Chemistry 02 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VII I. C-4 . 02 A Inspection Steel Steam Loss of Flow-Accelerated VIII.C-5 3.4.1-A (Internal) material Corrosion (FAC) 29 Page 3.4-39 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-1 Aging Management Review Results -Auxiliary Steam System-NUREG-Row Component Intended Aging Effect T Material Environment -Requiring Aging Management 1801 Table Notes No. Type Function(s)

Management Program Volume 1 Item 2 Item Pressure Loss of External Surfaces 3.4.1-37 Valve Body boundary Steel uncontrolled VIII.H-7 A (External) material Monitoring Structural Steam Loss of BWR Water 3.4.1-38 Valve Body integrity Steel (Internal) material Chemistry VIII.C-4 02 A Structural Steam Loss of Chemistry Program 3.4.1-39 Valve Body integrity Steel (Internal) material Effectiveness VIII.C-4 02 A___________Inspection 40 Valve Body Structural Stee Steam Loss of Flow-Accelerated VIIIC5 3.4.1- A integrity (Internal) material Corrosion (FAC) 29 Structural Air-indoor Loss of External Surfaces 3.4.1-41tValveuBol Steel uncontrolled -VIII.H-7 A integrity unotrolle material Monitoring 28___________(External) 42 Valve Bd Structural Steel Air-outdoor Loss of External Surfaces 3.4.1-4 a integrity (External) material Monitoring 28 Aging Management Review Results Page 3.4-40 January 2010 Table 3.4.2-1 Row Component Intended No. Type Function(s) Pressure 37 Valve Body boundary 38 Valve Body Structural integrity Structural 39 Valve Body integrity 40 Valve Body Structural integrity Structural 41 Valve Body integrity 42 Valve Body Structural integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Auxiliary Steam System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIILH-7 28 A (External)

Steel Steam Loss of BWRWater VIILC-4 3.4.1-A (Internal) material Chemistry 02 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIILC-4 02 A Inspection Steel Steam Loss of Flow-Accelerated VIILC-5 3.4.1-A (Internal) material Corrosion (FAC) . 29 Air-indoor Losspf External Surfaces 3.4.1-Steel uncontrolled VIILH-7 A (External) material Monitoring 28 Steel Air-outdoor Loss of External Surfaces VIILH-8 3.4.1-A (External) material Monitoring 28 Page 3.4-40 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.4.2-2 Aging Management Review Results -Condensate (Auxiliary)

System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program Volume I Item 2 Item Structurai Air-indoor .I 3.4.1-n 1 Bolting integrity Steel uncontrolled None "None VIii.H-4 220 6 (External) Structural Air-indoor Loss of 3.4.1-Bolting Steel uncontrolled terial Bolting Integrity VIII.H-4 3.. B B ntegrity (External) material 22 Structural Air-indoor Loss of 3.4.1-Bolting integrity Steel uncontrolled Bolting Integrity VIII.H-5 22B (External) pre-load_22 4 Bolting Structural Steel Air-outdoor Loss of Bolting Integrity VIII.H-1 3.4.1- B integrity (External) material 22 5 Bolting iStructural S Airoutdoor Loss of Bolting Integrity N/A N/A H Sintegrity Steel (External) pre-load Condenser Structural Air-indoor Loss of External Surfaces 3.4.1- C 6 Steel uncontrolled VIII. H-7 (CO-CU-1) integrity (internal) material Monitoring 28 0404 7 Condenser Structural Steel Air-indoor Loss of External Surfaces VIII.H-7 3.4.1- A(CO-CU-1) integrity uncontrolled material Monitoring -28 Air-indoor 8 Structural Steel uncontrol Loss of External Surfaces 341- C Piping integrity 28elunot0404VII.-(Internal) material Monitoring 28 0404 Structural Air-indoor Loss of External Surfaces 3.4.1-Piping integrity Steel uncontrolled material Monitoring 28 (External) material Moioig2 Aging Management Review Results Page 3.4-41 January 2010* Table 3.4.2-2 Row Component Intended No. Type Function(s) Structurai 1 Bolting integrity Structural 2 Bolting integrity Structural 3 Bolting integrity 4 Bolting Structural integrity 5 Bolting Structural integrity Condenser Structural 6 (CO-CU-1) integrity Condenser Structural 7 (CO-CU-1) integrity Structural 8 Piping integrity Structural 9 Piping integrity Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Auxiliary)

System Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes Management Program Volume* 1 Item 2 Item Air-indoor 3.4.1.;. I Steel uncontrolled None' . None VIII.H-4 22 0406 (External) Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting Integrity VIILH-4 22 B (External) Air-indoor Loss of 3.4.1-Steel uncontrolled pre-load Bolting Integrity VIILH-5 22 B (External) Steel Air-outdoor Loss of Bolting Integrity VIILH-1 3.4.1-B (External) material 22 Steel Air'"Outdoor Loss of Bolting Integrity N/A N/A H (EX!ernal) pre-load Loss of External Surfaces 3.4.1-C Steel uncontrolled VIILH-7 (Internal) material Monitoring 28 . 0404 Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material MonitOring VIILH-7 28 A (External) Air-indoor Loss of External Surfaces 3.4.1-C Steel uncontrolled material Monitoring VII I. H-7 28 0404 (Internal) Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIILH-7 28 A (External) Page 3.4-41 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-2 Aging Management Review Results -Condensate (Auxiliary) System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Maeil Evromn aeurnagemn Program Volume I Item Noe 2 Item Treated 10 Piping Structural Steel water > 60 °C Loss of BWR Water VlllE-33 3.4.1- A integrity (140 °F) material Chemistry 04 (Internal)

• • Treated Structural water > 60d C Loss of Chemistry Program 3.4.1-11 Piping iCtoSteel( Effectiveness VIII.E-33 04 A Snteructurl Ste (140 'F) material Inpcin0 (Internal)

Inspection Air-indoor Structural Ai-nor3.4.1-1 12 Piping integrity Steel uncontrolled None None VIII.H-7 3.4.1-(External) 28 0406 13 Pi Structural St Air-outdoor Loss of External Surfaces VlllH8 3.4.1- A integrity (External) material Monitoring 28 14 Pump Casing Structural Gray Cast Air-indoor Pump uncontrolled Loss of External Surfaces VIII.H-7 3.4.1- C (CO-P-4) integrity Iron (Internal) material Monitoring 28 0404 (internal)r 15 Pump Casing Structural Gray Cast Air-indoor Loss of External Surfaces VIII.H-7 3.4.1- A (CO-P-4) integrity Iron (External) material Monitoring 28 Treated 16 Valve Body Structural Steel water> 60 C Loss of BWR Water VIII.E-33 3.4.1-integrity (140 °F) material Chemistry 04 A (Internal) Treated Chemistry Program 17 Valve Body Structural Steel water > 60 °C Loss of Effectiveness VIII.E-33 341-integrity (140 °F) material 04" (Internal) Inspection Aging Management Review Results Page 3.4-42 January 2010 Table 3.4.2-2 Row Component Intended No. Type Function(s) 10 Piping Structural integrity Structural 11 Piping integrity Structural 12 Piping integrity 13 Piping Structural integrity Pump Casing Structural 14 (CO-P-4) integrity Pump Casing Structural 15 (CO-P-4) integrity , Structural 16 Valve Body integrity Structural 17 Valve Body integrity .. , Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Auxiliary)

System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Treated Steel water> 60°C Loss of BWRWater VIILE-33 3.4.1-A (140 OF) material Chemistry 04 (Internal) Treated -water> 60°C Loss of Chemistry Program 3.4.1-Steel (140 OF) material Effectiveness VIILE-33 04 A (Internal) -Inspection Air-indoor 3.4.1-I Steel uncontrolled None None VIILH-7 28 0406 (External) Steel Air-outdoor Loss of External Surfaces VIILH-8 3.4.1-A (External) . material Monitoring 28 Gray Cast Air-indoor Loss of External Surfaces 3.4.1-C uncontrolled VIILH-7 Iron (Internal) material Monitoring 28 0404 Gray Cast Air-indoor Loss of External Surfaces 3.4.1-uncontrolled VIILH-7 A Iron (External) material Monitoring 28 Treated water> 60°C Loss of BWRWater 3.4.1-Steel (140 OF) material Chemistry VIILE-33 04 r A (Internal) Treated Chemistry Program water> 60°C Loss of 3.4.1-Steel (140 OF) material Effectiveness VIILE-33 04 A (Internal) Inspection Page 3.4-42 . Ja*nuary 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-2 Aging Management Review Results -Condensate (Auxiliary)

System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program Volume I Item 2 Item Trca Air-indoor 3 Sintegrity Steel uncontrolled None None VIII.H-7 28 0406 18 Veoy inert (External) Air-indoor Structural Stelincor Loss of External Surfaces 3.4.1- C 19 Valve Body itgty Steel uncontrolled VIII.H-7.integrity (Internal) material Monitoring 28 0404 Structural Air-indoor Loss of External Surfaces 3.4.1-20 Valve Body integrity Steel uncontrolled mtraMoirngVIII.1--7 28A (External) material Monitoring 28 Aging Management Review Results Page 3.4-43 January 2010* Table 3.4.2-2 Row Component Intended No. Type Function{s) Structural 18 Valve Body integrity Structural 19 Valve Body integrity Structural 20 Valve Body integrity Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Auxiliary)

System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Air-indoor 3.4.1-I Steel uncontrolled None None VII I. H-7 28* 0406 (External) Air-indoor Loss of External Surfaces 3.4.1-C Steel uncontrolled material Monitoring VIII.H-7* 28 0404 (Internal) '(. Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VII I. H-7 28 A (External) ?age 3.4-43 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear) System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program Volume I Item 2 Item Air-ndooPressure Loss of 3.4.1-SBolting r Steel uncontrolled Bolting Integri2 VIII.H-4 B boundary (External)2 (External) Iaeil2 Pressure Air-indoor Loss of 3.4.1-2 Bolting boundary Steel uncontrolled Bolting Integrity VIII.H-5 B (External) pre-load B3 Pressure Air-outdoor H 3 Bolting boundary Steel (External) Cracking Bolting Integrity N/A N/A 0407 Pressure Air-outdoor Loss of 3.4.1-4 Bolting boundary Steel (External) material Bolting Integrity VIl.H1 22 B Pressure Air-outdoor Loss of 5 Bolting boundary Steel (External) pre-load Bolting Integrity N/A N/A H 6 Bolting Pressure Condensation Cracking Bolting Integrity N/A N/A H boundary Steel (External) C Pressure Condensation Loss of 3.4.1-Bolting boundary Steel (External) material Bolting Integrity VIIIH-1 28 E Bolting bPressure Condensation Loss of 8 boundary Steel (External) pre-load Bolting Integrity N/A N/A H Air-indoor Bolting Structural Steel uncontrolled oss of Bolting Integrity VIII.H-4 3.4.1- B integrity (External) material 22 Aging Management Review Results Page 3.4-44 January 2010 Table 3.4.2-3 Row Component Intended No. Type Function(s) Pressure 1 Bolting boundary Pressure 2 Bolting boundary 3 Bolting Pressure boundary Pressure 4 Bolting boundary 5 Bolting Pressure boundary 6 Bolting Pressure boundary 7 Bolting Pressure boundary 8 Bolting Pressure , boundary Structural 9 Bolting integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting IntegritY VIILH-4 22 B (External) Air-indoor Loss of 3.4.1-Steel uncontrolled pre-load Bolting Integrity VIILH-5 22 B (External) Steel Air-outdoor Cracking Bolting Integrity N/A N/A H (External) 0407 r Air-outdoor Loss of 3.4.1-Steel (External) material Bolting Integrity VIILH-1 22 B Steel Air-outdoor Loss of Bolting Integrity N/A N/A H (External) pre-load Steel Condensation Cracking Bolting Integrity N/A N/A H (External) Steel Condensation Loss of Bolting Integrity VIILH-10 3.4.1-E (External) material 28 Steel Condensation Loss of Bolting Integrity N/A N/A H (External) pre-load Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting Integrity VIII.H-4 22 B (External) Page 3.4-44 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear)

System NUREG-Row Component Intended Aging Effect Aging Management 1801 Table No. Type Function(s) Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Structural ir-indoor Loss of 34.1-ieiBolting t .... , Steel uncontrolled pre-lad Bolting Integrity VIII.H5 Structural Condensation 11 Bolting Strutu Steel Condenato Cracking Bolting Integrity N/A N/A H integrity (External) 12 BligStructural SelCondensation Loss of Botn nert VI3.4H--12 Bligintegrity Ste Etra) material BligItrtyVI.-0 28 13 Bolting Structural Steel Condensation Loss of Bolting Integrity N/A N/A H integrity (External) pre-load Heat Exchanger Pressure Moist air Loss of Supplemental 14 (shell), Main Steel (Internal) material Piping/Tank N/A N/A G Condenser boundary Inspection COND-HX-9 Heat Exchanger Pressure Treated water Loss of Flow-Accelerated VIII.E-35 3.4.1- C 15 (shell), M ain 29e VI .E 3 Condenser boundary (Internal) material Corrosion (FAC) 29 COND-HX-9 Heat Exchanger Pressure Treated water Loss of BWR Water 3.4.1-16 (shell), Main Steel VIII.E-7 05A Condenser boundary (Internal) material Chemistry COND-HX-9 Aging Management Review Results Page 3.4-45 January 2010 Aging Management Review Results Page 3.4-45 Janubary 2010* Table 3.4.2-3 Row Component Intended No. Type* Function(s) , Structural 10 Bolting integiity 11 Bolting Structural integrity 12 Bolting Structural integrity 13 Bolting Structural integrity Heat Exchanger Pressure 14 (shell), Main boundary Condenser COND-HX-9 Heat Exchanger Pressure 15 (shell), Main boundary Condenser COND-HX-9 Heat Exchanger Pressure 16 (shell), Main boundary Condenser COND-HX-9 Aging Management ReviewResults

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management -2 Item Air-indoor Loss of 3.4.1-Steel uncontrolled pre-load Bolting Integrity VIII.H-5 22 B (External) Steel Condensation Cracking Bolting Integrity N/A N/A H (External) Steel Condensation Loss of Bolting Integrity VIII.H-10 8.4.1-E (External) material 28 Steel Condensation Loss of Bolting Integrity N/A N/A H (External) pre-load Moist air Loss of Supplemental Steel . (Internal) material PipinglTank N/A N/A G Inspection Treated water Loss of Flow-Accelerated 3.4.1-Steel (Internal) material Corrosion (FAC) VIII.E-35 29 C -Treated water Loss of BWRWater 3.4.1-Steel (Internal) material Chemistry VIII.E-7 05 A Page 3.4-45 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear) System dAging Effect NUREG-Now yponen IFnctioning Aging Management 1801 Table Notes No. Type Function(s) Mang Program Volume 1 Item Management 2 Item Heat Exchanger Pressure Treated water Loss of Chemistry Program 3.4.1-17 (shell), Main Presure Steel Tetednate LEffectiveness VIII.E-7 05A Condenser boundary (Internal) material Inspection COND-HX-9 Heat Exchanger Pressure Air-indoor Loss of External Surfaces 3.4.1-18 (shell), Main Ste notold Ls f Etra ufcs VI.- ..- A Condenser boundary Steel uncontrolled material Monitoring VIII.H-7 28 COND-HX-9 19 Orifice Pressure Stainless Treated water Loss of BWR Water VIII.E-29 3.4.1- A boundary Steel (Internal) material Chemistry 16 20 Orifice Pressure Stainless Treated water Loss of Chemistry Program 3.4.1 A Effectiveness VIII.E-29 3416 boundary Steel (Internal) material Inspection 16 Pressure Stainless Air-indoor 3.4.1-21 Orifice boundary Steel uncontrolled None None VIII.1-10 41 A (External) 41 22 Orifice Pressure Stainless Condensation Loss of External Surfaces N/A N/A G boundary Steel (External) material Monitoring 23 Orifice Structural Stainless Treated water Loss of BWR Water VIII.E-29 3.4.1- A integrity Steel (Internal) material Chemistry 16 Structural Stainless Treated water Loss of Chemistry Program integrity Steel (Internal) material Effiecticteon VIII.E-29 16 A AgingManaementReviw Reslts age 34-46Januay201 Aging Management Review Results Page 3.4-46 I January 2010 Table 3.4.2-3 Row Component Intended "No. Type Function(s) Heat Exchanger Pressure 17 (shell), Main boundary -Condenser COND-HX-9 Heat Exchanger Pressure 18 (shell), Main boundary Condenser COND-HX-9 19 Orifice Pressure boundary Pressure 20 Orifice boundary Pressure 21 Orifice boundary 22 Orifice Pressure boundary 23 Orifice Structural integrity Structural 24 Orifice integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Treated water Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.E-7 05 A Inspection Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VII I. H-7 28 A (External) Stainless Treated water Loss of BWRWater VII I. E-29 3.4.1-A Steel (Internal) material Chemistry 16 Stainless Treated water Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VII I. E-29 16 A Inspection Stainless Air-indoor 3.4.1-Steel uncontrolled None None VIIU-10 41 A (External) Stainless Condensation Loss of External Surfaces N/A N/A G Steel (External) material Monitoring Stainless Treated water Loss of BWRWater VIII.E-29 3.4.1-A Steel (Internal) material Chemistry 16 ' Stainless Treated water Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VII I. E-29 16 A Inspection Page 3.4-46 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program Volume I Item 2 Item SStructural, Stainless Ai-n r34.41-1 1 1 ~~Air-indoor 1 2ie 25 Orifice St uncontrolled None None VIII.l-10 A integrity Steel (External) 41 26 Orifice Structural Stainless Condensation Loss of External Surfaces N/A N/A G integrity Steel (External) material Monitoring 27 Orifice Thrn Stainless Treated water Loss of BWR Water VIII.E-29 3.4.1- A roing Steel (Internal) material Chemistry 16 Stainless Treated water Loss of Chemistry Program 3.4.1- A 28 Orifice Throttling Steel (Internal) material Effectiveness VIII.E-29 16 2Inspection. Pressure Air-indoor Loss of External Surfaces 3.4.1- C 29 Piping boundary Steel uncontrolled material Monitoring VIII.H-7 28 0404 (Internal) mea Ming 0404 Pressure Air-outdoor Loss of External Surfaces 3.4.1-boundary Steel (Internal) material Monitoring .30 31 Piping Pressure Treated water Loss of BWR Water VIII.E-33 3.4.1- A boundary Steel (Internal) material Chemistry 04 Pressure Treated water Loss of Chemistry Program 3.4.1- A 3sunary Steel (Effectiveness VIII.E-33 04 32 Piping boundary (Internal) material Inspection Air-indoor Pressure Steel uncontrolled Loss of Buried Piping and VIII.H-7 284 040E 33 Piping boundary -(External) material Tanks Inspection 28 0408 Aging Management Review Results Page 3.4-47 January 2010 Table 3.4.2-3 Row Component Intended . No. Type Function(s) Structural 25 Orifice integiity 26 Orifice Structural integrity 27 Orifice Throttling 28 Orifice Throttling Pressure 29 Piping boundary , 30 Piping Pressure boundary 31 Piping Pressure boundary Pressure 32 Piping boundary Pressure 33 Piping boundary Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes Management Program Volume 1 Item 2 Jtem Stainless Air-indoor 3.4.1-uncontrolled None None VIIU-10 A Steel (External) 41 Stainless Condensation Loss of External Surfaces N/A N/A G Steel (External) material Monitoring Stainless Treated water Loss of BWRWater VII I. E-29 3.4.1-A Steel (lnternC\ll) material Chemistry 16 Stainless Treated water Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VII I. E-29 16 A Inspection. Air-indoor Loss of External Surfaces 3.4.1-C Steel uncontrolled material Monitoring VIII.H-7 28 0404 (Internal) Steel Air-outdoor Loss of External Surfaces VIII.B1-6 3.4.1-E (Internal) materiid Monitoring .30 Steel Treated water Loss of BWRWater VIII.E-33 3.4.1-A (Internal) material Chemistry 04 Chemistry Program , Treated water Loss of 3.4.1-Steel (Internal) material Effectiveness VIII.E-33 04 A Inspection Air-indoor Loss of Buried Piping and 3.4.1-E Steel uncontrolled VII I. H-7 (External) material Tanks Inspection 28 0408 Page 3.4-47 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear) System wAging Effect NUREG-Row Component Intended Material Environment Requiring1801 Table No. Type Function(s) Mong Program Volume I Item Management 2 Item Pressure Air-indoor Loss of External Surfaces 3.4.1-34 Piping boundary Steel uncontrolled material Monitoring 28 (External) 35 Pi Pressure *Air-outdoor Loss of External Surfaces VIII.H-8 3.4.1- A boundary (External) material Monitoring 28 36 Piping Pressure Steel Condensation Loss of External Surfaces VIII.H.10 3.4.1- A boundary (External) material Monitoring 28 37 Piping Pressure Soil Loss of Buried Piping and 3.4.1-boundary (External) material Tanks Inspection 11 Air-indoor 38 Piping Structural Stainless uncontrolled None None VIII.I-10 41- 0410 integrity Steel (Internal) 41_0410 39 Piping Structural Stainless Treated water Loss of BWR Water VIII.E-29 3.4:1- A integrity Steel (Internal) material Chemistry 16 Structural Stainless Treated water Loss of Chemistry Program 3.4.1-40 Piping integrity Steel (Internal) material Effectiveness VIII.E-29 16 A integrity Steel (internal) mateInspection 16 Structural Stainless Air-indoor 3.4.1-41 Piping uncontrolled None None VIII-.-10 A 41 P gintegrity Steel (External) 41 Structural Stainless Condensation Loss of External Surfaces N/A N/A G integrity Steel (External) material Monitoring Agin Maageent eviw Rsult Pae 34-48Janary201 Aging Management Review Results Page 3.4-48 January 2010.Table 3.4.2-3 Row Component Intended No. o Type Function(s) Pressure 34 Piping boundary 35 Piping Pressure boundary 36 Piping Pressure boundary 37 Piping Pressure boundary Structural 38 Piping integrity 39 Piping Structural integrity Structural 40 Piping integrity Structural 41 Piping integrity 42 Piping Structural integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VII I. H-7 28 A" (External) Steel Air-outdoor Loss of External Surfaces VIII.H-8 3.4.1-A (External) material Monitoring 28 Steel Condensation Loss of External Surfaces VIII.H-10 3.4.1-A (EXternal) material Monitoring 28 Steel Soil Loss of Buried Piping and VIII.E-1 3.4.1-A (External) material Tanks Inspection 11 Stainless Air-indoor 3.4.1-A uncontrolled None None VIII.I-10 Steel (Internal) 41 0410 Stainless Treated water o toss of BWRWater VIII.E-29 A Steel (Internal) material Chemistry 16 Stainless Treated water Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.E-29 16 A Inspection Stainless Air-indoor 3.4.1-Steel uncontrolled None None VIILI-10 41 A (External) Stainless Condensation Loss of External Surfaces N/A N/A G Steel (External) material Monitoring Page 3.4-48 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-RowMaterial Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program IVolume Item Manageent 12 Item Structural Air-indoor Loss of External Surfaces 3.4.1- C 43 Piping , Steel uncontrolled merial Monitoring VIII.H-7 28 ine riy(internal) ............ ..... ..Structural Treated water Loss of BWR Water 3.4.1-44 Piping integrity Steel (Internal) material Chemistry VIII.E-33 04 A Structural Treated water Loss of Chemistry Program 3.4.1-45teel(Internal) material Effectiveness VIII.E-33 4A 4integrity Inspection 04 Air-indoor 46 Piping Structural Loss of External Surfaces 3.4.1: 46tegring Steel uncontrolled VIII.H-7 A integrity trl material Monitoring 28 (External) Structural Condensation Loss of External Surfaces 3.4.1-47 Piping integrity Steel (External) material Monitoring VIII.H-10 28 A Cast Pump Casing Structural Austenitic Treated water Loss of BWR Water VIII.E-29 3.4.1- A 48 (COND-P-3, integrity Stainless (Internal) material Chemistry 16 4; 5) Steel Cast Pump Casing Chemistry Program 3.4.1-49 (COND-P-3, Structural Austenitic Treated water Loss of Effectiveness VIII.E-29 1A 4,C5) integrity Stainless (Internal) material Inspection 16 S5)Steel Pump Casing Cast Air-indoor 3.4.1-50 (COND-P-3, integrity Stainless uncontrolled None None VIII.1-10 41 A 4, 5) i Steel (External) Aging Management Review Results Page 3.4-49 January 2010* Table 3.4.2-3 Row Component Intended No. Type Function(s) Structural 43 Piping integiity Structural 44 Piping integrity Structural 45 Piping integrity Structural 46 Piping integrity 47 Piping Structural integrity Pump Casing Structural 48 (COND-P-3, integrity 4; 5) Pump Casing Structural 49 (COND-P-3, integrity 4,,5) Pump Casing Structural 50 (COND-P-3, integrity 4,5) Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-Material Environment Requiring. Aging Management 1801 Table Notes Management Program Volume 1 Item 2 Item Air-indoor Loss of External Surfaces 3.4.1-C . Steel uncontrolled materia! Monitoring VIII.H-7 28 0404 (Internal) Treated water Loss of BWRWater -3.4.1-Steel (Internal) , material Chemistry VIII.E-33 04 A Treated water Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.E-33 04 A Inspection Air-indoor Loss of External Surfaces 3.4.1 : Steel uncontrolled material Monitoring VIII.H-7 28 A (External) Steel Condensation Loss of External Surfaces VIII.H-10 3.4.1-A (External) material Monitoring 28 Cast . , Austenitic Treated water Loss of BWRWater 3.4.1-Stainless (Internal) material Chemistry VIII.E-29 16 A Steel Cast Chemistry Program Austenitic Treated water Loss of 3.4.1-Stainless (Internal) material Effectiveness VIII.E-29 16 A Steel Inspection Cast Air-indoor Austenitic 3.4.1-Stainless uncontrolled None None VIII.I-10 41 A Steel (External) Page 3.4-49 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear) System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program Volume C Item 2 Item PmCaigC-as t-51 C an g Structural, Austenitic Condensation Loss of External Surfaces N/A N/A G 4,5) integrity Stainless (External) material -Monitoring Steel 52 Tank (COND- Pressure Steel Air-outdoor Loss of External Surfaces VIII.H-8 3.4.1- C TK-1A, 1B) boundary (Internal) material Monitoring 28 0411 Tank (COND- Pressure Moist air Loss of Supplemental TK-1A, 1 B) boundary Steel (Internal) material Piping/Tank N/A N/A G Inspection Tank (COND- Pressure Treated water Loss of BWR Water 3.4.1-TK-1A, 1B) boundary (Internal) material Chemistry 06 Tank (COND- Pressure Treated water Loss of Chemistry Program341-TK-1A, 1B) boundary Steel (Internal) material Effectiveness VIII.EAO 06 1Inspection_____ 56 Tank (COND- Pressure Air-outdoor Loss of Aboveground Steel VIII.E-39 3.4.1- B TK-1A, 18) boundary (External) material Tanks Inspection 20 0409 Tank (COND- Pressure Steel Air-outdoor Loss of External Surfaces VIIIH8 3.4.1- A TK-1A, 11B) boundary (External) material Monitoring 28 58 Tubing Pressure Stainless Air-outdoor None None N/A N/A G boundary Steel (Internal) Pressure Stainless Treated water Loss of BWR Water 3.4.1-5 ubing boundary Steel (Internal) material Chemistry 16 Aging Management Review Results Page 3.4-50 January 2010 Table 3.4.2-3 Row Component Intended No. Type Function(s) Pump Casing Structural. 51 (COND-P:'3, 4,5) integrity 52 Tank (COND-Pressure TK-1A,18) boundary Tank (COND-Pressure 53 TK-1A,18) boundary 54 Tank (COND-Pressure TK-1A,18) boundary Tank (COND-Pressure 55 TK-1A,18) boundary 56 Tank (COND-Pressure TK-1A,18) boundary 57 Tank (COND-Pressure TK-1A,18) boundary 58 Tubing Pressure boundary 59 Tubing Pressure boundary Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condel1sate (Nuclear)

System Aging Effect NUREG-Aging Management 1801* Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Cast , Austenitic Condensation Loss of External Surfaces N/A N/A G Stainless (External) material . Monitoring , Steel Steel Air-outdoor Loss of External Surfaces VIII.H-8 3.4.1-C (Internal) material Monitoring 28 0411 Moist air Loss of Supplemental Steel (Internal) material .PipingfTank N/A N/A G Inspection Steel. Treated water Loss of 8WRWater VII I. E-40 3.4.1-A (Internal) material Chemistry 06 Treated water Loss of Chemistry Program 3.4.1-Steel Effectiveness VII I. E-40 A (Internal) material Inspection 06 Steel Air-outdoor Loss of Aboveground Steel VII I. E-39 3.4.1-8 (External) material Tanks Inspection 20 0409 Steel Air-outdoor Loss of External Surfaces VII I. H:-8 3.4.1-A (External) material Monitoring 28 Stainless Air-outdoor None None N/A N/A G Steel (Internal) Stainless Treated water Loss of 8WRWater VIII.E-29 3.4.1-A Steel (Internal) material Chemistry 16 Page 3.4-50 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear)

System_Aging EffectUREG-Row Component Intended Aging Management 1801 Table No. Type Intended Material Environment Requiring I Notes No. Type Function(s) I Management Program Volume I Item_2 Item 6 TPressure Stainless Treated water Loss of Chemistry Program 3.4.1-..Tubing t, , I e, rItriI Effectiveness VIII.E-29 16 A boundary ..... Inspection 16 Pressure Stainless Air-indoor 3.41-61 Tubing uncontrolled None None VIII.I-10 A boundary Steel (External) 41 62 Tubing Pressure Stainless Air-outdoor None None N/A N/A G boundary Steel (External) 63 Tb Pressure Stainless Condensation Loss of External Surfaces VILF2-1 3.3.1- E uing boundary Steel (External) material Monitoring 27 64 Tb Structural Stainless Treated water Loss of BWR Water VlllE29 3.4.1- A uing. integrity Steel (Internal) material Chemistry 16 Structural Stainless Treated water Loss of Chemistry Program 3.4.1-6 TuigEffectiveness VIII.E-29 ,1665 Tubing integrity Steel (Internal) material Effectin16___________ ___________ Inspection Structural Stainless Air-indoor 3.4.1-66 Tubing integrity Steel uncontrolled None None. VIII.I-10 41 A (External) 67 Tubing Structural Stainless Condensation Loss of External Surfaces N/A N/A G integrity Steel (External) material -MonitoringN 68 Valve Body Pressure Stainless Air-outdoor None None N/A N/A G boundary Steel (Internal) Aging Management Review Results Page 3.4-51 January 2010* Table 3.4.2-3 Row Component Intended No. Type Function(s) Pressure 60 Tubing boundary Pressure 61 Tubing boundary 62 Tubing Pressure boundary 63 Tubing Pressure boundary \ 64 Tubing. Structural integrity Structural 65 Tubing integrity Structural 66 Tubing . integrity 67 Tubing Structural integrity 68 Valve Body Pressure* boundary Aging Management Review Results *

• Columbia Generating Station License Application Technical Information Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-Aging Management 1801 Table . Material Environment Requiring Program Volume Notes Management 2 Item Stainless Treated water Loss of Chemistry Program 3.4.1-Steel (lnterna!) materia! Effectiveness VIII.E-29 16 A Inspection Stainless Air-indoor 3.4.1-Steel uncontrolled None None VII 1.1-1 0 41 A (External) Stainless Air-outdoor None None N/A N/A G Steel (External) Stainless Condensation Loss of External Surfaces VII.F2-1 3.3.1-E SteeJ (External) material Monitoring 27 Stainless Treated water Loss of BWRWater VIII.E-29 3.4.1-A Steel (Internal) material Chemistry 16 Stainless Treated water Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.E-29 16 A Inspection Stainless Air-indoor 3.4.1-Steel uncontrolled None None VII 1.1-1 0 41 A (External) Stainless Condensation Loss of ExternCiI Surfaces N/A N/A G Steel (External) material" Monitoring. Stainless Air-outdoor None None N/A N/A G, Steel (Internal) Page 3.4-51 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear) System Ro n eAging Effect NUREG- 'Table Row Component Intended Material Environment Requiring Aging Management 1801 Notes No. Type Function(s) Program Volume I Item Management 2 Item 69 Valve Body Pressure Stainless Air-outdoor None None N/A N/A G boundary Steel (External) Pressure Air-indoor Loss of External Surfaces 3.4.1- C 70 Valve Body boundary Steel uncontrolled material MonitoringVIII.H-7 (Internal) Pressure Treated water Loss of BWR Water 3.4.1-boundary Steel (Internal) material Chemistry 04 A Chemistry Program 341 PrsueTreated water Loss of CeityPorm3.4.1-72 Valve Body Pressure Effectiveness VIII.E-33 04 A boundary (Internal) material Inspection 04 PrsueAir-indoor Loss of External Surfaces 3.4.1-73 Valve Body Pressure Steel uncontrolled VIII.H-7 A boundary (External) \ material Monitoring 28 74 Valve Body Pressure Steel Air-outdoor Loss of External Surfaces VIII.Hm8 3.4.1- A boundary (External) material Monitoring 28 Pressure Steel Condensation Loss of External Surfaces VIII.H-1 3.4.1- A 75 Valve Body boundary (External) material Monitoring 28 76 Valve Bd Structural Stainless Treated water Loss of BWR Water VIIIE29 3.4.1- A 7Y integrity Steel (Internal) material Chemistry 16 Structural Stainless Treated water Loss of Chemistry Program 3.4.1-Effectiveness VIII.E-29 16 77 Valve Body integrity Steel (Internal) material Inspection Aging Management Review Results Page 3.4-52 January 2010 , Table 3.4.2-3 Row Component Intended No. Type Function(s) \: 69 Valve Body Pressure boundary Pressure 70 Valve Body bouhdary 71 Valve Body Pressure boundary Pressure 72 Valve Body boundary Pressure 73 Valve Body boundary 74 Valve Body Pressure boundary 75 Valve Body Pressure boundary -76 Valve Body Structural integrity Structural 77 Valve Body integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-Aging Management 1801 ' Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Stainless Air-outdoor None None N/A N/A G Steel (External) Air-indoor Loss of External Surfaces 3.4.1-C Steel uncontrolled material Monitoring VIII.H-7 28 0404 (Internal) Steel Treated water Loss of BWRWater VIII.E-33 3.4.1-A (Internal) material Chemistry 04 Treated water Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.E-33 04 A Inspection .' Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled VII I. H-7 A (External) \ material Monitoring 28 Steel Air-outdoor Loss of External Surfaces VIII.H-8 3.4.1-A (External) material Monitoring I 28 Steel Condensation Loss of External Surfaces VIII.H-10 3:4.1-A (External) material Monitoring 28 Stainless Treated water Loss of BWRWater VIII.E-29 3.4.1-A Steel (Internal) material Chemistry 16 -Stainless Treated water Loss of. Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.E-29 16 A Inspection Page 3.4-52 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-3 Aging Management Review Results -Condensate (Nuclear)

System n ENUREG-Row Component Intended Material Environment Aging Effect Aging Management 1801 Table Notes No. Type Function(s) i Requiring Program Volume 1 Item_2Management 2Item Structural Stainless Air-indoor

3. I 1-Suu Stain les uncontrolled None None VIII.l-10 A Integrity Steel (External) 41 79 Structural Stainless Condensation Loss of External Surfaces N/A N/A G Valve Body integrity Steel (External) material Monitoring 80 Valve Body Structural Steel Treated water Loss of BWR Water VIII.E-33 3.4.1- A integrity (Internal) material Chemistry 04 Structural Treated water Loss of Chemistry Program 41-81 Valve Body Steel (Internal) material Effectiveness VIII.E-33 04 A 81 aleBdy integrity (InternInspection Air-indoor 82 Valve Body Structural Steel unco'ntrolled Loss of External Surfaces VIII.H-7 3.4.1- A integrity (External) material Monitoring 28 83 Valve Bd Structural Steel Condensation Loss of External Surfaces VLHl0 3.4.1- A oy integrity (External) material Monitoring 28 Aging Management Review Results Page 3.4-53 January 2010* Table 3.4.2-3 Row Component Intended No. Type . Function(s)

Structural 78 Valve Body integrity 79 Valve Body Structural integrity 80 Valve Body Structural integrity Structural 81 Valve Body integrity Structural 82 Valve Body integrity 83 Valve Body Structural integrity Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Condensate (Nuclear)

System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management -2 Item Stainless Air-indoor 3.4.1-Steel uncontrolled . None None VII \.1-1 0 41 A (External) -Stainless Condensation Loss of External Surfaces N/A N/A G Steel (External) material Monitoring Steel Treated water Loss of BWRWater VIII.E-33 3.4.1-A (Internal) material Chemistry 04 Treated water Loss of Chemistry Program / 3.4.1-Steel (Internal) material Effectiveness VIII.E-33 04 A Inspection Air-indoor Loss of Exterl'1al Surfaces 3.4.1-Steel uncontrolled VII I. H-7 A (External) material Monitoring 28 Steel Condensation Loss of External Surfaces VIII.H-10 3.4.1-A (External) material Monitoring 28 Page 3.4-53 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Mong Program Volume I Item Management 2 Item Pressure Stainless Air-indoor 3.4.1-1 Bolting- bounry Stnee uncontrolled None None VIII.1-10 41 C Bolg boundary Steel (External) 41 Pressure Stainless Loss of 2 Bolting Pressure Stail uncontrolled pre-oad Bolting Integrity N/A N/A F g boundary Steel (External) Treated 3 Bolting Pressure Stainless water Cracking Bolting Integrity VIII.C-2 1440405 boundary Steel (External) 14 0405 Treated LosoBotnInertN/NA F Pressure Stainless water Loss of 4 otn onay Selwater pr-od Bolting Integrity N/A N/A F Bolting boundary Steel (External) Treated 5 Bolting Pressure Stainless water Loss of Bolting Integrity VIII.C-1E boundary Steel (External) material 16 0405 (Extr-ndoor Pressure Loss of 3.4.1-6 Bolting boundary Steel uncontrolled material Bolting Integrity VIII.H-4 22B (External) Pressure Loss of 3.4.1-7 Bolting boundary Steel uncontrolled pre-load Bolting Integrity VIII.H-5 B (External) 22 Air-indoor Structural Stelinc o r Loss of 3.4.1-Bolting integrity Steel uncontrolled material Bolting Integrity VIII.H-4 31 B (External) maeil2 Structural Air-indoor Loss of 3.4.1-9 Bolting integrity Steel uncontrolled pre-load Bolting Integrity VIII.H-5 B (External) pre-load 22 Aging Management Review Results Page 3.4-54 January 2010< Table 3.4.2-4 Row Component Intended No. Type Function(s) Pressure 1 Bolting* boundary Pressure 2 Bolting boundary Pressure 3 Bolting boundary Pressure 4 Bolting boundary 5 Bolting Pressure boundary Pressure 6 Bolting boundary Pressure 7 Bolting boundary Structural 8 Bolting integrity Structural 9 Bolting integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Main Steam System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Stainless Air-indoor" 3.4.1-Steel uncontrolled None None VIILI-10 41 C (External)

Stainless Air-indoor Loss of Steel uncontrolled pre-load Bolting Integrity N/A N/A F (External) Stainless Treated 3.4.1-E Steel water Cracking Bolting Integrity VII I. C-2 14 0405 (External) Stainless Treated Loss of Steel water pre-load Bolting Integrity N/A N/A F (External) Treated , Stainless water Loss of Bolting Integrity VIII.C-1 3.4.1-E Steel (External) material 16 0405 Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting Integrity VII I. H-4 22 B (External) Air-indoor Loss of 3.4.1-Steel uncontrolled pre-load Bolting Integrity VIII.H-5 22 B (External) Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting Integrity VII I. H-4 22 B (External) Air-indoor Loss of 3.4.1-Steel uncontrolled pre-load Bolting Integrity VIII.H-5 22 B (External) Page 3.4-54 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam System Aging ffectNUREG-Row Component Aging Management 1801 TableNNote No. Type Function(s)

MeManagement Program Volume 1 Item I Mteral nvionmnt equrin AgngManagement 10 al oe 2 Item Pressure Dried air None 3.4.1- A 10 Manifold bPoeurneda... Aluminum ,eNone .VIII-1 44 0402 Pressure Air-indoor 11 Manifold boury Aluminum uncontrolled None None N/A N/A G boundary (External) 12- Moisture Pressure Steel Steam Loss of BWR Water VIII.B2-3 3.4.1- C Separator boundary (Internal) material Chemistry 37 Moisture Pressure Steam Loss of Chemistry Program 3.4.1-(r maera Effectiveness VIII. B2-3 E Sep .arator boundary (internal) material Inspection 37 14 Moisture Pressure Steel Steam Loss of Flow-Accelerated VIII.B2-4 3.4.1- C Separator boundary (Internal) material Corrosion (FAC) 29 Moisture Pressure Air-indoor Loss of External Surfaces 3.4I. 1-15 Separator boundary uncontrolled material Monitoring 28 (External) Structural Stainless Moist air Loss of Supplemental16 Orifice Piping/Tank N/A N/A G integrity Steel (internal) material Inspection Structural Stainless Air-indoor 3.4.1-17 Orifice integrity Steel uncontrolled None None VIII.I-10 41 A (External) Pressure Stainless Steam C BWR Water VIII 62 1 3.4.1- A 18 Piping boundary Steel (Internal) Cracking Chemistry 13 Aging Management Review Results Page.3.4-55 January 2010* Table 3.4.2-4 Row Component Intended No. Type Function(s) 10 Manifold Pressure boundary' Pressure 11 Manifold boundary 12 Moisture Pressure Separator boundary Moisture Pressure 13 Separator boundary 14 Moisture Pressure. Separator boundary , Moisture Pressure 15 Separator boundary Structural 16 Orifice integrity Structural 17 Orifice integrity Pressure 18 Piping boundary Aging Management Review Results * '. Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Main Steam System Aging Effect NUREG. Material Environment Requiring Aging Management 1801 Table Notes Management Program Volume 1 Item 2 Item Aluminum Dried air None None VII 1.1-1 3.4.1-A (fnterna!) 44 0402 , Air-indoor .. Aluminum uncontrolled None None N/A N/A G (External) Steel Steam Loss of BWRWater VIII.B2-3 3.4.1-C (Internal) material Chemistry 37 Steam Loss of Chemistry Program 3.4.1-(Internal) material Effectiveness VIII.B2-3 37 E Inspection Steel Steam Loss of Flow-Accelerated VIII.B2-4 3.4.1-C (Internal) material Corrosion (FAC) 29 -Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIII.H-7 28 A (External) Stainless Moist air Loss of Supplemental Steel (Internal) material PipinglTank N/A N/A G Inspection Stainless Air-indoor 3.4.1-uncontrolled None None VII 1.1-1 0 A Steel (External) 41 Stainless Steam l BWRWater 3.4.1-Steel (Internal) Cracking Chemistry VIII.B2-1 13 A -Page 3.4-55 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) M Program Volume 1 Item Smanagement .2 Item Pressure Stainless Steam Chemistry Program 3.4.1-19 Piping boundary Steel (Internal) Cracking Effectiveness VIII.B2-1 13 A Inspection 20 Piping Pressure Stainless Steam Loss of BWR Water VIII.B2-2 3.4.1- A boundary Steel (Internal) material Chemistry 37 Pressure Stainless Steam Loss of Chemistry Program 341-21 Piping material Effectiveness VIII.B2-2 341 E boundary Steel (internal) Inspection7 Inspection 3 Treated 22 Piping Pressure Stainless water > 60 °C BWR Water VIII.C-2 3.4.1- A boundary Steel (140 OF) Cracking Chemistry 14 (Internal) Treated Chemistry Program 23 Piping Pressure Stainless water > 60 °C Cracking Effectiveness VIII.C-2 341-boundary Steel (140 °F) Ingpection 14 (Internal) Inspection Treated Pressure Stainless water > 60 °C Loss of BWR Water 3.4.1- A 24 Piping boundary Steel (140 °F) material Chemistry VIII.D2-4 16 0403 (Internal) Treated 25 Piping Pressure Stainless water > 60 °C Loss of Chemistry Program 3 4 01- A boundary Steel (140 OF) material Inspection 16 0403 (Internal) Pressu~re Stainless Air-indoor 3.4.1- A 26 Piping bouary Staleel uncontrolled None None VIII.I-10 41 0 26_ Pipingboundary Steel (Internal) 41 0410 Aging Management Review Results Page 3.4-56 January 2010 Table 3.4.2-4 Row Component Intended No. Type Function(s) Pressure 19 Piping boundary 20 Piping Pressure boundary Pressure 21 Piping boundary 22 Piping . Pressure boundary Pressure 23 Piping boundary 24 Piping Pressure boundary Pressure 25 Piping boundary Pressure 26 Piping boundary Aging Management Review Results e. Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Main Steam System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management . 2 Item Stainless Steam Chemistry Program 3.4.1-Steel (Internal) Cracking Effectiveness VIII.B2-1 13 A Inspection Stainless Steam Loss of BWRWater VIII.B2-2 3.4.1-A Steel (Internal) material 37 Stainless Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.B2-2 37 E Inspection Treated Stainless water> 60°C Cracking BWRWater VII I. C-2 3.4.1-A Steel (140 OF) Chemistry 14 (Internal) Treated Chemistry Program Stainless water> 60°C 3.4.1-Steel (140 OF) Cracking Effectiveness VII I. C-2 14 A (Internal) Inspection Treated Stainless water> 60°C Loss of BWRWater VIII. 02-4 3.4.1-A Steel (140 OF) material Chemistry 16 0403 (Internal) Treated Chemistry Program Stainless water> 60°C Loss of 3.4.1-A Steel (140 OF) material Effectiveness VIII. 02-4 16 0403 (Internal) Inspection Stainless Air-indoor 3.4.1-A Steel uncontrolled None None VII 1.1-1 0 41 0410 (Internal) Page 3.4-56 January 2010 e e Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Program Volume 1 Item Management 2 Item 1reoundre SAir-indoor 341-27 Piping Pressure Stainless uncontrolled None None VIII.I-10 A boundary ýee,,l (Etra)41...(External) _______Pressure Air-indoor Loss of External Surfaces 3.4.1- C 28 Piping boundary Steel uncontrolled material Monitoring VIII.H-7 28 0404 (Internal) Pressure Moist air Loss of Supplemental 29 Piping Prese Steel M t m i LPiping/Tank N/A N/A G boundary (Internal) material Inspection Pressure S team Loss of BWR Water 3.4.1-30 Piping boundary (Internal) material Chemistry 37 Pressure Steam Loss of Chemistry Program 3.4.1-Prss e telEffectiveness VJII.B2-3E 31 Piping boundary Steel (Internal) material Inspection 32 P. Pressure Steel Steam Loss of Flow-Accelerated VIII.12-4 3.4.1- A iping boundary (Internal) material Corrosion (FAC) 29 Pressure Treated Loss of BWR Water 3.4.1- A 33 Piping boundary Steel water material Chemistry 04 (internal) mtra hmsr 3ePressure wated Loss of Chemistry Program 3.4.1- A Tressury Steel water Lossrofl Effectiveness VIII.B2-6 04 (Internal) material Inspection Pressure Air-indoor Loss of External Surfaces 3.4.1-35 Piping boundary Steel uncontrolled material Monitoring 28________________________________________(External)____________________ ___Aging Management Review Results Page 3.4-57 January 2010* Table 3.4.2-4 Row Component Intended Type Function(s) Pressure 27 Piping boundary Pressure 28 Piping boundary Pressure 29 Piping. boundary 30 Piping Pressure boundary Pressure .31 Piping boundary 32 Piping Pressure boundary Pressure 33 Piping boundary Pressure 34 Piping boundary 35 Piping -' Pressure boundary Aging Management Review Results *

• Columbia Generating Station license Renewal Application Technical Information Aging Management Review Results -Main Steam System Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes Management Program Volume 1 Item 2 Item Stainless Air-indoor 3.4.1-Steel uncontrolled None None VIILI-10 41 A (External)

Air-indoor Loss of External Surfaces 3.4.1-C Steel uncontrolled material Monitoring VII I. H-7 28 0404 (Internal) Moist air Loss of Supplemental Steel (Internal) material PipingfTank N/A N/A G Inspection Steel I Steam Loss of BWRWater VIII.B2.;.3 3.4.1-A (Internal) material Chemistry 37 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.B2-3 37 E Inspection Steel Steam Loss of Flow-Accelerated V/II.B2-4 3.4.1-A (Internal) material Corrosion (FAC) 29 Treated Loss of BWRWater 3:4.1-Steel water material Chemistry VIII.B2-6 04 A (Internal) Treated Loss of Chemistry Program 3.4.1-Steel water material Effectiveness. VIII.B2-6 04 A (Internal) Inspection Air-indoor. .. Steel uncontrolled Loss of External Surfaces VIII.H-7 3.4.1-A (External) material Monitoring 28 Page 3.4-57 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program Volume I Item 2 Item Pressure Air-indoor Loss of Supplemental 3.4.1- E 36 Piping boundary Steel uncontrolled Piping/Tank VIII.H-7 28 0401 (External) material Inspection Pressure Treated Loss of BWR Water 3.4.1-37 Piping boundary Steel water material Chemistry 04 A (External) mtra hmsr Pressure Treated Lossof Chemistry Program 3.4.1-38 Piping boundary Steel water Effectiveness VIII.B2-6 04 A (External) material Inspection Structural Moist air Loss of Supplemental 39 Piping integrity Steel (Internal) material Piping/Tank N/A N/A G Inspection Structural Steam Loss of BWR Water Vlll.B2-3 3.4.1- A 40 Piping integrity Steel (Internal) material Chemistry 37 Structural Steam Loss of Chemistry Program 3.4.1-41 Ppil Steel (nternal) m a 0Effectiveness VIII.B2-3 37 41 Piping integrity (internal) material spection42 Piping Structural Steel Steam Loss of Flow-Accelerated VIII B24 3.4.1- A integrity (Internal) material Corrosion (FAC) 29 Structural Air-indoor Loss of External Surfaces 3.4.1-43 Piping integrity Steel uncontrolled VIII.H-7 A (External) material Monitoring 28 Structural Stainless Moist air Loss of Supplemental 44 Piping Piping/Tank N/A N/A G 44 Piping integrity Steel (Internal) material Inspection Aging Management Review Results Page 3.4-58 January 2010 Table 3.4.2-4 Row Component Intended No. Type Function(s) Pressure 36 Piping boundary Pressure 37 Piping boundary Pressure 38 Piping boundary Structural 39 Piping integrity 40 Piping Structural integrity Structural 41 Piping integrity 42 Piping Structural integrity Structural 43 Piping integrity Structural 44 Piping integrity Aging Management Review Results

• Columbia Generating Station u"cense Renewal Application Technical Information Aging Management Review Results -Main Steam System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Air-indoor Loss of Supplemental 3.4.1-E Steel uncontrolled material PipinglTank VIII.H-7 28 0401 (External)

Inspection . Treated Loss of BWRWater 3.4.1-Steel water material Chemistry VIII.B2-6 04 A (External) Treated Loss'of Chemistry Program 3.4.1-Steel water material Effectiveness VII I. B2-6 04 A (External) Inspection Moist air Loss of Supplemental Steel (Internal) material PipinglTank N/A N/A G Inspection Steel Steam Loss of BWRWater VII I. B2-3 3.4.1-A (Internal) material Chemistry 37 Chemistry Program -Steam Loss of 3.4.1-Steel (Internal) material Effectiveness VII I. B2-3 37 E Inspection Steel Steam Loss of Flow-Accelerated VII I. B2-4 3.4.1-A (Internal) material Corros.ion (FAC) 29 Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VII I. H-7 28 A (External) Stainless Moist air Loss of* Supplemental. Steel (Internal) material PipinglTank N/A N/A G Inspection Page 3.4-58 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam System Aging Effect NUREG-Aging Effen IAging Management 1801 Table Notes Row Type Function(se Material Environment Requiring Program Volume I Item No. Management 2 Item I2 I t e 45 Quencher Pressure Stainless Treated Loss of BWR Water VIII.C-1 3.4.1- A 1atQuencherC-l boundary Steel (Internal) materia. Chemistry 16 Pressure Stainless Treated Loss of Chemistry Program 3.4.1-46 Quencher water Effectiveness VIII.C-1 31 boundary Steel (Internal) material Inspection 16 Pressure Stainless Treated Loss of BWR Water 3.4.1-47 Quencher boundary Steel water material Chemistry VllC-1 16 Pressure Stainless Treated Loss of Chemistry Program 3.4.1-48 Quencher boundary Steel water material Effectiveness VIII.C-1 16A bou~undary Stel(External)

Inspection 16 eQ h Stainless Tated Loss of BWR Water VIII.C-1 3.4.1- A uencerSteel (internal) material Chemistry 16 SprayCSteelt(Internal) Stainless Treated Loss of Chemistry Program 3.4.1-Steel water material Effectiveness VIII.C-1 A16 50 Quencher Spray Steel (Internal)6 (Internal) Inspection Stainless Treated Loss of BWR Water 3.4.1-51 Quencher Spray Steel water material Chemistry 16____________ ~~(External) __________ Treated Loss of Chemistry Program 3.4. A 52 Quencher Spray Steel water material Effectiveness VIII.C-1 16A (External) Inspection Pressure Steam Loss of BWR Water 3.4.1- A 53 Strainer Body boundary Steel (Internal) material Chemistry 37 Aging Management Review Results Page 3.4-59 January 2010* Table 3.4.2-4 Row Component Intended No. Type Function(s) Pressure 45 Quencher boundary Pressure 46 Quencher boundary Pressure 47 Quencher boundary Pressure 48. Quencher boundary 49 Quencher Spray 50 Quencher Spray 51 Quencher Spray 52 Quencher Spray 53 Strainer Body Pressure boundary Aging Management Review Results * , .

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Main Steam System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Stainless Treated Loss of BWRWater 3.4.1-Steel water materia! Chemistry , VIILC-1 16 A (Internal)

Stainless Treated Loss of Chemistry Program 3.4.1-Steel water material Effectiveness VIILC-1 16 A (Internal) Inspection Stainless Treated Loss of BWRWater 3.4.1-Steel water material Chemistry VIILC-1 J6 A (External) Stainless Treated Loss of Chemistry Program 3.4.1-Steel water material Effectiveness VIII.C-1 16 A (External) Inspection Stainless Treated Loss of BWRWater 3.4.1-Steel water material Chemistry VIILC-1 16 A (Internal) Stainless Treated* Loss of Chemistry Program 3.4.1-Steel water material Effectiveness VIILC-1 16 A (Internal) Inspection Stainless Treated Loss of BWRWater 3.4.1-Steel water material Chemistry VIILC-1 16 A (External) Stainless Treated Loss of Chemistry Program 3.4.1-water -Effectiveness VIILC-1 A Steel material 16 (External) Inspection , Steel Steam Loss of BWRWater VIII.B2-3 3.4.1-A (Internal) material' Chemistry 37 Page 3.4-59 January 2010 Columbia Generating Station License Renewal Application Technical Information a Table 3.4.2-4 Aging Management Review Results -Main Steam System 1Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program Volume 1 Item 2 Item Pressure Steam Loss of Chemistry Program 3.4.1-54 Strainer Body boundary Steel (Internal) material Effectiveness VIII.B2-3 37 Inspection 55 Strainer Bod Pressure Steam Loss of Flow-Accelerated VIII B2A 3.4.1- A 5 Srn boundary (Internal) material Corrosion (FAC) 29 Pressure Air-indoor Loss of External Surfaces 3.4.1-56 Strainer Body boundary Steel uncontrolled materialVIII.H-7 28A (External) Monitoring 57 T Structural Gray Cast Moist air Loss of Selective Leaching N/A N/A G Trap B integrity Iron (Internal) material Inspection Structural Gray Cast Moist air Loss of Supplemental G integrity Iron (Internal) material Inspection N/A_ N/A Structural Gray Cast Steam Loss of BWR Water 3.4.1-59 Trap Body integrity Iron (Internal) material Chemistry VIII.B2-3 7 Structural Gray Cast Steam Loss of Chemistry Program 3.4.1-Strctual rayCas Stam ossof Effectiveness VIII.B2-3 341 60 Trap Body integrity iron (Internal) material Inspection 37 61 T Bd Structural Gray Cast Steam Loss of Flow-Accelerated V 12- 3.4.1- A rap oy integrity. Iron (Internal) material Corrosion (FAC) 29 62 Trap Body Structural Gray Cast Steam Loss of Selective Leaching N/A N/A G integrity Iron (Internal) material Inspection I I Aging Management Review Results Page 3.4-60 January 2010., Table 3.4.2-4 Row Component Intended No. Type Function(s) Pressure 54 Strainer Body boundary 55 Strainer Body Pressure boundary .. Pressure 56 Strainer Body boundary 57 Trap Body Structural 'integrity Structural 58 Trap Body integrity 59 Trap Body Structural integrity Structural 60 Trap Body integrity 61 Trap Body Structural integrity 62 Trap Body Structural integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Main Steam System Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes Management Program Volume 1 Item 2 Item Steam Loss of Chemistry Program 3.4.1-Steel --Effectiveness VIII.B2-3 E (Internal) material Inspection 37 Steel Steam Loss of Flow-Accelerated VIII.B2-4 3.4.1-A (Internal) material Corrosion (FAC) 29 Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIII.H-7 28 A (External)

Gray Cast Moist air Loss of Selective Leaching N/A N/A G Iron (Internal) material Inspection Gray Cast Moist air Loss of Supplemental N/A Iron (Internal) material PipinglTank N/A G Inspection Gray Cast Steam Loss of BWRWater VII I. B2-3 3.4.1-A Iron (Internal) material Chemistry 37 Gray Cast Steam Loss of Chemistry Program 3.4.1-iron (Internal) material Effectiveness VIII.B2-3 37 E Inspection Gray Cast Steam Loss of Flow-Accelerated VII I. B2-4 3.4.1-A Iron (Internal) material Corrosion (FAC) 29 Gray Cast Steam Loss of Selective Leaching N/A N/A . G Iron (Internal) material Inspection Page 3.4-60 January 2010 *

• 0 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s)

Manavement Program Volume 1I Item Management 2 ItemStrutura " ray ast Air-indoor Structural Ga Cast AnLoss of External Surfaces 3.4.1-63 Trap Body y I1- uncontrolled VIII.H-7 (External) terial Monitoring 28 Supplemental 64Structural Steel Moist air Loss of Piping/Tank N/A N/A G integrity (Internal) material Inspection 65 Trap Body Structural Steel Steam Loss of BWR Water VIII B2-3 3.4.1- A integrity (Internal) material Chemistry 37 Structural Steam Loss of Chemistry Program 3.4.1-66 Trap Body rucu Steel Effectiveness VIII.B2-3

3. E integrity (internal) material Inspection 37 Structural Steam Loss of Flow-Accelerated 3.4.1-67 Trap Body integrity Steel (Internal) material Corrosion (FAC) VIII.B24 29 A Structural Air-indoor Loss of External Surfaces 3.4.1-68 Trap Body integrity Steel uncontrolled VIII.H-7 A (External) material Monitoring 28 Pressure Stainless 3.4.1- A 69 Tubing boundary Steel uncontrolled None None VIII.1-10 41 0410 (Internal)

Pressure Stainless Dried air 3.4.1- A 70 Tubing boundary Steel (Internal) None None VII.1-12 4 0402 71 Tb Pressure Stainless Steam C BWR Water VIII B21 3.4.1- A ubing boundary Steel (Internal) Cracking Chemistry 13 Aging Management Review Results Page 3.4-61 January 2010* Table 3.4.2-4 Row Component Intended No. Type F'unction(s) Structural 63 Trap Body integiity" Structural 64 Trap Body integrity 65 Trap Body Structural integrity Structural 66 Trap Body integrity 67 Trap Body Structural integrity Structural 68 Trap Body integrity Pressure 69 Tubing boundary 70 Tubing Pressure boundary 71 Tubing Pressure boundary Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Main Steam System Aging Effect NUREG-Material Environment Requiring ,Aging Management 1801 Table Notes Management Program Volume 1 Item 2 Item Gray Cast Air-indoor Loss of External Surfaces ' 3.4.1-uncontrolled materia! Monitoring VII I. H-7 28 A IIVII (External)

Moist air Loss of Supplemental Steel (Internal) material PipingfTank N/A N/A G Inspection Steel Steam Loss of BWRWater VIII.B2-3 3.4.1;-A (Internal) material Chemistry 37 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.B2-3 37 E Inspection Steel Steam Loss of Flow-Accelerated VIII.B2-4 3.4.1-A (Internal) material Corrosion (FAC) 29 Air-indoor Loss of' External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIII.H-7 28 A (External) Stainless Air-indoor 3.4.1-A Steel uncontrolled None None VII 1.1-1 0 41 0410 (Internal) Stainless Dried air None None VIII.I-12 3.4.1-A Steel (Internal) 44 0402 Stainless Steam Cracking BWRWater VIII.B2-1 3.4.1-A Steel (Internal) Chemistry ... 13 Page 3.4-61 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam-System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program Volume 1 Item 2 Item Pressure Stainless Steam Chemistry Program 341-72 Tubing boundary Steel (Internal) Cracking Effectiveness VIII.B2-1 13 A Inspection 13 73 Tubing Pressure Stainless Steam Loss of BWR Water VIII B22 3.4.1- A boundary Steel (Internal) material Chemistry 37 Pressure Stainless Steam Loss of Chemistry Program 341-74 Tubing Effectiveness VIII.B2-2 3.4 E boundary Steel (Internal) material Inspection Treated 75 Tubing Pressure Stainless water > 60 °C BWR Water VIII C.2 3.4.1- A boundary Steel (140 OF) Cracking Chemistry 14 (Internal) Treated Chemistry Program Pressure Stainless water > 60 'C Cracking Effectiveness VIII.C-2 3.4.1-boundary Steel (140 OF) Ingpection 14 (Internal) Inspection Treated 77 Tubing Pressure Stainless water > 60 'C Loss of BWR Water VIII.D2-4 3.4.1- A boundary Steel (140 OF) material Chemistry 16 0403 (Internal) Treated Chemistry Program 78 Tubing Pressure Stainless water > 60 °C Loss of Effectiveness VIII.2-r 3.4.1- A boundary Steel (140 OF) material Inspection 16 0403 (Internal).Pressure Stainless Air-indoor -3.4.1-79 Tubing boundary Steel uncontrolled None None VIII.1-10 41 A 79_ _ Tubing_ _ boundary_ Steel(External) 41 Aging Management Review Results Page 3.4-62 January 2010 Table 3.4.2-4 Row Component Intended No. Type Function(s) Pressure 72 Tubing boundary 73 Tubing Pressure boundary Pressure 74 Tubing boundary 75 Tubing Pressure boundary Pressure 76 Tubing boundary 77 Tubing Pressure boundary Pressure 78 Tubing boundary Pressure 79 Tubing boundary Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Main Steam-System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Stainless Steam Chemistry Program 3.4.1-Steel (Internal)

Cracking Effectiveness VII I. B2-1 13 A Inspection Stainless Steam Loss of BWRWater VII I. B2-2 3.4.1-A Steel (Internal) material Chemistry 37 Stainless Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.B2-2 37 E -Inspection Treated Stainless water> 60°C Cracking BWRWater VIII.C-2 3.4.1-A Steel (140 OF) Chemistry 14 (Internal) Treated Chemistry Program Stainless water> 60°C 3.4.1-Steel (140 OF) Cracking Effectiveness VIII.C-2 14 A (Internal) Inspection Treated Stainless . water> 60°C Loss of BWRWater VII I. D2-4 3.4.1-A Steel (140 OF) material Chemistry 16 0403 (Internal) -Treated Chemistry Program Stainless water> 60°C Loss of 3.4.1-A Steel (140 OF) material Effectiveness VI II. D2-4 16 0403 (Internal) Inspection Stainless Air-indoor " 3.4.1-Steel uncontrolled None None VII 1.1-1 0 41 A (External) Page 3.4-62 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam System ANUREG-Row Component Intended MrAging Effect Aging Management 1801 Table No. Type Function(s)

Material Environment Requiring Program Volume I Item Notes Cn teManagement 2Item 80 Turbine Pressure Steam Loss of BWR Water VIII.B2-3 31- C Casing boundary interal) materi C-heImisfnr 37 Turbine. Pressure Steam Loss of Chemistry Program 3.4.1-81 Casing boundary Steel (internal) material Effectiveness VIII.B2-3 Cainoudry(ntrnlmtril Inspection 37 82 Turbine Pressure Steel Steam Loss of Flow-Accelerated VIII.B2-4 3.4.1- C Casing boundary (Internal) material Corrosion (FAC) 29 Turbine Pressure Air-indoor Loss of External Surfaces 3.4.1-83 Tubn rsue Steel uncontrolled VIII.H-7 A Casing boundary Sentrolle material Monitoring 28 (External) 84 Valve Body Pressure Dried air N 3.4.1- A boundary (internal) None None VIII.l-1 44 0402 Pressure Air-indoor 85 ValveBody Aluminum uncontrolled None None N/A N/A G 85 Vale*Boy boundary (External) 86 valve Body Pressure Stainless Steam BWR Water VIIIB21 3.4.1-- A boundary Steel (Internal) Cracking Chemistry 13 Va Pressure Stainless Steam Chemistry Program 3.4.1- A 87boundary Steel (Internal) Cracking Effectiveness VIII.B2-1 13 Inspection 13 Pressure Stainless Steam Loss of BWR Water 3.4.1- A boundary Steel (Internal) material Chemistry 37 Aging Management Review Results Page 3.4-63 January 2010* Table 3.4.2-4 Row Component Intended No. Type Function(s) 80 Turbine Pressure Casing boundary Turbine Pressure 81 Casing boundary 82 Turbine Pressure Casing boundary Turbine Pressure 83 Casing boundary 84 Valve Body Pressure boundary Pressure 85 Valve Body boundary 86 Valve80dy Pressure boundary Pressure 87 Valve Body boundary 88 Valve Body Pressure . boundary Aging ManagementReview Results *

• Columbia Generating Station License Renewal Application . Technical Information Aging Management Review Results -Main Steam System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Steel Steam Loss of BWRWater VII I. B2-3 3.4.1-C (Interna!)

materia! Chemistry 37 -Chemistry Program ( Steam Loss of 3.4.1-Steel (Internal) material Effectiveness VIII.B2-3 37 E* Inspection Steel Steam Loss of Flow-Accelerated VIII.B2-4 3.4.1-C (Internal) material Corrosion (FAG) 29 Air-indoor Loss of External Surfaces' 3.4: 1-Steel uncontrolled VII I. H-7 A (External) material Monitoring 28 , Dried air -None 3.4.1-A Aluminum (Internal) None VIILI-1 44 0402 Air-indoor Aluminum uncontrolled None None N/A N/A G (External) Stainless Steam Cracking BWRWater VIII.B2-1 3.4.1--A Steel (Internal) Chemistry 13 Stainless Steam Chemistry Program 3.4.1-Steel (Internal) . Cracking . Effectiveness VIII.B2-1 13 A Inspection Stainless Steam Loss of BWRWater VIII.B2-2 3.4.1-A Steel (Internal) material Chemistry 37 Page 3.4-63 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam System Row Component Intended Aging Effect NUREG-Iow Typo Funtended Material Environment Requiring Aging Management 1801 Table Notes No. Type, i Function(s) Maaemn Program Volume I 1Item Management 2 Item ___Pressre Sainles Stam Los of Chemistry Program 31 89 Valve Body Effectiveness VIII.B2-2 3.4 1 boundary Steel (Internal) material Inspection37 Treated 90 Valve Body Pressure Stainless water > 60 °C Cracking BWR Water 3.4.1-boundary Steel (140 -F) Cracking 1 (Internal) Treated Pressure Stainless water > 60 d C Chemistry Program 3.4.1-91 Valve Body Pressure Staes wt>0 0 C Cracking Effectiveness VIII.C-2 A boundary Steel (140 -F) 1 (Internal) Inspection Treated 92 Valve Body Pressure Stainless water > 60 OC Loss of BWR Water 3.4.1- A boundary Steel (140 -F) material Chemistry 16 0403 (Internal) Treated Chemistry Program Pressure Stainless water > 60 OC Loss of 3.4.1- A Valve Body boundary Steel (140 -F) material Inspection 16 0403 (Internal) Pressure Stainless Air-indoor 3.4.1-94 Valve Body uncontrolled None None VIII.I-10 A boundary Steel (External) 41 Pressure Air-indoor Loss of External Surfaces 3.4.1- C 95 Valve Body boundary Steel, uncontrolled material Monitoring VIII.H-7 28 0404 (Internal) mtra Moioig2 04 96 VaBd Pressure Steam Loss of BWR Water 3.4.1-aveoy boundary Steel (Internal) material Chemistry VIII.B2-3 37 A Aging Management Review Results Page 3.4-64 January 2010Table 3.4.2-4 Row Component Intended No. Type Function(s) Pressure 89 Valve Body boundary 90 Valve Body Pressure boundary Pressure 91 Valve Body boundary 92 Valve Body Pressure boundary Pressure 93 Valve Body boundary Pressure 94 Valve Body boundary Pressure 95 Valve Body boundary 96 Valve Body Pressure boundary Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Main Steam System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume " '1 Item Notes Management 2 Item Stainless Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.B2-2 37 E Inspection Treated Stainless water> 60°C Cracking BWRWater VIII.C-2 3.4.1-A Steel (140 OF) Chemistry 14 (Internal)

Treated Chemistry Program Stainless water> 60 DC 3.4.1-Steel (140 OF) Cracking Effectiveness VIII.C-2 14 A (Internal) Inspection Treated Stainless water> 60 DC Loss of BWRWater VIII.D2-4 3.4.1-A Steel (140 OF) material Chemistry 16 0403 (lnternall Treated Chemistry Program Stainless water> 60 DC Loss of 3.4.1-A Steel (140 OF) material Effectiveness VIII.D2-4 16 0403 (Internal) Inspection Stainless Air-indoor 3.4.1-Steel uncontrolled None None VII 1.1-1 0 41 A (External) Air-indoor Loss of External Surfaces 3.4.1-C Steel. uncontrolled material Monitoring VII I. H-7 28 0404 (Internal) Steel Steam Loss of BWRWater VIII.B2-3 3.4.1-A (Internal) material Chemistry 37 Page 3.4-64 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.4.2-4 Aging Management Review Results -Main Steam System RweAging Effct NUREG-Row Component Intended Material Environment Requiring Agn Ma ge nt 10T bl No s No. Function(s)

Management Program Volume I Item_2 Item I T £ Chemistry Program I Pressure Steam Loss of CeityPorm3.4.1-E 97 Valve Body T Psunr Steel Sntearm Lo Effectiveness VIII.B2-3 3E ValeounIdary I Itra) material 3 Inspection 98 Pressure Steel Steam Loss of Fow-Accelerated VIII.B2-4 3.4.1- A Valve Body boundary (Internal) material Corrosion (FAC) 29 Pressure Steel Air-indoor Loss of External Surfaces VIII.H-7 3.4.1- A 99 Valve Body boundary uncontrolled matel M (External) material Monitoring 28 Structural Moist air Loss of Supplemental 10 av oySelPiping/Tank N/A N/A 100 Valve Body integrity Steel (Internal) material Inspection N/AN/A 101 Valve Body Structural Steel Steam Loss of BWR Water VIII.B2-3 3.4.1- A integrity (Internal) material Chemistry 37 Structural Steam Loss of Chemistry Program 3.4.1-102 Vale ody Stuctra StelStem ossof Effectiveness VIII.B2-3 3.417 102 Valve Body integrity Steel (Internal) material Inspection _______3_103 Valve Body Structural Steel Steam Loss of Flow-Accelerated VIII.B2-4 .1- A integrity (Internal) material Corrosion (FAC) 29 Structural Air-indoor Loss of -External Surfaces 3.4.1-104 Valve Body integrity Steel uncontrolled VIII.H-7 A/ (External) material Monitoring 28 Aging Management Review Results Page 3.4-65 January 2010* Table 3.4.2-4 Row Component Intended No. Type. Function(s) 97 Valve Body boundary' 98 Valve Body Pressure boundary Pressure 99 Valve Body boundary Structural 100 Valve Body integrity 101 Valve Body Structural integrity Structural 102 Valve Body integrity 103 Valve Body Structural integrity 104 Valve Body Structural I integrity Aging Management Review Results *

• Columbia Generating Station . License Renewal Application Technical Information Aging Management Review Results -Main SteamSystem Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Steam Loss of Chemistry Program 3.4.1-Steel Effectiveness VIII.B2-3 E (Interna!)

materia! Inspection 37 Steel Steam Loss of Flow-Accelerated VIII.B2-4 3.4.1-A (Internal) material Corrosion (FAC) 29 Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIII.H-7 28 A (External) Moist air Loss of Supplemental Steel (Internal) material PipingfTank N/A N/A G* Inspection Steel Steam Loss of BWRWater VIII.B2-3 3.4.1-A (Internal) material Chemistry 37 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII:B2-3 37 E Inspection Steel Steam Loss of Flow-Accelerated VIII.B2-4 3.4.1-A (Internal) material Corrosion (FAC) 29 Air-indoor -Steel uncontrolled Loss of External Surfaces VIII.H-7 3.4.1-A (External) material Monitoring 28 Page 3.4-65 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-5 Aging Management Review Results -Main Steam Leakage Control System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program Volume 1 Item 2 Item Structural Stainless Air-indoor 3.4.1- A 1 Annubar integrity Steel uncontrolled None None VIII.1-10 41 0410 (Internal) Structural Stainless Air-indoor 3.4.1-2 Annubar integrity Steel uncontrolled None None VIII.1-10 41 A integrity___-_Steel (External) 41 Pressure Air-indoor Loss of 3.4.1-3 Bolting boundary Steel uncontrolled material Bolting Integrity VIII.H-4 22B Boltng ounary(External) Air-indoor Pressure Ai-nor Loss of 3.4.1-4 Bolting boundary Steel uncontrolled -loss Bolting Integrity VIII.H-5 3. B" (External) pre-load 22 Air-indoor Structural Ai-nor Loss of 3.4.1-Bolting Strutu Steel uncontrolled Bolting Integrity VIII.H-4 B integrity (External) material 22 Air-indoor Structural Stelincor Loss of 3.4.1-Bolting integrity Steel uncontrolled pre-load Bolting Integrity VIII.H-5 31 B (External) pr-od *2 Air-indoor L oE rSa.1 F H Structural Gray Cast uncontrol Loss of External Surfaces VIII.H-7, 3.4.1- C 7 an ousing integrity Iron (Internall material Monitoring 28 0404 Air-indoor 8 Structural Gray Cast uncontrolled Loss of External Surfaces VIII.H-7 3.4.1- A F integrity Iron (External) material Monitoring 28 Filter Structural Air-indoor Loss of External Surfaces 3.4.1- C Housing integrity Steel Uncontrolled material Monitoring VIIIH-7 28 0404_______ ___________ ___________ ____________ (Internal) ________ ___________ _________Aging Management Review Results Page 3.4-66 January 2010 0 Table 3.4.2-5 Row Component Intended No. Type Function(s) Structural 1 Annubar integrity Structural 2 Annubar integrity Pressure 3 Bolting boundary Pressure 4 Bolting boundary Structural 5 Bolting integrity Structural 6 Bolting integrity Structural 7 Fan Housing integrity Structural 8 Fan Housing integrity Filter Structural 9 Housing integrity Aging Management Review Results ** Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Main Steam Leakage Control System , NUREG-Aging Effect Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Stainless Air-indoor 3.4.1-A Steel uncontrolled None None VIILI-10 41 0410 (Internal) Stainless Air-indoor 3.4.1-uncontrolled None None VIILI-10 A Steel (External) 41 Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting Integrity VIILH-4 22 B (External) Air-indoor Loss of 3.4.1-Steel uncontrolled* pre-load Bolting Integrity VIILH-5 22 B' (External) Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting Integrity VIILH-4 22 B (External) Loss of 3.4.1-Steel uncontrolled pre-load . Bolting Integrity VIILH-5 22 B (External) Gray Cast Air-indoor Loss of' External Surfaces 3.4.1-C uncontrolled VIILH-T Iron (Internal) material Monitoring 28 0404 Gray Cast Air-indoor Loss of External Surfaces 3.4.1-uncontrolled VIILH-7 A Iron (External) material Monitoring 28 Air-indoor Loss of External Surfaces 3.4.1-C Steel uncontrolled VIILH-7 (Internal) material Monitoring 28 0404 Page 3.4-66 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-5 Aging Management Review Results -Main Steam Leakage Control System Aging Effect NUREG-Agig ffctAging Management 1801 Table Notes Row Component Intended Material Environment Requiring Program Voum T item No. Type Function(s)

Management Program Volume I Item M2 Item Filter Structural Loss of External Surfaces 3.4.1-10 Steel uncontrolled of E Sra VIII.H-7 A Housing InLeiitY (External) material Monitoring 28 Air-indoor of External Surfaces 3.4.1- C 11 Piping Pressure Steel uncontrolled Loss VIII.H-7 284 0404 boundary (internal) material Monitoring 28 0404 12 Piping Pressure Steel Steam Loss of BWR Water vIII C.. 3.4.1- A boundary (Internal) material Chemistry 02 Pressure Steam Loss of Chemistry Program 3.4.1-13 Piping boundar Steel (Internal) material Effectiveness VIII.C-3 02 A Inspection Pressure Air-indoor Loss of External Surfaces 3.4.1-14 Piping boundary Steel uncontrolled material Monitoring 28 (External) Structural Air-indoor Loss of External Surfaces 3.4.1- C 15 Piping integrity Steel uncontrolled, aeil Mntrn VIII.H-7 28 04* ~~~~~~~(Internal) maeil Mntrg28 04 Air-indoor Structural Steel Andoor Loss of External Surfaces Vlll.H-7 3.4.1-u n(External) material Monitoring 28 Structural Stainless 3.4.1- A 17 Piping uncontrolled None None VIII.I-10 17 Piping integrity Steel (Internal) 41 0410 Air-indoor Structural Stainless 3.4.1-18 Piping integrity Stale uncontrolled None None VIII.1-10 41 A 18 Piinteriy Steel (External) 41 Aging Management Review Results Page 3.4-67 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-5 Aging Management Review Results -Main Steam Leakage Control System Aging Effect NUREG-Row Component Intended Material Environment . Requiring Aging Management 1801 Table Notes No. Type Function(s) . Management Program Volume 1 Item -2 Item Filter Structural Air-indoor Loss of External Surfaces 3.4.1-10 Steel . uncontrolled VIII.H-7 A Housing integrity (External) materia! Monitoring 28 . Pressure Air-indoor Loss of External Surfaces 3.4.1-C 11 Piping boundary Steel uncontrolled material Monitoring VIII.H-7 28 0404 (Internal) 12 Piping Pressure Steel Steam Loss of BWRWater VIII.C-3 3.4.1-A boundary (Internal) material Chemistry 02 Pressure Steam Loss of Chemistry Program 3.4.1-13 Piping boundary Steel (Internal) material Effectiveness VIII.C-3 02 A Inspection Pressure Air-indoor Loss of External Surfaces 3.4.1-14 Piping boundary Steel uncontrolled material Monitoring VIII.H-7 28 A (External)

Structural Air-indoor Loss of External Surfaces 3.4.1-C 15 Piping Steel uncontrolled VIII.H-7 integrity (Internal) material Monitoring 28 0404 Structural Air-indoor Loss of External Surfaces 3.4.1-16 Piping integrity Steel uncontrolled material Monitoring VIII.H-7 28 A (External) Structural Stainless Air-indoor 3.4.1-A 17 Piping integrity Steel uncontrolled None None VIIU-10 41 0410 (Internal) Structural Stainless Air-indoor* 3.4.1-18 Piping integrity Steel uncontrolled None None VIIU-10 41 A (External) Aging Management Review Results Page 3.4-67 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-5 Aging Management Review Results -Main Steam Leakage Control System 1Aging Effect NUREG-No.iype uncionc)tiAging Management 1801 Table Notes Row Component Intended Material Environment Requiring Program Voum T Item No. Type Function(s) Maaeet Program Volume 1 Item_Management 2 Item Structural Stainless Air-indoor 3.4.1- A 19 Tubing integrity Steel uncontrolled None None VIII.l-10 41 0410 9 Tubing integi(Internal) Structural Stainless Air-indoor 3.4.1-20 Tubing integrity Steel uncontrolled None None VIII.l-10 41 A 20 _Tubing _ integritySteel(External) 41 Pressure Air-indoor Loss of External Surfaces VIIIH7 3.4.1- C 21 Valve Body bonay SteelunotledVI.- boundary (Internal) material Monitoring 28 0404 22 Valve Bd Pressure Ste Steam Loss of BWR Water VIIIC3 3.4.1- A 2 a boundary (Internal) material Chemistry 02 Pressure Steam Loss of Chemistry Program 3.4.1-23 Valve Body boundary (internal) material Effectiveness VIII.C-3 02 A Inspection Air-indoor 24 Valve Body Pressure Steel uncontrolled Loss of External Surfaces VIII.H-7 3.4.1- A boundary (External) material Monitoring 28 Air-indoor 341 SrcuaAi-n o r Loss of External Surfaces 3.4.1-25 Valve Body Structural Steel uncontrolled VIII.H-7 integrity (Internal) material Monitoring 28 0404 Air-indoor Structural Stelincor Loss of External Surfaces 3.4.1-26 Valve Body integrity Steel uncontrolled material Monitoring 28 (External) mtra MoItoig2 Aging Management Review Results Page 3.4-68 January 2010 Aging Management Review Results Page 3.4-68 January, 2010 Table 3.4.2-5 Row Component Intended No. Type Function(s) Structural 19 Tubing integrity Structural 20 Tubing integrity Pressure 21 Valve Body boundary 22 Valve Body Pressure boundary Pressure 23 Valve Body boundary Pressure 24 Valve Body boundary Structural 25 Valve Body integrity Structural 26 Valve Body integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Main Steam Leakage Control System Aging Effect NUREG-Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Stainless Air-indoor 3.4.1-A Steel uncontrolled None None VIII.I-10 41 0410 (Internal)

Stainless Air-indoor 3.4.1-Steel uncontrolled* None None VIII.I-10 41 A (External) Air-indoor Loss of External Surfaces 3.4.1-C Steel uncontrolled material Monitoring VII I. H-7 28 0404 (Internal) Steel Steam Loss of BWRWater VIII.C-3 3.4.1-A (Internal) material Chemistry 02 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.C-3 02 A Inspection Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VII I. H-7 28 A (External) Air-indoor Loss of External Surfaces 3.4.1-C* Steel uncontrolled material Monitoring VIII.H-7 28 0404 (Internal) Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIII.H-7 28 A (External) Page 3.4-68 January. 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-6 Aging Management Review Results -Miscellaneous Drain System* NUREG-Aging Effect NRG Row Component Intended Aging Aging Management 1801 Table Notes No. Type Function(s)

Material Environment Requiring Program Volume 1 ,Item Management 2 Item Pressure ~~Air-indoor Ls f34!1 Bolting Pressure Steel ( xen)uncontrolled material Bolting Integrity VIII.H-4 3..2 Air-indoor Ls 1 3.4.1 Pressure Steel uncontrolled L Bolting Integrity VIII.H-5 Bolting boundary (External) pre-load 22 Structural Air-indoor Loss of 3.4.1-Boltingry Steel uncontrolled Bolting Integrity VIII.H-4 3.Boltingt (External) pre-riad 22 Air-indoor 3 Bolting Structural Steel uncontrolled Loss of Bolting Integrity VIII.H-5 3.4.- B Integrity (External) mral 22 Orifice Pressure Stainless Steam BWR Water 3.4.1-5 boundary Steel (Internal) Cracking Chemistry VIII.B2-1 13 A Pressure Stainless Steam Chemistry Program 3.4.1-6 Orifice Cracking Effectiveness VIII.B2-1 13 A boundary Steel (internal) Inspection 13 7 ii'Pressure Stainless Steam Loss of BWR Water VIII.B22 3.4.1- A Orifice boundary Steel (Internal) material Chemistry 37 Pressure Stainless Steam Loss of Chemistry Program 3.4.1-Orifice boundary Steel (Internal) material Inspection 37 Air-indoor 3.4.1-9 Orifice Pressure Stainless uncontrolled None None VIII.I-10 41 A Orieboundary Steel (External) 41 Aging Management Review Results Page 3.4-69 January 2010* Table 3.4.2-6 Row Component Intended No. Type Function(s) Pressure 1 Bolting boundary Pressure 2 Bolting boundary , Structural 3 Bolting integrity Structural 4 Bolting Integrity 5 Orifice Pressure boundary Pressure 6 Orifice boundary 7 Orifice Pressure boundary Pressure 8 Orifice boundary Pressure 9 Orifice boundary Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Miscellaneous Drain System Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes , Program Volume 1 ,Item Management 2 Item Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting Integrity VII I. H-4 22 B (External)

Air-indoor Loss of 3.4.1-Steel uncontrolled pre-load Bolting Integrity VIII.H-5 22 B (External) Air-indoor Loss of 3.4.1-Steel uncontrolled material Bolting Integrity VII I. H-4 22 B (External) Air-indoor Loss of 3.4.1-Steel uncontrolled pre-load Bolting Integrity VII I. H-5 22 B (External) Stainless Steam Cracking BWRWater VIII.B2-1 3.4.1-A Steel (Internal) Chemistry 13 Stainless Steam " Chemistry Program 3.4.1-Steel (Internal) Cracking Effectiveness VIII.B2-1 13 A Inspection Stainless Steam Loss of BWRWater VIII.B2-2 3.4.1-A Steel (Internal) material Chemistry 37 Stainless Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VII I. B2-2 37 E Inspection Stainless Air-indoor 3.4.1-uncontrolled None None VII 1.1-1 0 A Steel (External) 41 Page 3.4-69 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-6 Aging Management Review Results -Miscellaneous Drain System IAging Effect NUREG-RowMaterial Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Program Volume I ItemI Management 2 Item Structural Stainless Moist air Loss of Supplemental 10 Orifice integrity Steel (internal) material Piping/Tank N/A N/A G Inspection Structural Stainless Air-indoor 3.4.1-11 Orifice integrity Steel uncontrolled None None VIII.1-10 41 A integrity _ Steel____ (External) Stainless Steam BWR Water 3.4.1-12 Orifice Throttling Steel (Internal) Cracking Chemistry VIII.B2-1 13 A Stainless Steam Chemistry Program 3.4.1-13 Orifice Throttling Steel (Internal) Cracking Effectiveness VIII.B2-1 3A Inspection 13 14 Orifice Throttling Stainless Steam Loss of BWR Water VIII B2-2 3.4.1- A Steel (internal),- material Chemistry 37 Stainless Steam Loss of Chemistry Program 341-15e (Internal) Throttll Effectiveness VIII.B2-2 34* E 1g SteelI (internal) material Inspection 37 Pressure Steam Loss of BWR Water 3.4.1-16 Piping boundary (Internal) material Chemistry 02 Chemistry Program 3.4.1-17 Piping Pressure Semosf Effectiveness VIII.C-3 A boundary (Internal) material Inspection 02 Pressure Steam Loss of Flow-Accelerated 3.4.1-18 Piping boundary Steel (Internal) material Corrosion (FAC) VIII.C-5 29 A Aging Management Review Results Page 3.4-70 January 2010 Table 3.4.2-6 Row Component Intended* No. Type Function(s) Structural 10 Orifice integrity Structural 11 Orifice integrity 12 Orifice Throttling 13 Orifice Throttling 14 Orifice Throttling . 15 Orifice Throttling 16 Piping Pressure boundary Pressure 17 Piping boundary 18 Piping Pressure boundary Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -MisceUaneou.s Drain System Aging Effect NUREG..; Aging Management 1801 Table Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Stainless Moist air Loss of Supplemental Steel (Internal) material PipingfTank N/A N/A G Inspection Stainless Air-indoor 3.4.1-Steel uncontrolled None None VIILI-10 41 A (External)

Stainless Steam Cracking BWRWater VIII.B2-1 3.4.1-A Steel (Internal) Chemistry 13 Stainless Steam -Chemistry Program 3.4.1-Steel (Internal) Cracking Effectiveness VIII.B2-1 13 A Inspection Stainless Steam Loss of BWRWater VIII.B2-2 3.4.1-A Steel (Internal) .. material Chemistry 37 Chemistry Program Stainless Steam Loss of 3.4.1-Steel (Internal) material Effectiveness VIII.B2-2 37 E Inspection Steel Steam Loss of BWRWater VIII.C-3 3.4.1-A (Internal) material Chemistry 02 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIII.C-3 02 A Inspection Steel Steam Loss of Flow-Accelerated VIII.C-5 3.4.1-A (Internal) material Corrosion (FAC) 29 Page 3.4-70 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-6 Aging Management Review Results -Miscellaneous Drain System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s)

Management Program Volume I Item* Management _2 Item 19 Piping [Pressure Steel uAir-indoor Loss of External Surfaces 3.4.1-Suncontroled material MEnal Surf a VIII.H-7 28A..... o' x(External) .......... 2 20 Piping Pressure Stainless Steam BWR Water VIII.2-1 3.4.1-boundary Steel (Internal) Cracking Chemistry 13 Pressure Stainless Steam Cracking Chemistry Program 3.4.1-21 Piping Pressure Staless (ternal Cracking Effectiveness VIII.B2-1 13 A 21 P gboundary Steel (internal) Inspection Pressure Stainless Steam Loss of BWR Water 3.4.1-22 Piping boundary Steel (Internal) material Chemistry VIII.B2-2 37A Pressure Stainless Steam Loss of Chemistry Program 3.4.1- E 23PPipingsounary SteeleSternal) mEffectiveness VIII.B2-2 37 23 Piping boundary Steel (Internal) material Inspection Pressure Stainless Air-indoor 3.4.1-24 Piping uncontrolled None None VIII.l-10 A boundary Steel (External) 41 Structural Moist air Loss of Supplemental 25 Piping integrity Steel (Internal) material ipin Inspection 26 Piping Structural Steel Air-indoor Loss of External Surfaces VIII.H-7 3.4.1- A integrity (External) material Monitoring 28 Pressure Steam Loss of BWR Water 3.4.1-27 Strainer Body boundary (Internal) material Chemistry 02 Aging Management Review Results Page 3.4-71 January 2010 e , Table 3.4:2-6 Row Component Intended No. Type Function(s) 19 Piping Pressure boundary' 20 Piping Pressure boundary Pressure 21 Piping boundary 22 Piping Pressure boundary Pressure 23 Piping boundary Pressure 24 Piping boundary Structural 25 Piping integrity Structural 26 Piping integrity 27 Strainer Body .Pressure boundary Aging Management Review Results e e. Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Miscellaneous Drain System Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes Management Program Volume 1 Item , 2 Item Air-indoor I Steel uncontrolled Loss of External Surfaces VIILH-7 3.4.1-A (External) materia! . Monitoring 28 Stainless Steam Cracking BWR Water VIILB2-1 3.4.1-A Steel (Internal) Chemistry 13 Stainless Steam Chemistry Program 3.4.1-Steel (Internal) Cracking Effectiveness VIILB2-1 13 A Inspection Stainless Steam Loss of BWRWater VIILB2-2 3.4.1-A Steel (Internal) material ChemistryJ 37 -Stainless Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIILB2-2 37 E Inspection Stainless Air-indoor 3.4.1-uncontrolled None None VIIU-10 A Steel (External) 41 I Moist air Loss of Supplemental Steel (Internal) material PipinglTank N/A N/A -G Inspection , Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIII.H-7 28 A (External) Steel Steam Loss of BWRWater VIILC-3 3.4.1-A (Internal) material Chemistry 02 Page 3.4-71 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-6 Aging Management Review Results -Miscellaneous Drain System dAging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) i E Program Volume I Item M anage m en t 2 Item Pressure Steam Loss of Chemistry Program 3.4.1- A 28 Strainer Body boundary Steel (internal) material Effectiveness VIII.C-3 02 A bInspection 29 Strainer Bd Pressure Ste Steam Loss of Flow-Accelerated VlllC5 3.4.1- A oy boundary (Internal) material Corrosion (FAC) 29 Pressure Air-indoor Loss of External Surfaces 3.4.1-30 Strainer Body Steelbuncontroll material Monitoring VIII.H-7 28A boundary (Etriaternal)n 2 Structural Moist air Loss of Supplemental 31 Strainer Body integrity Steel (internal) material Piping/Tank N/A N/A G Inspection Air-indoor Structural Stelincoro Loss of External Surfaces 3.4.1-32 Strainer Body integrity Steelt material MonitoringVIII.H-7 A (External) mtra oioig2 33 Valve Pressure Steam Loss of BWR Water VlllC3 3.4.1- A 3 Vav boundary (Internal) material Chemistry 02 Pressure Steam Loss of Chemistry Program 3.4.1-34 Valve Body Steel Effectiveness VIII.C-3 02A 34 V y boundary (internal) material Inspection Pressure Steam Loss of Flow-Accelerated 3.4.1-35 Valve Body boundary Steel (Internal) material Corrosion (FAC) VIII.C-5 29 A Pressure Air-indoor Loss of External Surfaces 3.4.1-36 Valve Body Steel uncontrolled VIII.H-7 A 36 Vleoy boundary (External) material Monitoring 28 Aging Management Review Results Page 3.4-72 January.2010 Table 3.4.2-6 Row Component Intended No. Type Function(s) Pressure 28 Strainer Body boundary 29 Strainer Body Pressure boundary Pressure 30 Strainer Body boundary Structural 31 Strainer Body integrity Structural 32 Strainer Body integrity 33 Valve Body Pressure boundary Pressure 34 Valve Body boundary 35 Valve Body Pressure boundary Pressure 36 Valve Body boundary Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Miscellaneous Drain System Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes Management Program Volume 1 Item 2 Item Steam Loss of Chemistry Program 3.4.r .. Steel (Internal) material Effectiveness VII LC-3 02 A Inspection Steel Steam Loss of . Flow-Accelerated VIII.C-5 3.4.1-A (Internal) material Corrosion (FAC) 29 Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIILH-7 28 A (External)

Moist air Loss of Supplemental Steel (Internal) material PipinglTank N/A N/A G Inspection Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIILH-7 28 A (External) Steel Steam Loss of BWRWater VIILC-3 3.4.1-A (Internal) material Chemistry 02 Steam Loss of Chemistry Program 3.4.1-Steel (Internal) material Effectiveness VIILC-3 02 A Inspection Steel Steam Loss of Flow-Accelerated VII LC-5 3.4.1-A (Internal) material Corrosion (FAC) 29 Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled rnaterial Monitoring VIII.H-7 28 A (External) Page 3.4-72 January. 201 0 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-6 Aging Management Review Results -Miscellaneous Drain System IAging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s)

Management Program Volume I Item Managment2 Item Structural Moist air Loss of Supplemental T 37 Valve Body itrutua I Steel 1 ( al) Piping/Tank N/A N/A G inegit material Inspection Structural Air-indoor Loss of External Surfaces 3.4.1-38 Valve Body integrity Steel uncontrolled material MonitoringVIII.H-7 28_A unoteroll material IMonitoring 28 Aging Management Review Results Page 3.4-73 January 2010 Aging Management Review Results*Page 3.4-73 January 2010* Table 3.4.2-6 / Row Component Intended No. Type Function(s) Structural 37 Valve Body integrity Structural 38 Valve Body integrity Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Miscellaneous Drain System NUREG-Aging Effect Aging Management 1801 Table Material Environment Requiring Notes Management Program Volume 1 Item 2 Item Moist air Loss of Supplemental . Steel (!nterna!)

materia! PipingfTank N/A N/A G Inspection Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIII.H-7 28 A (External) . Page 3.4-73 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table 3.4.2-7 Aging Management Review Results -Reactor Feedwater System Aging Effect NUREG-RowMaterial Environment Requiring Aging Management 1801 Table No. Type Function(s) M Program Volume I Item Notes Management 2 Item Air-indoor Bolting tructural Steel uncontrolled Loss of Bolting Integrity VIII.H-4 3.4.1- B integrity (External) material 22 Air-indoor Air-indoor Loss of Botn nert IIH5 3.4.1-2 Bolting Structural Steel uncontrolled Bolting Integrity VIII.H-5 B integrity (External) pre-load 22 Treated Flow Structural Steel water > 60 0 C Loss of BWR Water VIII.D2-7 3.4.1- A Element integrity (140 OF) material Chemistry 04 0403 (Internal), Treated Chemistry Program Flow Structural Steel water > 60 °C Loss of Effectiveness VIII.D2-7 34.1- A Element integrity (140 OF) material Inspection04 0403 (Internal) Treated Flow Structural water > 60 °C Loss of Flow-Accelerated 3.4.1- A Eeet itgiy- Steel wtr60CLosf Fl-Aceaed VIII.D2-829 03 Element integrity (140 °F) material Corrosion (FAC) 29 0403 (Internal) Flow Structural Air-indoor Loss of External Surfaces 3.4.1-Element integrity Steel uncontrolled material Monitoring 28 (External) Treated 7 Piping Structural Stainless water > 60 OC BWR Water VIII.E.31 3.4.1- A integrity Steel (140 OF) Cracking Chemistry 14 (Internal) Treated Chemistry Program 8 Piping Structural Stainless water > 60 'C Cracking Effectiveness VIII.E-31 341-8 integrity Steel (140 °F) 14_ 1 1 (Internal) Inspection Aging Management Review Results Page 3.4-74 January 2010 Table 3.4.2-7 Row Component Intended No. Type Function(s) 1 Bolting Structural integrity -2 Bolting Structural integrity 3 Flow Structural Element integrity Flow Structural 4 Element integrity 5 Flow Structural Element integrity Flow Structural 6 Element integrity 7 Piping Structural integrity Structural 8 Piping integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Reactor Feedwater System Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes Program Volume 1 Item Management 2 Item Air-indoor

-Steel uncontrolled Loss of Bolting Integrity VIII.H-4 3.4.1-B (External) material 22 Air-indoor Steel uncontrolled Loss of Bolting Integrity VIII.H-5 3.4.1-B (External) pre-load 22 Treated Steel . water> 60 DC Loss of BWRWater VIII.D2-7 3.4.1-A (140 OF) material Chemistry 04 0403 (Internal) Treated Chemistry Program water:> 60 DC Loss of 3.4.1-A Steel (140 OF) material Effectiveness VIII.D2-7 04 0403 (Internal) Inspection Treated Steel water> 60 DC Loss of Flow-Accelerated VII I. D2-8 3.4.1-A (140 OF) material Corrosion (FAG) 29 0403 (Internal) Air-indoor Loss of ( External Surfaces 3.4.1-Steel uncontrolled VIII.H-7 A (External) material Monitoring 28 Treated -, Stainless water> 60 DC Cracking BWRWater VIII.E-31 3.4.1-A Steel (140 OF) Chemistry 14 (Internal) Treated Chemistry Program Stainless water> 60 DC 3.4.1-Steel (140 OF) Cracking* Effectiveness VIII.E-31 14 A (Internal) Inspection Page 3.4-74 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-7 Aging Management Review Results -Reactor Feedwater System Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s)

Management Program Volume 1 Item 2 Item 1 I Treated ° 1 Structural Stainless water > 60 IC Loss of BWR Water VIII.D2-4 3.4.1- A integrity Steel (140 -F) material Chemistry 16D0403___________ (Internal) Treated Chemistry Program 10 Piping Structural Stainless water > 60 'C Loss of Effectiveness VIII.2- 3.4.1-, A integrity Steel (140 °F) material Inspection 16 0403 (Internal) Insecio Structural Stainless Air-indoor 341-11 Piping Steel uncontrolled None None VIII.I-10 4.1- A 11 P gintegrity Steel (External) 41 Treated Structural Water > 60 'C Loss of BWR Water VIII.D2- 3.4.1- A 12 Piping integrity Steel (140 °F) material Chemistry 04 0403 (Internal) Treated Structural water > 60 °C Loss of Chemistry Program04 0 13 Piping itgty Steel 14 Fmaeil Effectiveness VIII.D2-7 3..1 A integrity (140 F) material0403 (Internal) Inspection Treated Structural water> 60 °C Loss of Flow-Accelerated 3.4.1- A 14 Piping integrity Steel (140 °F) material Corrosion (FAC) VIII.D2-8 29 0403 (Internal) 1 *Structural Air-indoor Loss of External Surfaces 3.4.1-15 Piping integrity Steel uncontrolled VIII.H-7 A i (External) material Monitoring 28 Treated Structural water > 60 'C Loss of BWR Water 3.4.1- A 16 Valve Body iSteel (140 -F) material Chemistry VIII.D2-7 04 0403 (Internal) Aging Management Review Results Page 3.4-75 January 2010* Table 3.4.2-7 Row Component Intended No. Type Function(s) 9 o* . Structural .Iprng -integrity Structural 10 Piping integrity Structural 11 Piping integrity. 12 Piping Structural integrity Structural 13 Piping integrity 14 Piping Structural integrity Structural 15 Piping integrity 16 Valve Body Structural integrity Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Reactor Feedwater System Aging Effect NUREG-Material Environment Requiring Aging Management 1801 Table Notes Management Program Volume 1 Item 2 Item Treated Stainless water> 60°C Loss of BWRWater VIII.D2-4 3.4.1-A Steel (140 oFf material Chemisiry 16 0403 (Internal)

Treated Chemistry Program Stainless water> 60°C Loss of '3.4.1-. A Steel (140 OF) material Effectiveness VIII.D2-4 16 0403 (Internal) Inspection Stainless Air-indoor 3.4.1-Steel uncontrolled None None VII 1.1-1 0 41 A (External) Treated Steel water> 60°C Loss of BWRWater VIII.D2-7 3.4.1-A (140 OF) material Chemistry 04 0403 (Internal) . Treated Chemistry Program water> 60°C Loss of 3.4.1-A Steel (140 OF) material Effectiveness VIII.D2-7 04 (internal) Inspection Treated Steel water> 60°C Loss of Flow-Accelerated VIII.D2-8 3.4.1-A (140 OF) material Corrosion (FAC) ./ 29 0403 (Internal) Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VIII.H-7 28 A (External) Treated Steel water> 60°C Loss of BWRWater VII I. D2-7 3.4.1-A (140 OF) material Chemistry 04 0403 (Internal) ." Page 3.4-75 January 2010 / Columbia Generating Station License Renewal Application Technical Information Table 3.4.2-7 Aging Management Review Results -Reactor Feedwater System TAging Effect NUREG-Rowgompnent Intnde Aging Management 1801 Table Row Component Intended1 No. Type Function(s) Material Environment Requiring Volume Item Notes Management Pr2gItem Item Treated Chemistry Program Structural water > 60 0C Loss of Effectiveness VIII.D2-7 34.1- A 17 Valve Body integrity (140 OF) material Inspection 04 0403 (internal) Iseto Treated Structural water> 60 0C Loss of Flow-Accelerated 3.4.1- A 18 Valve Body ntegrSteel (140 °F) material Corrosion (FAC) VIII.D2-8 29 0403 (Internal) Structural S Air-indoor Loss of External Surfaces 3.4.1-19 Valve Body itgty Steel uncontrolled VIII.H-7 A u n(External) material Monitoring 28 Aging Management Review Results Page 3.4-76 January 2010 Table 3.4.2-7 Row Component Intended No. Type Function(s) Structural 17 Valve Body integrity 18 Valve Body Structural integrity Structural 19 Valve Body integrity Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Reactor Feedwater System Aging Effect NUREG-Environment Aging Management 1801 Table Material Requiring Program Volume 1 Item Notes Management 2 Item Treated Chemistry Program water> 60°C Loss of 3.4.1-A Steel (140 OF) . material Effectiveness VIII.D2-7 04 0403 (Internal) . Inspection Treated Steel water> 60°C Loss of Flow-Accelerated VII I. D2-8 3.4.1-A (140 OF) material Corrosion (FAC) 29 0403 (Internal)

Air-indoor Loss of External Surfaces 3.4.1-Steel uncontrolled material Monitoring VII I. H-7 28 A (External) Page 3.4-76 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Generic Notes: A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.E Consistent with NUREG-1801 item for material, environment, and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.

G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination. 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: 0401 The Supplemental Piping/Tank Inspection will manage loss of material at the air-water interface on and within the MSRV discharge piping at the surface of the suppression pool.0402 "Dried air' is not an environment in NUREG-1 801 Chapter VIII for aluminum or stainless steel; however, for the purposes of this comparison, "Gas" is an equivalent environment. 0403 "Loss of material" is not an aging effect identified in NUREG-1801 for stainless steel exposed to "Treated water > 60 °C (140 OF);" however, loss of material is not dependent on temperature in a treated water environment, so for the purposes of this comparison, "Treated water" is an equivalent environment. Aging Management Review Results Page 3.4-77 January 2010 Aging Management Review Results Page 3.4-77 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Generic Notes: A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP. B Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP. , C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP. D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP. E Consistent with NUREG-1801 item for material, environment, and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program. F Material notin NUREG-1801 for this component.

G Environment not in NUREG-1801 for this component and material. H Aging effect not in NUREG-1801 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-1801. Plant-Specific Notes: , 0401 The Supplemental PipingfTank Inspection will manage loss of material at the air-water interface on and within the MSRV discharge piping at the surface of the suppression pool. 0402 "Dried air" is not an environment in NUREG-1801 Chapter VIII for aluminum or stainless steel; however, for the purposes of this comparison, "Gas" is an equivalent environment. 0403 "Loss of material" is not an aging effect identified in NUREG-1801 for stainless steel exposed to "Treated water> 60 DC (140 OF);" however, loss of material is not dependent on temperature in a treated water environment, so for the purposes of this comparison, "Treated water" is an equivalent environment. Aging Management Review Results Page 3.4-77 January 2010 Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes: 0404 The aging effect determination for the Air-indoor uncontrolled (Internal) environment is the same as the NUREG-1801 determination for an Air-indoor uncontrolled (External) environment because the material is the same and the internal environment is equivalent to the external environment evaluated ifi the NUREG-1801 item Monitoring of the external surface condition will be used to characterize the aging effects on the internal surfaces.0405 Bolting associated with the quenchers is stainless steel and located in the suppression pool.0406 This steel component has an external surface temperature > 212 IF. Therefore, the surface is dry and general corrosion is notan aging effect requiring management; there are also no other aging effects requiring management.0407 The Bolting Integrity Program will also manage cracking for the carbon and low-alloy (steel) bolting at the base and foundation of the CSTs due to potential for ponding or pooling of water.0408 The Buried Piping and Tanks Inspection Program will manage loss of material for the carbon steel (steel) piping from the CSTs that is enclosed in guard pipe and buried.0409 The Aboveground Steel Tanks Inspection will detect and characterize loss of material at the base of each CST in contact with the tank foundation. The aging effect determination for the Air-indoor uncontrolled (Internal) environment is the same as the NUREG-1 801 0410 b determination for an Air-indoor uncontrolled (External) environment because the material is the same and the internal environment is equivalent to the external environment evaluated in the NUREG-1801 item There are no aging effects requiring management. The aging effect determination for the Air-outdoor (Internal) environment is the same as the NUREG-1801 determination for an 0411 Air-outdoor (External) environment because the material is the same and the internal environment is equivalent to the external environment evaluated in the NUREG-1 801 item. Monitoring of the external surface condition will be used to characterize the aging effects on the internal surfaces.Aging Management Review Results Page 3.4-78 January 2010 Aging Management Review Results Page 3.4-78 January 2010 Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes: 0404 The aging effect determination for the Air-indoor uncontrolled (Internal) environment is the same as the NUREG-1801 determination for an Air-indoor uncontrolled (External) environment because the material is the same and the internal environment is equivalent to the external environment evaluated in the NUREG-1801 item Monitoring of the external surface condition will be used to characterize the aging effects on the internal surfaces. 0405 Bolting associated with the quenchers is stainless steel and located in the suppression pool. 0406 This steel component has an external surface temperature> 212 of. Therefore, the surface is dry and general corrosion is not an aging effect requiring management; there are also no other aging effects requiring management. 0407 The Bolting Integrity Program will also manage cracking for the carbon and low-alloy (steel) bolting at the base and foundation of the CSTs due to potential for ponding or pooling of water . 0408 . The Buried Piping and Tanks Inspection Program will manage loss of material for the carbon steel (steel) piping from the CSTs that is enclosed in guard pipe and buried. 0409* The Aboveground Steel Tanks Inspection will detect and characterize loss of material at the base of each CST in contact with the tank foundation. The aging effect determination for the Air-indoor uncontrolled (Internal) environment is the same as the NUREG-1801 0410 determination for an Air-indoor uncontrolled (External) environment because the material is the same and the internal environment is equivalent to the external environment evaluated in the NUREG-1801 item There are no aging effects requiring management. The aging effect determination for the Air-outdoor (Internal) environment is the same as the NUREG-1801 determination for an 0411 Air-outdoor (External) environment because the material is the same and the internal environment is equivalent to the external environment evaluated in the NUREG-1801 item. Monitoring of the external surface condition will be used 'to characterize the aging effects on the internal surfaces. Aging Management Review Results Page 3.4-78 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information

3.5 AGING

MANAGEMENT OF CONTAINMENTS, STRUCTURES, AND COMPONENT SUPPORTS 3.5.1 Introduction Section 3.5 provides the results of the aging management reviews (AMRs) for those structural components and commodities identified in Section ,2.4, Scoping and Screening Results -Structures, subject to AMR. The structures or structural commodities are described in the indicated sections.* Primary Containment [Includes Drywell, Suppression Chamber, and internal structural components] (Section 2.4.1)* Reactor Building (Includes Secondary Containment, Reactor Cavity, Refueling Area, New Fuel Storage Vault, Release Stack] (Section 2.4.2)* Standby Service Water Pump House 1A and 1 B and Spray Pond 1A and 1 B (Section 2.4.3)* Circulating Water Pump House (Section 2.4.4)* Diesel Generator Building (Section 2.4.5)" Fresh Air Intake Structure No. 1 and 2 (Section 2.4.6)* Makeup Water Pump House (Section 2.4.7)* Radwaste Control Building (Section 2.4.8)* Service Building (Section 2.4.9)* Turbine Generator Building (Section 2.4.10)* Water Filtration Building (Section 2.4.11)* Yard Structures (Section 2.4.12)* Bulk Commodities (Section 2.4.13)Table 3.5.1, Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and Ill of NUREG-1801, provides the summary of the programs evaluated in NUREG-1801 that are applicable to structural component and commodity groups in this section. Text addressing summary items requiring further evaluation is provided in Section 3.5.2.2.3.5.2 Results The following tables summarize the results of the AMR for Containments, Structures, and Component Supports.Aging Management Review Results Page 3.5-1 January 2010*

• Columbia Generating Station License Renewal Application Technical Information

3.5 AGING

MANAGEMENT OF CONTAINMENTS, STRUCTURES, AND COMPONENT SUPPORTS 3.5.1 Introduction Section 3.5 provides the results of the aging management reviews (AMR's) for those structural components and commodities identified in Section, 2.4, Scoping' and Screening -Structures, subjeCt to AMR. The structures . or structural commodities are described in the indicated sections.

• Primary Containment

[Includes Drywell, Suppression Chamber, and internal structural components] (Section 2.4.1)

• Reactor Building [Includes Secondary Containment, Cavity, Refueling Area, New Fuel Storage Vault, Release Stack] (Section 2.4.2)
• Standby Service Water Pump House 1 A and 1 B and Spray Pond 1 A and 1 B (Section 2.4.3)
• Circulating Water Pump House (Section 2.4.4)
• Diesel Generator Building (Section 2.4.5)
• Fresh Air Intake Structure No.1 and 2 (Section 2.4.6)
• Ma,keup Water Pump House (Section 2.4.7)
• Radwaste Control Building (Section 2.4.8)
• Service Building (Section 2.4.9)
• Turbine Generator Building (Section 2.4.10)
• Water Filtration Building (Section 2.4.11)
• Yard Structures (Section 2.4.12) * (Section 2.4.13) \ Table 3.5.1, Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801, provides the summary of the programs evaluated in NUREG-1801 that are applicable to structural component and commodity groups in this section. Text addreSSing summary items requiring further evaluation is provided in Section 3.5.2.2. ' 3.5.2 Results The following tables summarize the results of the AMR for Containments, Structures, and Component Supports.'" . Aging Management Review Results Page 3.5-1 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary ContainmentTable 3.5.2-2 Aging Management Review Results -Reactor Building Table 3.5.2-3 Aging Management Review Results -Standby Service Water Pump House 1A and 1 B and Spray Pond 1A and 1 B Table 3.5.2-4 Aging Management Review Results -Circulating Water Pump House Table 3.5.2-5 Aging Management Review Results -Diesel Generator Building Table 3.5.2-6 Aging Management Review Results -Fresh Air Intake Structure No. 1 and 2 Table 3.5.2-7 Aging Management Review Results -Makeup Water Pump House Table 3.5.2-8 Aging Management Review Results -Radwaste Control Building Table 3.5.2-9 Aging Management Review Results -Service Building Table 3.5.2-10 Aging Management Review Results -Turbine Generator Building Table 3.5.2-11 Aging Management Review Results -Water Filtration Building Table 3.5.2-12 Aging Management Review Results -Yard Structures Table 3.5.2-13 Aging Management Review Results -Bulk Commodities 3.5.2.1 Materials, Environments, Aging Effects Requiring Management, and Aging Management Programs The materials from which specific components and commodities are fabricated, the environments to which they are exposed, the potential aging effects requiring management, and the aging management programs used to manage these aging effects are provided for each of the above structures and structural components in the following sections.3.5.2.1.1 Primary Containment Materials Primary Containment structural components subject to AMR are constructed of the following materials:
• Aluminum* Carbon Steel Aging Management Review Results Page 3.5-2 January 2010 Columbia Generating Station License Renewal Application
• Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment Table 3.5.2-2 Aging Management Review Results -Reactor Building Table 3.5.2..:3 Aging Management Review Results -Standby Service Water Pump House 1A and 1 B and Spray Pond 1Aand 1 B Table 3.5.2-4 Aging Management Review Results -Circulating Water Pump House Table 3.5.2-5 Aging Management Review Results -Diesel Generator Building Table 3.5.2-6 Aging Management Review Results -Fresh Air Intake Structure No.1 and 2 Table 3.5.2-7 Aging Management Review Results -Makeup Water Pump House Table 3.5.2-8 Aging Management Review Results -Radwaste Control Building Table 3.5.2-9 Aging Management Review Results -Service Building Table 3.5.2-10 Aging Management Review Results -Turbine Generator Building Table 3.5.2-11 Aging Management Review Results -Water Filtration Building Table 3.5.2-12 Aging Management Review Results -Yard Structures Table 3.5.2-13 Aging Management Review Results -Bulk Commodities 3.5.2.1 Materials, Environments, Aging Effects Requiring Management, and Aging Management Programs The materials from which specific components and commodities are fabricated, the environments to which they are exposed, the potential aging effects requiring management, and the aging management programs used to manage these aging effects are provided for each of the above structures and structural components in the following sections.

3.5.2.1.1 . Primary Containment Materials Primary Containment structural components subject to AMR are constructed of the following materials:

• Aluminum
• Carbon Steel Aging Management Review Results Page 3.5-2 January 2010 *
• Columbia Generating Station License Renewal Application Technical Information
• Concrete* Elastomer* Galvanized Steel.Stainless Steel Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Environments Primary Containment structural components subject to AMR are exposed to the following environments:

• Concrete* Air-indoor 0 Treated water* Raw water Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effect associated with the Primary Containment structural components requires management:

• Loss'of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Programs The following programs are credited for managing the effects of aging on the Primary Containment structural components:

• Inservice Inspection (ISI) Program -IWE* Inservice Inspection (ISI) Program -IWF* Appendix J Program* Structures Monitoring Program" BWR Water Chemistry Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-3 January 2010* * *

• Concrete
• Elastomer
• Galvanized Steel
• Stainless Steel Columbia Generating Station License Renewal Application Technical Information Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Environments Primary Containment structural components subject to AMR are exposed to the following environments:

• Concrete
• Air-indoor
• Treated water .* Raw water Environments for bulk commodity components are addressed in Section 3.5.2.1.13 . Aging Effects Requiring Management The following aging effect associated with the Primary Containment structural components requires management:
• Loss 'of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Programs The following programs are credited for managing the effects of aging on the Primary Containment structural components:

• Inservice Inspection (lSI) Program -IWE
• Inservice Inspection (lSI) Program -IWF
• Appendix J Program
• Structures Monitoring Program
• B't'JR Water Chemistry Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-3 January 2010 Columbia Generating StationLicense Renewal Application Technical Information 3.5.2.1.2 Reactor Building Materials Reactor Building structural components subject to AMR are constructed of the following materials:

• Aluminum* Carbon Steel* Concrete* Concrete Block or Brick (freestanding or stacked shield wall)* Galvanized Steel* Stainless Steel* Boron Carbide (B4C)Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Environments Reactor Building structural components subject to AMR are exposed to the following environments:

• Soil* Air-indoor
• Air-outdoor
• Treated water* Raw water Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management -The following aging effect associated with the Reactor Building structural components requires management:

• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-4 January 2010 3.5.2.1.2 Materials Reactor Building Columbia Generating Station License Renewal Application Technical Information Reactor Building structural components subject to AMR are constructed of the following materials:

• Aluminum
• Carbon Steel
• Concrete
• Concrete Block or Brick (freestanding or stacked shiel(j wall)
• Galvanized Steel
• Stainless Steel
• Boron Carbide (B4C) *Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Environments

• Reactor Building structural components subject to AMR are exposed to the following
• environments: .
• Soil
• Air-indoor
• Air-outdoor
• Treated water
• Raw water Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effect associated with the Reactor Building structural components requires management:

• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-4 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information Aging Management Programs The following programs are credited for managing the effects of aging on the Reactor Building structural components:
• Structures Monitoring Program* Material Handling System Inspection Program BWR Water Chemistry Program* Fire Protection Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.
• 3.5.2.1.3 Standby Service Water Pump House 1A and 1 B and Spray Pond 1A and 1B Materials Standby Service Water.Pump House and Spray Pond structural components subject to AMR are constructed of the following materials:

Carbon Steel* Concrete* Galvanized Steel* Stainless Steel* Teflon Materials for bulk commodity components are addressed in Section 3.5.2.1.13. Environments Standby Service Water Pump House and Spray Pond structural components subject to AMR are exposed to the following environments:

• Soil* Air-indoor
• Air-outdoor
• Water-flowing
• Raw water Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-5 January 2010* *

• Aging Management Programs Columbia Generating Station License Renewal Application Technical Information The following programs are* credited for managing the effects of aging on the Reactor. Building structural components:
• Structures Monito.ring Program *. Material System Inspection Program
• BWR Water Chemistry Program
• Fire Protection Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.3 Standby Service Water Pump House 1 A and 1 B and Spray Pond 1 A and* 1B Materials Standby Service Water. Pump House and Spray Pond structural components subject to AMR are constructed of the following materials: Carbon Steel

• Concrete
• Galvanized Steel
• Stainless Steel
• Teflon Materials for bulk commodity components are addressed in Section

'-Environments Standby Service Water Pump House and Spray Pond strLlctural components subject to AMR are exposed to the following environments:

• Soil
• Air-indoor
• Air-outdoor
• Water-flowing
• Raw water Environments for bulk commodity components are addressed in Section 3.5.2.1.13 . Aging Management Review Results Page 3.5-5 January 2010 Columbia Generating Station License Renewal Application Technical Information Aging Effects Requiring Management The following aging effects associated with the Standby Service Water Pump House and Spray Pond structural components require management:
• Cracking* Loss of material Aging effects requiring management for bulk commodity components are addressed' in Section 3.5.2.1.13.

Aging Management Programs The following programs are credited for managing the effects of aging on the StandbyService Water Pump House and Spray Pond structural components: " Structures Monitoring Program -Water Control Structures Inspection" Inservice Inspection (ISI) Program -IWF Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13. 3.5.2.1.4 Circulating Water Pump House Materials Circulating Water Pump House structural components subject to AMR constructed of the following materials:

• Carbon Steel* Galvanized Steel* Stainless Steel* Concrete* Concrete Block Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Environments Circulating Water Pump House structural components subject to AMR are exposed to the following environments:

• Soil* Air-indoor Aging Management Review Results Page 3.5-6 January 2010 Aging Effects Requiring Management Columbia Generating Station License Renewal Application Technical Information The following aging effects associated with the Standby Service Water Pump House and Spray Pond structural components require management:
• Cracking
• Loss of material Aging effects requiring management for bulk commodity components are addressed' in Section 3.5.2.1.13.

Aging Management Programs The following programs are credited for managing the effects of aging on the Standby Service Water Pump House and Spray Pond structural components:

• Structures Monitoring Program -Water Control Structures Inspection
• Inservice Inspection (lSI) Program -IWF Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.4 Circulating Water Pump House Materials Circulating Water Pump House structural components subject to AMR constructed of the following materials:

• Carbon Steel
• Galvanized Steel
• Stainless Steel
• Concrete
• Concrete Block Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Environments Circulating Water Pump 'House structural components subject to AMR are exposed to the following environments:

• Soil
• Air-indoor Aging Management Review Results Page 3.5-6 January 2010 * *
• Columbia Generating StationLicense Renewal Application Technical Information
• Air-outdoor" Water-flowing Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effects associated with the Circulating Water Pump House structural components, require management: " Cracking* Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13. Aging Management Programs The following programs are credited for managing the effects of aging on the Circulating Water Pump House structural components:

• Structures Monitoring Program -Water Control Structures Inspection" Structures Monitoring Program -Masonry Wall Inspection
• Fire Protection Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.5 Diesel Generator Building Materials Diesel Generator Building structural components subject to AMR. are constructed of the following materials:

• Carbon Steel* Galvanized Steel* Concrete Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-7 January 2010* * *

• Air-outdoor
• Water-flowing Columbia Generating Station License Renewal Application*

Technical Information Environments for bulk commodity components are addressed in Section 3.5.2.1.13 .. Aging Effects Requiring Management The following aging effects associated with the Circulating Water Pump House structural components, require ma..nagement:

• Cracking
• Loss of material Aging effects requiring management' for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Programs The following programs are credited for managing the effects of aging on the Circulating Water Pump House structural components:

• Structures Monitoring Program -Water Control Structures Inspection
• Structures Monitoring Program -Masonry Wall Inspection
• Fire Protection Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.5 Materials Diesel Generator Building Diesel Generator Building structural components subject to AMR are constructed of the following materials: . . . I

• Carbon Steel
• Galvanized Steel
• Concrete Materials for bulk commodity components are addressed in Section 3.5.2.1.13 . Aging Management Review Results Page 3.5-7 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Environments Diesel Generator Building structural components subject to AMR are exposed to the following environments:
• Soil" Air-indoor
• Air-outdoor Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effect associated with the Diesel Generator Building structural components, requires management:

• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Programs The following programs are credited for managing the effects of aging on the Diesel Generator Building structural components:

• Structures Monitoring Program" Fire Protection Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.3.5.2.1.6 Fresh Air Intake Structure No. 1 and 2 Materials Fresh Air Intake Structure No. 1 and 2 structural components subject to AMR are constructed of the following material:* Concrete Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-8 January 2010 Aging Management Review Results Page 3.5-8 January 2010 Environments Columbia Generating Station License Renewal Application Technical Information Diesel Generator Building structural components subject to AMR are exposed to the following environments:

• Soil
• Air-indoor
• Air-outdoor Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Man'agement The following aging effect associated with the Diesel Generator Building structural components, requires management:

• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Programs The following programs are credited for'managing the effects of aging on the Diesel Generator Building structural components:

• Structures Monitoring Program
• Fire Protection Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.6 Materials Fresh Air Intake Structure No.1 and 2 Fresh Air Intake Structure No. 1 and 2 structural components subject to AMR are constructed of the following material:

• Concrete Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Environments Fresh Air Intake Structure No. 1 and 2 structural components subject to AMR are exposed to the following environments:
• Soil" Air-outdoor Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management There are no aging effects requiring management for the Fresh Air Intake Structure No.1 and 2 structural components. However, the aging management program identified below will be used to confirm the absence of significant aging effects for the period of extended operation. Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13. Aging Management Programs The following program is credited for managing the effects of aging on the Fresh Air Intake Structure No. 1 and 2 structural components:

• Structures Monitoring Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.7 Makeup Water Pump House Materials Makeup Water Pump House structural components subject to AMR are constructed of the following materials: " Carbon Steel* Galvanized Steel* Concrete Materials for bulk commodity components are addressed in Section 3.5.2.1.13. Aging Management Review Results Page 3.5-9 January 2010* *

• Environments Columbia Generating Station License Renewal Application Technical Information Fresh Air Intake Structure No. 1 and 2' structural components subject to AMR are exposed to the environments:
• Soil
• Air-outdoor Environments for bulk commodity components are addr.essed in Section 3.5.2.1.13.

Aging Effects Requiring Management " There are no aging effects requiring management for the Fresh Air Intake Structure No. 1 and 2 structural components. However, the aging management program identified below will be used to confirm the absence of significant aging effects for the period of extended operation. Aging effects requiring management for bulk commodity com'ponents are addressed in Section 3.5.2.1.13. Aging Management Programs The following program is credited for managing the effects of aging on the Fresh Air Intake Structure No.1 and 2 structural components:

• Structures Monitoring Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.7 Materials Makeup Water Pump House Makeup Water Pump House structural components subject to AMR are constructed of the following materials: .

• Carbon Steel
• Galvanized
• Concrete Materials for bulk commodity components are addressed in Section 3.5.2.1.13 . A£ling Management Review Results Page 3.5-9 January 2010 Columbia Generating Station License Renewal Application Technical Information Environments Makeup Water Pump House structural components subject to AMR are exposed to the following environments:
• Soil* Air-indoor
• Air-outdoor Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effect associated with the Makeup Water Pump House structural components, requires management:

• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Programs The following program is credited for managing the effects of aging on the MakeupWater Pump House structural components:

• Structures Monitoring Program -Water Control Structures Inspection Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.8 Radwaste Control Building Materials Radwaste Control Building structural components subject to AMR are constructed of the following materials:

• Carbon Steel" Galvanized Steel" Stainless Steel" Concrete* Concrete Block Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-10 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Environments Makeup Water Pump House structural components subject to AMR are exposed to the following environments:
• Soil
• Air-indoor
• Air-outdoor Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effect associated with the Makeup Water Pump House structural components, requires management:

• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Programs The following program is credited for managing the effects of aging on the Makeup Water Pump House structural components:

• Structures Monitoring Program -Water Control Structures Inspection Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3:5.2.1.8 Materials Radwaste Control Building Radwaste Control Building structural components subject to AMR are constructed of the following materials:

• Carbon Steel
• Galvanized Steel
• Stainless Steel
• Concrete
• Concrete Block . I Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-10 January 201 0 *

• Columbia Generating Station License Renewal Application Technical Information Environments Radwaste Control Building structural components subject to AMR are exposed to the following environments:
• Soil* Air-indoor
• Air-outdoor Environments for bulk commodity components are addressed in Section 3,5.2.1.13.

Aging Effects Requiring Management The following aging effects associated with the Radwaste Control Building structural components, require management:

• Change in material properties
• Cracking* Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Programs The following programs are credited for managing the effects of aging on the Radwaste Control Building structural components:

• Structures Monitoring Program* Structures Monitoring Program -Masonry Wall Inspection
• Fire Protection Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.3.5.2.1.9 Service Building Materials Service Building structural components subject to AMR are constructed of the following materials:
• Carbon Steel" Galvanized Steel Aging Management Review Results Page 3.5-11 January 2010* *
• Environments Columbia Generating Station License Renewal Application Technical Information Radwaste Control Building structural components subject to AMR are exposed to the following environments:
• Soil
• Air-indoor
• Air-outdoor Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

AgJng Effects Requiring Management The following aging effects associated with the Radwaste Control Building structural components, require

• Change in material properties
• Cracking * '. Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13. . Aging Management Programs The following programs are credited for managing the effects of aging on the Radwaste Control Building structural components:
• Structures Monitoring Program
• Structures Monitoring Program -Masonry Wall Inspection
• Fire Protection Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.9 Materials Service Building Building structural components subject to AMR are constructed of the following. materials:

• Carbon Steel
• Galvanized Aging Management Review Results Page 3.5-11 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Concrete Materials for bulk commodity components are addressed .in Section 3.5.2.1.13.

Environments Service Building structural components subject to AMR are exposed to the following environments:

• Soil* Air-indoor
• Air-outdoor Environments for bulk commodity components are-addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effect associated with the Service Building structural components, requires management:

• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Programs The following program is credited for managing the effects of aging on the Service Building structural components:

• Structures Monitoring Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.10 Turbine Generator Building Materials Turbine Generator Building structural components subject to AMR are constructed of the following materials:

• Carbon Steel* Galvanized Steel" Stainless Steel Aging Management Review Results Page 3.5-12 January 2010* Concrete Columbia Generating Station License Renewal Application Technical Information Materials for bulk commodity components are addressed .in Section 3.5.2.1.13.

Environments Service Building structural components subject to AMR are exposed to the following environments:

• Soil
• Air-indoor
• Air-outdoor Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effect associated with the Service Building structural components, requires management:

• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Programs The following program is credited for managing the effects of aging on the Service Building structural components: .

• Structures Monitoring Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.10 Turbine Generator Building Materials Turbine Generator Building structural components subject to AMR are constructed of the following materials:

• Carbon Steel
• Galvanized Steel
• Stainless Steel Aging Management Review Results Page 3.5-12 January 2010 * *
• Columbia Generating StationLicense Renewal Application Technical Information
• Concrete* Concrete Block* Concrete Block or Brick (freestanding or stacked shield wall)Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Environments Turbine Generator Building structural components subject to AMR are exposed to the following environments:

• Soil" Air-indoor" Air-outdoor
• Raw water Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effects associated with the Turbine Generator Building structural components, require management:

• Cracking" Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1,13.

Aging Management Programs The following programs are credited for managing the effects of aging on the Turbine Generator Building structural components:

• Structures Monitoring Program* Structures Monitoring Program -Masonry Wall Inspection
• Fire Protection Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-13 January 2010* * *

• Concrete
• Concrete Block Columbia Generating Station License Renewal Application Technicallnforniation
• Concrete Block or Brick (freestanding or stacked shield wall) Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Environments . Turbine Generator Building structural components subject to AMR are exposed to the following environments:

• Soil
• Air-indoor
• Air-outdoor
• Raw water Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effects associated with the Turbine Generator Building structural components, require management:

• Cracking
• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

' Aging Management Programs The following programs are credited for managing the effects of aging on the Turbine Generator Building structural components:

• Structures Monitoring Program
• Structures Monitoring Program -Masonry Wall Inspection
• Fire Protection Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13 . Aging Management Review Results Page 3.5-13 January 2010 Columbia Generating Station License Renewal Application Technical Information 3.5.2.1.11 Water Filtration Building Materials Water Filtration Building structural-components subject to AMR are constructed of the following materials: " Carbon Steel* Galvanized Steel* Concrete Materials for bulk commodity components are addressed in Section 3.5.2.1.13.
• Environments Water Filtration Building structural components subject'to AMR are exposed to the following environments:
• Soil* Air-indoor
• Air-outdoor Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effect associated with the Water Filtration Building structural components, requires management:

• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Program's The following program is credited for managing the effects of aging on the Water Filtration Building structural components:

• Structures Monitoring Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

Aaina Manaaement Re.vie.w Resuldts Pane_ 3 5-14 .lanuarv 2010 Columbia Generating Station License Renewal Application

• Technical Information 3.5.2.1.11 Water Filtration Building Materials Water Filtration Building structural components subject to AMR are constructed of the following materials:
• Carbon Steel
• Galvanized Steel
• Concrete Materials for bulk commodity components are addressed in Section 3.5.2.1.13

.. Environments Water Filtration Building structural components subject' to AMR are exposed to the following environments:

• Soil
• Air-indoor
• Air-outdoor Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effect associated with the Water Filtration Building structural components, requires management:

• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Program's The following program is credited for managing the effects of aging on the Water Filtration Building structural components:

• Structures Monitoring Program Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Management Review Results Page 3.5-14 January 2010. *

• Columbia Generating StationLicense Renewal Application Technical Information 3.5.2.1.12 Yard Structures Materials Structural components of yard structures subject to AMR are constructed of the following materials:

0 Aluminum* Carbon Steel* Galvanized Steel* Concrete* Earthen Structures Materials for bulk commodity components are addressed in Section 3.5.2.1.13. Environments Structural components of yard structures subject to AMR are exposed to the following environments:

• Soil" Air-indoor" Air-outdoor
• Raw water* Water-flowing Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requiring Management The following aging effects associated with structural components of evaluated yard structures require management: Cracking* Loss of form* Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13. Aging Management Review Results Page 3.5-15 January 2010* * , .

• 3.5.2.1.12 Materials Yard Structures Columbia Generating Station License Renewal Application Technical Information Structural components of yard structures subject to AMR are constructed of the following materials:
• Aluminum
• Carbon Steel
• Galvanized Steel
• Concrete
• Earthen Structures Materials for bulk commodity components are addressed in Section 3.5.2.1.13.

Environments Structural components of yard structures subject to AMR are exposed to the following environments:

• Soil
• Air-indoor
• Air-outdoor
• Raw water
• Water-flowing Environments for bulk commodity components are addressed in Section 3.5.2.1.13.

Aging Effects Requirill1g Management The following aging effects associated with structural components of *evaluated yard structures require management: .* Cracking

• Loss of form
• Loss of material Aging effects requiring management for bulk commodity components are addressed in Section 3.5.2.1.13 . Aging Management Review Results 3.5-15 January 2010

/Columbia Generating Station License Renewal Application Technical Information Aging Management Programs The following program is credited for managing the effects of aging on yard structures' structural components:

• Structures Monitoring Program* Structures Monitoring Program -Water Control Structures Inspection Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.13 Bulk Commodities Materials Structural components of bulk commodities subject to AMR are constructed of the following materials:

• Aluminum* Carbon Steel* Concrete* Elastomer* Fire Barrier materials (Ceramic fiber/ Thermolag/

Darmatt/ 3M Interam)* Fluoropolymer

• Galvanized Steel* Insulation materials (Calcium Silicate/

Fiberglass/Aluminum jacketing/ Stainless Steel Mirror insulation)

• Lubrite* Nylon" Stainless Steel Environments Structural components of bulk commodities subject to AMR are exposed to the following environments:
• Air-indoor
• Air-outdoor
• Raw water* Soil Aging Management Review Results Page 3.5-16 January 2010 Aging Management Programs Columbia Generating Station License Renewal Application Technical Information The following program is for managing the effects of aging on yard structures' structural components:
• Structures Monitoring Program
• Structures Monitoring Program -Water Control Structures Inspection Aging management programs for bulk commodity components are addressed in Section 3.5.2.1.13.

3.5.2.1.13 Bulk Commodities Materials Structural components of bulk commodities subject to AMR are constructed of the following materials:

• Aluminum
• Carbon Steel
• Con'crete
• Elastomer
• Fire Barrier materials (Ceramic fiber! Thermolag!

DarmatU 3M Interam)

• Fluoropolymer
• Galvanized Steel
• Insulation materials (Calcium Silicate!

Fiberglass!Aluminum jacketing! Stainless Steel Mirror insulation)

• Lubrite
• Nylon
• Stainless Steel Environments Structural components of bulk commodities subject to AMR are exposed to the following environments:
• Air-indoor
• Air-outdoor
• Raw water
• Soil Aging Management Review Results Page 3.5-16 January 2010 * *
• Columbia Generating Station License Renewal Application Technical Information
• Treated water Aging Effects Requiring Management The following aging effects associated with structural components of evaluated bulk commodities require management:
• Change in material properties
• Cracking/delamination
• Loss of material* Separation Aging Management Programs The following program is credited for managing the effects of aging on bulk commodities:
• BWR Water Chemistry Program , Fire Protection Program 0 Inservice Inspection (ISI) Program -IWF 0 Structures Monitoring Program 3.5.2.2 Further Evaluation of Aging Management as Recommended by NUREG-1 801 For the Columbia containment, structures, and component supports, those items requiring further evaluation are addressed in the following sections.3.5.2.2.1 PWR and BWR Containments 3.5.2.2.1.1 Aging of Inaccessible Concrete Areas The Primary Containment is a free-standing, steel pressure vessel. It utilizes the pressure suppression technique through the GE BWR Mark II over-under configuration.

The concrete mat foundation under the suppression chamber is a common foundationsupporting the steel primary containment vessel, including all-equipment and structures therein, and the Reactor Building of which the primary containment vessel is a part.The primary containment vessel and the Reactor Building enclosing the primary containment vessel are both supported on a common, reinforced concrete mat foundation. The Reactor Building foundation mat is not subject to flowing water. Seismic Category I structures and safety-related systems and components at Columbia are located above the present groundwater elevation 380 feet msl (mean sea level) and are not subject to any force effects of buoyancy and static water from this groundwater elevation. The Aging Management Review Results I Page,,3.5-17 January 2010* * *

• Treated water Aging Effects Requiring Management Columbia Generating Station License Renewal Application Technical Information The following aging effects associated with structural components of evaluated bulk commodities require malnagement:
• Change in material properties
• Cracking/delamination
• Loss of material
• Separation Aging Management Programs The following program is credited for managing the of aging on bulk commodities:
• BWR Water Chemistry Program I
• Fire Protection Program
• Inservice Inspection (lSI) Program -IWF
• Structures Monitoring Program 3.5.2.2 Further Evaluation of Aging Management as Recommended by NUREG-1801 For the Columbia containment, structures, and component' supports, those items requiring further evaluation are addressed in the following sections.

3.5.2.2.1 PWR and BWR Containments 3.5.2.2.1.1 Aging of Inaccessible Concrete Areas The Primary Containment is a free-standing, steel pressure vessel. It utilizes the pressure suppression technique through the GE BWR Mark II over-under configuration. The concrete mat foundation under the suppression chamber is a common foundation' supporting the steel primary containment vessel, including all equipment and structures therein,and the Reactor Building of which the primary containment vessel is a part. The priniary. containment vessel' and the Reactor Building enclosing the primary' containment vessel are both supported on a common, reinforced concrete mat foundation. ' The Reactor Building foundation mat is not subject to flowing water. Seismic Category I structures and safety-related systems and components at Columbia are located above the present groundwater elevation 380 feet msl (mean sea level) and are not subject to any force effects of buoyancy and static water from this groundwater elevation. The Aging Management Review Results Page ,3.5-17 January 2010 Columbia Generating Station License Renewal Application Technical Information bottom of the Reactor Building foundation mat is at elevation 400 feet 9 inches;therefore, foundation interaction with groundwater is unlikely.The below-grade environment at Columbia is non-aggressive (Chlorides < 500 ppm, Sulfates < 1,500 ppm, and pH > 5.5) and has been confirmed by water chemistry analysis results. Sampling results indicate.a groundwater pH minimum value of 6.9, chloride content maximum value of 36 ppm, and sulfate content maximum value of 323 ppm.Primary Containment foundation concrete is designed in accordance with American Concrete Institute (ACI) 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and American Society for Testing and Materials (ASTM) standards. Concrete constructed to these criteria has a low water-to-cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.) The Primary Containment concrete is not exposed to an aggressive environment and the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding aggressive chemical attack and embedded steel corrosion aging mechanisms. Therefore, increases in porosity and permeability, cracking, loss of material (spalling, scaling) due to aggressive chemical attack, and cracking, loss of bond, and loss of material (spalling, scaling) due to corrosion of embedded steel are not applicable for Primary Containment concrete in inaccessible areas.The absence of concrete aging effects is confirmed under the Structures Monitoring Program. The Inservice Inspection Program -IWL does not apply to Columbia since it is a BWR Mark II steel containment. Aging Management Review Results Page 3.5-18 January 2010 Aging Management Review Results.Page 3.5-18 January 2010/ Columbia Generating Station License Renewal Application Technical Information bottom of the Reactor Building foundation mat is at elevation 400 feet 9 inches; therefore, foundation interaction with groundwater is unlikely. The below-grade environment at Columbia is non-aggressive (Chlorides < 500 ppm, Sulfates < 1,500 ppm, and pH > 5.5) and has been confirmed by water chemistry analysis results. Sampling results indicate.a groundwater pH minimum value of 6.9, chloride content maximum value of 36 ppm,and sulfate content maximum value of 323 ppm. Primary Containment foundation concrete is designed in accordance with American Concrete .Institute (ACI) 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and American Society for Testing and Materials (ASTM) standards. Concrete constructed to these criteria has a low cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and * . provides a good quality dense concrete with a low permeability, which meets the intent of ACI201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio Since the

• average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.)

/ . The Primary Containment concrete is not exposed to an aggressive environment and the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding aggressive chemical attack' and embedded steel corrosion aging mechanisms. Therefore, increases in porosity and permeability, cracking, loss of material (spalling, scaling) due to aggressive chemical attack, and cracking, loss of bond, and loss of material (spalling, scaling) due. to corrosion' of embedded steel are not applicable for Primary Containment concrete in inaccessible areas. The absence of concrete aging effects is confirmed under the Structures Monitoring . Program. The Inservice Inspection Program -IWL does not apply to Columbia since it is a BWR Mark II steel containment.' Aging Management Review Results. . Page 3.5-18 January 2010

• Columbia Generating Station License Renewal Application Technical Information3.5.2.2.1.2 Cracks and Distortion due to Increased Stress Levels from Settlement; Reduction of Foundation Strength; Cracking and Differential Settlement due to Erosion of Porous Concrete Subfoundations, if Not Covered by Structures Monitoring Program Cracking due to settlement is not an aging effect requiring management for concrete components below grade because the total differential settlement experienced in the past 20 years is well within the permissible limits for these types of structures and no settlement has manifested itself via cracked walls or cracked foundations.

Foundations of all Columbia plant structures are supported on structural backfill. The backfill provides safe bearing for the structural foundations, and settlements are estimated to be minimal.In order to compare the calculated to actual settlement, measurement points were established at the corners of the substructure of the Reactor Building, Radwaste Qontrol Building, Spray Ponds, and along the four sides of the sub-structure of the Turbine Generator Building. These points have been monitored systematically since the beginning of construction. The settlement observation records to date for these facilities are included in the FSAR, Appendix 2.5H. The results of settlement monitoring program show that the actual maximum differential settlements are well within the estimated differential settlements and that they remain of no consequence to the design of plant structures appurtenances. The measured settlement rate in the time frame from 1986 to 1991 has virtually leveled off (i.e., zero settlement) for the, Reactor, Radwaste Control, and Turbine Generator buildings and was less than an average of 0.001 feet per year for both Spray Ponds. Therefore, commitments regarding settlement have been satisfied as any future settlements during the lifetime of the plant will not adversely affect the plant structures or appurtenances. Columbia does not employ a de-watering system in any of the site structures for control of settlement since the groundwater level at the site is sufficiently lower than the deepest foundation in the complex. The Primary Containment base foundation is not constructed of porous concrete below-grade and is not subject to flowing water.Therefore, cracks and distortion due to increased stress levels from settlement, and reduction of foundation strength, cracking, and differential settlement due to erosion of porous concrete are not applicable to the Primary Containment concrete subfoundations. 3.5.2.2.1.3 Reduction of Strength and Modulus of Concrete Structures due to Elevated Temperature ASME Code, Section III, Division 2, Subsection CC indicates that aging due to elevated temperature exposure is not significant as long as concrete general area temperatures do not exceed 150 OF and local area temperatures do not exceed 200 OF. During normal operation, areas within Primary Containment are within these temperature limits.Normal temperature limits are given in FSAR Table 3.11-1. The temperature for the Primary Containment is maintained below 150 OF during normal operation, 135 OF bulk Aging Management Review Results Aging Management Review Results Page 3.5-19 January 2010 Page 3.5-19 January 2010* *

• 3.5.2.2.1.2 Columbia Generating Station License Renewal Application . Technical Information Cracks and Distortion due to Increased Stress Levels from Settlement; Reduction of Foundation Strength; Cracking and Differential Settlement due to Erosion of Porous Concrete Subfoundations, if Not Covered by Structures Monitoring Program Cracking due to settlement is not an aging effect requiring management for concrete components below grade because the total differential settlement experienced in the past 20 years is well within the permissible limits for these. types, of structures and no settlement has manifested itself via cracked walls or cracked foun'dations.

Foundations of all Columbia plant structures are supported on structural backfilL The backfill provides safe bearing for the structural foundations, and settlements are estimated to be minimal. In order to compare the calculated to actual settlement, measurement points were established at the corners of the substructure of the Reactor Building, Radwaste Control Building, Spray Ponds, and along the four sides of the sub-structure of the Turbine Generator Building. These points have been monitored systematically since the beginning of construction. The settlement observation records to date for these facilities are included in the FSAR, Appendix 2.5H. The results of settlement monitoring program show that the actual maximum differential settlements are well within the estimated differential settlements and that they remain of no consequence to the design of plant structures appurtenances. The measured settlement rate in the time frame from 1986 to 1991 has virtually leveled off (i.e., zero settlement) for the Reactor, Radwaste Control, and Turbine Generator buildings and was less than an average of 0.001 feet per year for both Spray Ponds. Therefore, commitments regarding settlement have been satisfied as any future settlements during the lifetime of the plant will not adversely affect the plant structures or appurtenances. Columbia does not employ a de-watering system in any of the site structures for control of settlement since the groundwater level at the site is sufficiently lower* than the deepest fou.ndation in the complex. The Primary Containment base foundation is not constructed of porous concrete below-grade and is not subject to flowing water. Therefore, cracks *and distortion due to increased stress levels from settlement, and reduction of foundation strength, cracking, and differential settlement due to erosion of porous concrete are not applicable to the Primary Containment concrete subfoundations. 3.5.2.2.1.3 Reduction of Strength and Modulus of Concrete Structures due to Elevated Temperature . ASME Code, Section III, DiVision 2, Subsection CC indicates that aging due to elevated temperature exposure is not significant as long as concrete general area temperatures . do not exceed 150 OF and local area temperatures do not exceed 200 OF. During normal operation, areas within Primary Containment are within these temperature limits. Normal temperature limits are given in FSAR Table 3.11-1. The temperature for the Primary Containment is maintained below 150 OF normal operation, 135 OF bulk Aging Management Review Results . Page 3.5-19 \ January 2010 Columbia Generating StationLicense Renewal Application Technical Information average maximum. The area beneath the RPV is a localized area with a maximum temperature limit of 165 OF, which is below the 200 OF threshold for localized areas.Piping contained in the Primary Containment is not in direct contact with concrete and the concrete temperature surrounding hot penetrations, such as the main steam line penetrations, is maintained at less than or equal to 200 IF. Columbia specificationscontain required insulation thicknesses for high temperature process piping.Consequently, localized hot spots on concrete are not expected from exposure to adjacent piping.Therefore, reduction of strength and modulus of concrete due to elevated temperatures are not aging effects requiring management for the Primary Containment concrete components. 3.5.2.2.1.4 Loss of Material due to General, Pitting, and Crevice Corrosion Loss of material due to corrosion in steel elements of accessible areas is managed by the Inservice Inspection (ISI) Program -IWE and the Appendix J Program. In addition to the Inservice Inspection (ISI) Program -IWE and the Appendix J Program, loss of material due to pitting and crevice corrosion for steel elements exposed to treated water (i.e., suppression chamber) is managed by the BWR Water Chemistry Program.Loss of material due to corrosion in steel elements of inaccessible areas is not significant based on the following information. The GE BWR Mark II steel Primary Containment is located within the Reactor Building and is protected from weather. The Primary Containment consists of an upper drywell and a lower suppression pool. The Primary Containment does not have boron reactivity control. The drywell and suppression pool atmosphere is inerted with nitrogen during normal operation. These are all positive influences for limiting loss of material due to corrosion in accessible and inaccessible areas.The drywell floor peripheral seal is made of stainless steel and is welded to the primary containment vessel and to the underside of the circular closure girder embedded in the drywell floor. There are no concrete to metal moisture barriers at the drywell floor.A sand filled pocket area is provided at the surrounding exterior of the primary containment vessel near the base. The sand filled pocket area is used to collect any drainage between the primary containment vessel exterior and the biological shield wall.An embedded steel closure ring is installed on the top of the sand filled transition area.Due to the possibility of containment shell degradation from corrosion induced by a moist environment in the sand pocket region, Columbia has committed to monitor humidity levels in this region. Columbia has implemented a procedure to survey the relative humidity of air drawn from within the containment annulus sand pocket region.[Reference NRC Accession Number ML042530061] Aging Management Review Results Page 3.5-20.January2010 Columbia Generating Station License Renewal Application Technical Information average maximum. The area beneath the RPV is a localized area with a maximum temperature limit of 165 of, which is below the 200 of threshold for localized areas. Piping contained in the Primary Containment is not in direct contact with concrete and the concrete temperature surrounding hot penetrations, such as the main steam line penetrations, is maintained at less than or equal to 200 of. Columbia specifications contain required insulation thicknesses for high temperature process piping. Consequently, localize9 hot spots on concrete are not expected from exposure to adjacent piping. , Therefore, reduction of strength and modulus of concrete due to elevated temperatures are not aging effects requiring management for the Primary Containment concrete components. 3.5.2.2.1.4 Loss of Material due to General, Pitting, and Crevice Corrosion Loss of material due to corrosion in steel elements of accessible areas is managed by the Inservice Inspection (lSI) Program -IWE and the Appendix J Program. In addition to the Inservice Inspection (lSI) Program -IWE and the Appendix J Program, loss of material due to pitting and crevice corrosion for steel elements exposed to treated water (i.e., suppression chamber) is managed by the BWR Water Chemistry Program.

• Loss of material due to corrosion in steel elements of inaccessible areas is not
• significant based on the following information.

The GE BWR Mark II steel Primary Containment is located within the Reactor Building and is protected from weather. The Primary Containment consists of an upper drywell a lower suppression pool. The Primary Containment does not have boron reactivity control. The drywell and suppression pool atmosphere is inerted with nitrogen during normal operation. These are all positive influences for limiting loss of material due to corrosion in accessible and inaccessible areas. The drywell floor peripheral seal is made of stainless steel and is welded to the primary containment vessel and to the underside of the circufar closure girder embedded in the drywell floor. There are no concrete to metal moisture barriers at the drywell floor. A sand filled pocket area is provided at the surrounding exterior of the primary containment vessel near the base. The sand filled pocket area is used to collect any drainage between the primary containment vessel exterior and the biological shield wall. An embedded steel closure ring is installed on the top of the sand filled transition area. Due to the possibility of containment shell degradation from corrosion induced by a moist environment in the sand pocket region, Columbia has committed to monitor humidity levels in this region. Columbia has implemented a procedure to survey the relative humidity of air drawn from within the containment annulus sand pocket region. [Reference NRC Accession Number ML042530061] Aging Management Review Results Page 3.5-20 January 2010

• Columbia Generating Station License-Renewal Application Technical Information As a result of the design features and the committed surveillance indicated above, significant corrosion of inaccessible areas of the Primary Containment is not expected.The continued monitoring of the drywell for loss material due to general, pitting, andcrevice corrosion through the Inservice Inspection (ISI) Program -IWE and Appendix JProgram provides reasonable assurance that loss of material in inaccessible areas of the drywell is insignificant and will be detected prior to the loss of an intended function.3.5.2.2.1.5 Loss of Prestress due to Relaxation, Shrinkage, Creep, and Elevated Temperature The Primary Containment is a GE BWR Mark II steel containment design. There are no prestressed tendons associated with the Primary Containment design.As a result of the Primary Containment design, loss of prestress forces due to relaxation, shrinkage, creep, and elevated temperature is not an aging effect applicable to the Primary Containment..

3.5.2.2.1.6 Cumulative Fatigue DamageThis NUREG-1800 discussion involves metal fatigue of steel elements, such as containment penetration sleeves and bellows, vent lines, vent line bellows,'vent header, and downcomers.I The containment design includes penetrations, hatches, drywell head, downcomer vents, safety relief valve (SRV) discharge piping, and SRV quenchers. Containment process line penetrations are of welded steel construction without expansion bellows, gaskets, or sealing compounds and are an integral part of the construction. Time-limited aging analyses are evaluated in accordance with 10 CFR 54.21(c) as documented in Section 4. Fatigue time-limited aging analyses are evaluated as documented in Section 4.6. 3.5.2.2.1.7 Cracking due to Stress Corrosion Cracking (SCC)Stress corrosion cracking (SCC) requires a combination of a corrosive environment, susceptible materials, and high tensile stresses.The primary containment penetrations are 'of welded steel construction without expansion bellows, gaskets, or sealing compounds and are an integral part of the construction. The penetration sleeves, vent headers, and downcomers are fabricated from carbon steel.(1) SCC is not an applicable aging effect for the primary containment penetration sleeves, vent line headers, or downcomers because they are carbon steel components not susceptible to SCC.Aging Management Review Results Page 3.5-2 1 January 2010 Aging Management Review, Results Page 3.5-21 January 2010*

• Columbia Generating Station License 'Renewal Application Technical Information As a result of the design features and the committed surveillance indicated above, significant corrosion of inaccessible areas of the Primary Containment is not expected.

The continued monitoring of the drywell for loss material due to general, pitting, and crevice corrosion the Inservice Inspection (lSI) Program -IWE and Appendix J Program provides reasonable assurance that loss of material in inaccessible areas of the drywell is insignificant and will be detected prior to the loss of an intended function. 3.5.2.2.1.5 Loss of Prestress due to Relaxation, Shrinkage, Creep, and Elevated Temperature The Primary is a GE BWR Mark II steel containment design. There are no prestressed tendons associated with the Primary Containment design. As a result of the Primary Containment design, loss of prestress forces due to relaxation, shrinkage, creep, and elevated temperature is not an aging effect applicable to the Primary Containment., 3.5.2.2.1.6 Cumulative Fatigue' Damage This NUREG-1800 discussion involves metal fatigue of steel elements, such as containment penetration sleeves and bellows, vent lines, vent line bellows/vent header, and downcomers.) The containment design includes penetrations, hatches, drywell head, downcomer vents, safety relief valve (SRV) discharge piping, and SRV quenchers. process line penetrations are of welded construction without expansion bellows, gaskets, or sealing compouhds and are an integral part of the construction. TiiTle-limited aging analyses are ,evaluated in accordance with 10 CFR 54.21 (c) as documented in Section 4. Fatigue time-limited aging analyses are evaluated as documented in Section 4.6. 3.5.2.2.1.7 Cracking due to Stress Corrosion Cracking (SCC) Stress corrosion cracking (SCC) requires a combination ofa corrosive environment, susceptible materials, Clnd high tensile stresses. The primary containment penetrations are 'of welded steel construction without expansion bellows, galskets, or sealing compounds and are an integral part of the construction. The penetration sleeves, vent headers, and downcomers are fabricated from carbon steel. ' (1) SCC is not an applicable aging effect for the primary containment penetration sleeves, vent line headers, or downcomers because they are carbon steel components not susceptible to SCC. Aging Management Review Results Page 3.5-21 January 2010 Columbia Generating Station License Renewal Application Technical Information (2) To be susceptible to SCC, stainless steel must be subject to both high temperature (>140 OF) and an aggressive chemical environment. SCC is not an applicable aging effect for dissimilar metal welds in the primary containment penetration sleeves since the'welds are located inside the primary containment drywell or outside the drywell (within the Reactor Building), and are not subject to an aggressive chemical environment. The Primary Containment is designed to permit appropriate periodic inspection of all penetrations. The design includes provisions for periodic testing at containment design pressure of the leaktightness of pressure containing or leakage limiting boundaries such as air locks, door seals, penetrations, drywell head, and access hatches.A review of Columbia operating experience indicates that. cracking due to SCC has not been a concern for the steel containment pressure boundary. As a result, cracking due to SCC is not applicable for the Primary Containment pressure boundary.For the steel elements of containment that are part of the IWE pressure boundary; both the Inservice Inspection (ISI) Program -IWE and the Appendix J Program are used to monitor for degradation. 3.5.2.2.1.8 Cracking due to Cyclic Loading Columbia penetrations do not use expansion bellows, and penetration sleeves are fabricated of carbon steel.Cracking of metal components as a result of cyclic loads is a potential aging effect. However, review of the Columbia containment and associated operating experience concluded that cyclic loading from plant heatups and cooldowns, containment testing, and system vibration was very low or limited in numbers of cycles; and, therefore, additional methods of detecting postulated cracking are not warranted. Note that the cyclic loading' of steel elements has been analyzed as a time-limited aging analysis;refer to Section 3.5.2.2.1.6 above.For the steel elements of containment that are part of the IWE pressure boundary; both the Inservice Inspection (ISI) Program -IWE and the Appendix J Program are used to monitor for degradation. A review of Columbia operating experience indicates that cracking due to cyclic loading has not been a concern for steel containment pressure boundary, components. 3.5.2.2.1.9 Lossof Material (Scaling, Cracking, and Spalling) due to Freeze-Thaw The Primary Containment is a GE BWR Mark II steel containment design located within the Reactor Building. Loss of material (scaling, cracking, and spalling) due to freeze-thaw is applicable only to concrete containments exposed to weather.Aging Management Review Results Page 3.5-22 January 2010 Columbia Generating Station License Renewal Application Technical Information (2) To be susceptible to SCC, stainless steel must be subject to both high temperature (>140 OF) and an aggressive chemical environment. SCC is not an applicable aging effect for dissimilar metal welds in the primary containment penetration sleeves since the 'Welds are located inside the primary containment drywell or outside the drywell (within the Reactor Building), and are not subject to an aggressive chemical environment. The Primary Containment is designed to permit appropriate periodic inspection of all penetrations. The design includes provisions for periodic testing at containment design pressure of the leaktightness of pressure containing or leakage limiting boundaries such as air locks, door seals, penetrations, drywell head, and access hatches .. A review of Columbia operating experience indicates that cracking due to SCC has not been a concern for the steel containment pressure boundary. As a result, cracking due to SCC is not applicable for the Primary Containment pressure boundary. For the steel elements of containment that are part of the IWE pressure boundary; both the Inservice Inspection (lSI) Program -IWE and the Appendix J Program are used to monitor for degradation. 3.5.2.2.1.8 Cracking due to Cyclic Loading Columbia penetrations do not use expansion bellows, and penetration sleeves are fabricated of carbon steel. Cracking of metal components as a* result of cyclic loads is a potential aging effect. However, review of the Columbia containment and associated operating experience concluded that cyclic loading from plant heatups and cooldowns, containment testing, and system vibration was very low or limited in numbers of cycles; and, therefore, additional methods of detecting postulated cracking are not warranted. Note that the cyclic loading' of steel elements has been analyzed as a time-limited aging analysis; refer to Section 3.5.2.2.1.6 above. For the steel elements of containment that are part of the IWE pressure boundary; both the Inservice Inspection (lSI) Program -IWE and the Appendix J Program are used to monitor for degradation. A review of Columbia operating experience indicates that cracking due to cyclic loading has not been a concern for steel containment pressure boundary components. 3.5.2.2.1.9 Loss'of Material (Scaling, Cracking, and Spalling) due to Freeze-Thaw The Primary Containment is a GE BWR Mark II steel containment design located within . the Reactor Building. Loss of material (scaling, cracking, and spalling) due to thaw is applicable only to concrete .containments exposed tp weather. Aging Management Review Results Page 3.5-22 January 2010 / * *

• Columbia Generating StationLicense Renewal Application Technical Information Therefore, loss of material (scaling, cracking, and spalling) due to freeze-thaw is not anaging effect applicable to the Primary Containment.

3.5.2.2.1.10 Cracking due to Expansion and Reaction with Aggregate, and Increase in Porosity and Permeability due to Leaching of Calcium Hydroxide P5rimary Containment concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low water-to-cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using thematerials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.) Columbia requires that concrete aggregates conform to ASTM C33 and that the potential reactivity of aggregates be acceptable based on testing in accordance with the Standard Test Method for Potential Alkali Reactivity of Cement-Aggregate Combinations (Mortar-Bar Method) (ASTM C227) or the Standard Test Method for Potential Alkali-Silica Reactivity of Aggregates (Chemical Method) (ASTM C289).Columbia specifications for concrete prohibit the use of calcium chloride in the concrete mix design.Leaching of calcium hydroxide from reinforced concrete becomes significant only if the concrete is exposed to flowing water. Seismic Category I structures and safety-related systems and components at Columbia are located above the present groundwater elevation 380 feet msl (mean sea level) and are not subject to any force effects of buoyancy and static water from this groundwater elevation. The bottom of the Reactor Building foundation mat is at elevation 400 feet 9 inches; therefore, foundation interaction with groundwater is unlikely. The Primary Containment concrete is not exposed to flowing water and the design and construction of the Primary Containment concrete is in accordance with accepted ACI Standards, thereby precluding expansion and reaction with aggregate and leaching of calcium hydroxide aging mechanisms. Ther'efore, cracking due to expansion and reaction with aggregate, and increase in porosity and permeability due to leaching of calcium hydroxide are not aging effects requiring management for primary concrete components. Aging Management Review Results Page 3.5-23 January 2010 Aging Management Review Results Page 3.5-23 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Therefore, loss.of material (scaling, cracking, and spalling) due to freeze-thaw is notan aging effect applicable to the Primary Containment.

3.5.2.2.1.10 Cracking due to Expansion and Reaction with Aggregate, and Increase in , Porosity and Permeability due to Leaching of Calcium Hydroxide Primary Containment concrete is designed in accordance with.ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low cement ratio of less than 0.50 and an air entrainment between 3 and .6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.) Columbia requires that concrete aggregates conform to ASTM C33 and that the potential reactivity of aggregates be acceptable based on testing in accordance with the Standard Test Method for Potential Alkali Reactivity of Cement-Aggregate Combinations (Mortar-Bar Method) (ASTM C227) or the Standard Test Method for Potential Alkali-Silica Reactivity of Aggregates (Chemical Method) (ASTM C289). Columbia specifications for concrete prohibit the use of calcium chloride in the concrete mix design. Leaching of calcium hydroxide from reinforced concrete becomes significant only if the concrete is exposed to flowing water. Seismic Category I structures and safety-related systems and components at Columbia are located above the present groundwater elevation 380 feet msl (mean sea level) and are not subject to any force of buoyancy and static water from this groundwater elevation. The bottom of the Reactor Building foundation mat is at elevation 400 feet 9 inches; therefore, foundation interaction with groundwater is unlikely. The Primary Containment concrete is not exposed to flowing water and the design and construction of the Primary Containment concrete is In accordance with accepted ACI Standards, thereby precluding expansion and reaction with aggregate and leaching of calcium hydroxide aging mechanisms. Therefore, cracking due to expansion and reaction with aggregate, and increase in porosity and permeability due to leaching of calcium hydroxide are not aging effects requiring management for primary concrete components . Aging Management Review Results Page 3.5-23 January 2010 Columbia Generating Station License Renewal Application Technical Information The absence of concrete aging effects is confirmed under the Structures Monitoring Program.3.5.2.2.2 Safety-Related and Other Structures and Component Supports 3.5.2.2.2.1 Aging of Structures Not Covered by Structures Monitoring Program The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in accordance with NRC position on managing concrete, even if the AMR did not identify aging effects requiring management. NRC Interim Staff Guidance (ISG)-3 for aging management-of concrete elements determined that concrete structures and components that are in the scope of license renewal are subject to visual inspection for the period of extended operation. Accordingly, Columbia complies with the staff guidance and concrete structures and components that are in the scope of license renewal include an aging management program to provide confirmation of the absence of aging effects requiring management. Columbia concurs with Interim Staff Guidance ISG-3 that sound engineering practices during material (concrete mix) design and construction together with sound inspection programs, in which the performance and condition of plant structures are periodically evaluated and monitored, are both necessary to maintain the serviceability of concrete nuclear structures. Additional discussion of specific aging effects and mechanisms follows.(1) Cracking, loss of bond, and loss of material (spalling, scaling) due to corrosion of embedded steel for Groups 1-5, 7, 9 structures Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low water-to-cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1. inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.) The below-grade environment is non-aggressive (Chlorides < 500 ppm, Sulfates< 1,500 ppm, and pH > 5.5) and has been confirmed by water chemistry analysis results. Sampling results indicated groundwater pH minimum value of 6.9, chloride content maximum value of 36 ppm, and sulfate content maximum value of 323 ppm.Aging Management Review Results Page 3.5-24 January 2010 Columbia Generating Station License Renewal Application Technical Information The absence of concrete aging effects is confirmed under the Structures Monitoring Program. 3.5.2.2.2 Safety-Related and Other Structures and Component Supports 3.5.2.2.2.1 Aging of Structures Not Covered by Structures Monitoring Program The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in accordance with NRC position on managing concrete, even if the AMR did not identify aging effects requiring management. NRC Interim Staff Guidance (ISG)-3 for aging management' of concrete elements determined that concrete structures and components that are in the scope of license renewal are subject to visual inspection for the period of extended operation. Accordingly, Columbia complies with the staff guidance and concrete structures and components that are in the scope of license renewal include an aging management program to provide confirmation of the absence of aging effects requiring management. Columbia concurs with Interim Staff Guidance , ISG-3 that sound engineering practices during material (concrete mix) design and construction together with sound inspection programs, in which the performance and condition of plant structures are periodically evaluated and monitored, are both necessary to maintain the . serviceability of concrete nuclear structures. Additional discussion of specific aging effects and mechanisms follows. (1) Cracking, loss of bond, and loss of material (spallirig, scaling) due to corrosion of embedded steel for Groups 1-5, 7, 9 structures Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1, inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches 'tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.) The below-grade environment is non-aggressive (Chlorides < 500 ppm, Sulfates < 1,500 ppm, and pH > 5.5) and has been confirmed by water chemistry analysis results. Sampling results indicated groundwater pH minimum value of 6.9, chloride content maximum value of 36 ppm, and sulfate content maximum value of 323 ppm. Aging Management Review Results Page 3.5-'24 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Annual rain water data summary from the National Atmospheric Deposition program/National Trends Network (sample well located in Columbia River Gorge Skamania County) indicates the pH of precipitation sampled was 5.4, which is mildly acidic. Concrete components exposed to air-outdoor has proper drainage and slopedesign that limits the duration that concrete is exposed to mildly acidic rain water. The external surfaces are not continuously wetted (annual precipitation only amounts to less than 7 inches) or exposed to an aggressive ambient environment (such as a saltwater atmosphere, sulfur dioxide, etc.) or industrial locations.

Rain water results in exposure for only intermittent periods of time; therefore, its mildly acidic aggressiveness is non-significant. The concrete components below grade are not exposed to an aggressive environment and the design and construction of the concrete is in accordance .with accepted ACI Standards, thereby precluding embedded steel corrosion aging mechanism. Therefore, cracking, loss of bond, and loss of material (spalling, scaling) due to corrosion of embedded steel are not aging effects requiring management for the concrete structure components. (2) Increase in porosity and permeability, cracking, loss of material (spalling, scaling)due to aggressive chemical attack for Groups 1-5, 7, 9 structures Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low water-to-cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however formassive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.) The below-grade environment is non-aggressive (Chlorides < 500 ppm, Sulfates< 1,500 ppm, and pH > 5.5) and has been confirmed by water chemistry analysis results. Sampling results indicated groundwater pH minimum value of 6.9, chloride content maximum value of 36 ppm, and sulfate content maximum value of 323 ppm.Annual rain water data summary from the National Atmospheric Deposition Program/National Trends Network (sample well located in Columbia River Gorge Skamania County) indicates the pH of precipitation sampled was 5.4, which is mildly Aging Management Review Results Page 3.5-25 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Annual rain water data summary from the National Atmospheric Deposition Program/National Trends Network (sample well located in Columbia River Gorge Skamania County) indicates the pH of precipitation sampled was 5.4, which is mildly acidic. Concrete components exposed to air-outdoor has proper drainage and slope design that limits the duration that concrete is exposed to mildly acidic rain water. The external surfaces are not continuously wetted (annual precipitation only amounts to less than 7 inches) or exposed to an aggressive ambient environment (such as a saltwater atmosphere, sulfur dioxide, etc.) or industrial locations.

Rain water results in exposure for only intermittent periods of time; therefore, its mildly acidic aggressiveness is significant. The concrete components below grade are not exposed to an aggressive environment and the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding embedded steel corrosion aging mechanism. Therefore, cracking, loss of bond, and loss of material (spalling, scaling) due to corrosion of embedded steel are not aging effects requiring management for the concrete structure components. . 1 (2) Increase in porosity and permeability, cracking, loss of material (spalling, scaling) due to aggressive attack for Groups 1-5, 7, 9 structures Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and . provides a good quality dense concrete with a low permeability, which meets the intent of ACI (Note: Columbia does not specify wat'er-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to .. cement ratio is established, by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.) The below-grade environment is non-aggressive (Chlorides < 500 ppm, Sulfates < 1,500 ppm, and pH > 5.5) and has been confirmed by water chemistry analysis results. Sampling results indicated groundwater pH minimum value of 6.9, chloride content maximum value of 36 ppm, and sulfate content maximum value of 323 ppm. Annual rain water data summary from the National Atmospheric Deposition Program/Nati.onal Trends Network (sample well located in Columbia River Gorge Skamania County) indicates the pH of precipitation sampled was 5.4, which is mildly Aging Management Review Results Page January 2010 Columbia Generating Station License Renewal Application Technical Information acidic. Concrete components exposed to air-outdoor has proper drainage and slope design that limits the duration that concrete is exposed to mildly acidic rain water. The external surfaces are not continuously wetted (annual precipitation only amounts to less than 7 inches) or exposed to an aggressive ambient environment (such as a saltwater atmosphere, sulfur dioxide, etc.) or industrial locations. Rain. water results in exposure for only intermittent periods of time; therefore, its mildly acidic aggressiveness is non-significant. The concrete components below grade are not exposed to an aggressive environment and the design and construction of the concrete is in accordance with accepted ACI Standards thereby precluding aggressive chemical attack aging mechanism. There are also aggressive chemicals 'stored at the plant and system leakage that could cause structural components to be exposed to chemicals is possible. However, accidental chemical spills are negligible since spills are cleaned up quickly in accordance with plant housekeeping procedures. System leakages are event driven and are not expected to continue for the extensive periods required ý for concrete degradation, and repairs would be made prior to loss of intended function.Therefore, increase in porosity and permeability, cracking, loss of material (spalling, scaling) due to aggressive chemical attack are not aging effects requiring management for concrete structure components below grade.However, the Structures Monitoring Program will include review of site groundwater and raw water pH, chlorides, and sulfates in order to validate that the below-grade environment remains non-aggressive during the period of extended operation. (3) Loss of material due to corrosion for Groups 1-5, 7, 8 structures The Structures Monitoring Program is credited for aging management of loss of material due to corrosion for Columbia Groups 1-5, 7 and 8 structures. Tanks subject to AMR are evaluated with the respective mechanical systems. Tank anchorages are managed by the Structures Monitoring Program.(4) Loss of material (spalling, scaling) and cracking due to freeze-thaw for Groups 1-3, 5, 7-9 structures Columbia is located in an area where weathering conditions are moderate (weathering index 100 to 500 day-inch per year). The structures are designed with proper drainage and slope such that ponding or prolonged exposure to standing water on concrete surfaces is not significant. Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low water-to-Aging Management Review Results Page 3.5-26 January 20i 0 Columbia Generating Station License Renewal Application Technical Information acidic. Concrete components exposed to air-outdoor has proper drainage and slope design that limits the duration that concrete is exposed to mildly acidic rain water. The external surfaces are not continuously wetted (annual precipitation only amounts to less than 7 inches) or exposed to an aggressive ambient environment (such as a saltwater atmosphere, sulfur dioxide, etc.) or industrial locations. Rain. water results in exposure for only intermittent periods of time; therefore, its mildly acidic aggressiveness is significant. The concrete components below grade are not exposed to an aggressive environment and the design and construction of the concrete is in accordance with accepted ACI Standards thereby precluding aggressive chemical attack aging mechanism. There are also aggressive chemicals 'stored at the plant and system leakage that could cause structural components to be exposed to chemicals is possible. However, accidental chemical spills are negligible since spills are cleaned up quickly in accordance with plant housekeeping procedures. System leakages are event driven and are not expected to continue for the extensive periods required' for concrete degradation, and repairs would be made prior to loss of intended function. Therefore, increase in porosity and permeability, cracking, loss of material (spalling,

• scaling) due to aggressive chemical attack are not aging effects requiring management
• for concrete structure components below grade. However, the Structures Monitoring Program will include review of site groundwater and raw water pH,' chlorides, and sulfates in order to validate that the below-grade environment remains during the period of extended operation.

(3) Loss of material due to corrosion for Groups 1-5, 7, 8 structures The Structures Monitoring Program is credited for aging management of loss of material due to corrosion for Columbia Groups 1-5, 7 and 8 structures. Tanks subject to AMR are evaluated with the respective mechanical systems. Tank anchorages are managed by the Structures Monitoring Program. (4) Loss of material (spalling, scaling) and cracking due to freeze-thaw for Groups 1-3, 5, 7-9 structures Columbia is located in an area where weathering conditions are moderate (weathering index 100 to 500 day-inch per year). The structures are designed with proper drainage and slope such that ponding or prolonged exposure to standing water on concrete surfaces is not significant. Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low water-to-Aging Management Review Results , Page 3,5-26 January 2010

• Columbia Generating Station License Renewal Application Technical Information cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete, which results in good freeze-thaw and sulfate resistance.)

The design and construction of the concrete is in accordance with accepted ACI Standards that preclude freeze-thaw aging mechanism. Therefore, loss of material (spalling, scaling) and cracking due to freeze-thaw are not aging effects requiring management for concrete structure components.(Note that loss of material (spalling, scaling) and cracking due to freeze-thaw are aging effects requiring management for Columbia water control structures (Group 6 structures) exposed to raw water because the concrete located in water control structures may become saturated and therefore could be susceptible to freeze-thaw. Freeze-thaw on water control structures typically manifest near the water line; concrete component submerged in raw water (e.g., spray pond foundation) is not susceptible to freeze-thaw. Columbia plant operating experience has confirmed freeze-thaw degradation on concrete exposed to raw water.)(5) Cracking due to expansion and reaction with aggregates for Groups 1-5, 7-9 structures Columbia design specifications require that concrete aggregates conform to ASTM C33 and that the potential reactivity of aggregates be acceptable based on testing in accordance with ASTM Standard Test Method for Potential Alkali Reactivity of Cement-Aggregate Combinations (Mortar-Bar Method) (ASTM C227) or Standard Test Method for Potential Alkali-Silica Reactivity of Aggregates (Chemical Method) (ASTM C289).The design and construction of the concrete is in accordance with accepted ACI Standards that preclude the expansion and reaction with aggregate aging mechanism. Therefore, cracking due to expansion and reaction with aggregates is not an aging effect requiring management for concrete structure components. Aging Management Review Results , Page 3.5-27 January 2010* *

• Columbia Generating Station license Renewal Application Technical Information cement ratio of less than 0.50 and an air entrainment between 3 and .6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete, which results in good freeze-thaw and sulfate resistance.}

The design and construction of the concrete is in accordance with accepted ACI Standards that preclude freeze-thaw' aging mechanism. Therefore, loss of (spalling, scaling) and cracking due to freeze-thaw are not aging effects requiring management for concrete structure components. (Note that loss of material (spalling, scaling) and cracking due to freeze-thaw are aging effects requiring management for Columbia water control structures (Group 6 structures) exposed to raw water because' the concrete located in water control structures may become saturated and therefore could be susceptible to freeze-thaw. Freeze:"thaw on water control structures typically manifest near the water line; concrete component submerged in raw water (e.g., spray pond foundation) is not susceptible to freeze-thaw. Columbia plant operating experience has confirmed freeze-thaw degradation on concrete exposed to raw water.} (5) Cracking due to expansion and reaction with aggregates for Groups 1-5, 7-9 structures Columbia design specifications require that concrete aggregates conform to ASTMC33 and that the potential reactivity of aggregates be acceptable based on testing in accordance with ASTM Standard Test Method for Potential Alkali Reactivity of Aggregate Combinations (Mortar-Bar Method) (ASTM C227) or Standard Test Method for Potential Alkali-Silica Reactivity of (Chemical Method) (ASTM C289). \ . The design and construction of the concrete is in accordance with accepted ACI Standards that preclude the expansion and reaction with aggregate aging mechanism. Therefore, cracking due to expansion and reaction with aggregates is not an aging effect requiring management for concrete structure components . Aging Management Review Results *Page 3.5-27 January 2010 Columbia Generating Station License Renewal Application Technical Information (6) Cracks and distortion due to increased stress levels from settlement for Groups 1-3, 5-9 structures Cracking due to settlement is not an aging effect requiring management for concrete components below grade because the total differential settlement experienced in the past 20 years is well within the permissible limits for these types of structures and no settlement has manifested itself via cracked walls or cracked foundations. Foundations of all Columbia plant structures are supported on structural backfill. The backfill provides safe bearing for the structural foundations, and settlements are estimated to be minimal. In order to compare the calculated to actual settlement, measurement points were established at the corners of the substructure of the Reactor Building, Radwaste Control Building, Spray Ponds, and along the four sides of the sub-structure of the Turbine Generator Building. These points .have been monitored systematically since the beginning of construction. The settlement observation records to date for these facilities are included in the FSAR, Appendix 2.5H. The results of settlement monitoring program show that the actual maximum differential settlements are well within the estimated differential settlements and that they remain of no consequence to the design of plant structures appurtenances. The measured settlement rate in the time frame from 1986 to 1991 has virtually leveled off (i.e., zero settlement) for the Reactor, Radwaste Control, and Turbine Generator buildings and was less than an average of 0.001 feet per year for both Spray Ponds. Therefore, commitments regarding settlement have been satisfied as any future settlements during the lifetime of the plant will not adversely affect the plant structures or appurtenances. Columbia does not employ a de-watering system in any of the site structures for control of settlement since the groundwater level at the site is sufficiently lower than the deepest foundation in the complex.Therefore, cracks and distortion due to increased stress levels from settlement' are not aging effects requiring management for the concrete structural components. (7) Reduction in foundation strength, cracking, differential settlement due to erosion of porous concrete subfoundation for Groups 1-3, 5-9 structures The concrete foundations are not constructed with porous concrete and are not subject to flowing water. Columbia does not employ a de-watering system at any of the site structures for' control of settlement. Therefore, reduction in foundation strength, cracking, and differential settlement due to erosion of porous concrete subfoundations are not aging effects requiring management for the concrete foundations. (8) Lock up due to wear could occur for Lubrite radial beam seats in BWR drywell, Reactor Pressure Vessel support shoes for PWR with nozzle supports, steam generator supports, and other sliding support bearings and sliding support surfaces Aging Management Review Results Page 3.5-28 January 2010 Columbia Generating Station License Renewal Application Technical Information (6) Cracks and distortion due to increased stress levels from settlement for Groups 1-3, 5-9 structures

• Cracking due to settlement is not an aging effect requiring management for concrete components below grade because the total differential settlement experienced in the past 20 year,s is well within the permissible limits for these types of structures and no settlement has manifested itself via cracked walls or cracked foundations.

Foundations of all Columbia plant structures are supported on structural backfill. The backfill provides safe bearing for the structural foundations, and settlements are estimated to be minimal. In order to compare the calculated to actual settlement, measurement points were established at the corners of the substructure of the Reactor Building, Radwaste Control Building, Spray Ponds, and along the four sides of the sub-structure of the Turbine Generator Building. These points .have been* monitored systematically since the beginning of construction. The settlement observation records to date for these facilities are included in the FSAR, Appendix 2.5H. The results of settlement monitoring program show that the actual maximum differential settlements are well within the estimated differential settlements and that they remain of no consequence to the design of plant structures appurtenances. The measured settlement rate in the time frame from 1986 to 1991 has virtually leveled off (i.e., zero settlement) for the Reactor, Radwaste Control, and Turbine Generator buildings and was less than an of 0.001 feet per year for both Spray Ponds. Therefore, commitments regarding settlement have been satisfied as any future settlements during the lifetime of the plant

• will not adversely affect the plant structures or appurtenances.

Columbia does not employ a de-watering system in any of the site structures for control of settlement since the groundwater level at the site is sufficiently lower than the deepest foundation in the complex. . Therefore, cracks and distortion due to increased stress levels from settlement' are not aging effects requiring management for the concrete structural components. (7) Reduction in foundation strength, cracking, differential settlement due to erosion of porous concrete subfoundation for Groups 1-3, 5-9 structures The concrete foundations are not constructed with porous concrete and are not subject to flowing water. Columbia does not employ a de-watering system at any of the site structures fo( control of settlement. Therefore, reduction in foundation strength, cracking, and differential settlement due to erosion of porous concrete subfoundations are not aging effects requiring management for the concrete foundations. (8) Lock up due to wear could occur for Lubrite radial beam seats in BWR drywell, Reactor Pressure Vessel support shoes for PWR with nozzle supports, steam generator supports, and other sliding support bearings and sliding support surfaces Aging Management Review Results Page 3.5-28 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information Lubrite plates are provided in certain situations to reduce friction on sliding support assemblies in Columbia in-scope structural components.

They are used in association with such components as the radial beam seat connections on the vessel shell high temperature piping supports. Lubrite is the trade name for a low friction lubricant material used in applications where relative motion (sliding) is desired. The Lubrite proprietary lubricant is a custom compound mixture of metals, metal oxides, minerals,and other lubricating materials combined with a lubricating binder. Lubrite material resists deformation, has a low coefficient of friction, resists softening at elevated temperatures, absorbs grit and abrasive particles, is not susceptible to corrosion, withstands high intensities of radiation, and will not score or mar. Additionally, Lubrite products are solid, permanent, completely self lubricating, and require no maintenance. The Lubrite lubricants used in nuclear applications are designed for the environments to which they are exposed. There are no known aging effects that would lead to a loss of intended function. Review of plant-specific operating experience identified no occurrences of Lubrite degradations. Therefore, there are no aging effects requiring management for Lubrite plates.However, aging degradations of supports designed with or without sliding connections are managed by the Inservice Inspection (ISI) Program -IWF and the Structures Monitoring Program.3.5.2.2.2.2 Aging Management of Inaccessible Areas 3.5.2.2.2.2.1 Below-Grade Inaccessible Concrete Areas -Freeze-Thaw Columbia is located in an area where weathering conditions are moderate (weathering index 100 to 500 day-inch per year). The structures are designed with proper drainage and slope such that ponding or prolonged exposure to standing water on concrete surfaces is not significant. Columbia concrete is designed in accordance with ACI 31.8-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low water-to-cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides'a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or-of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete, which results in good freeze-thaw and sulfate resistance.) Aging Management Review Results Page 3.5-29 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Lubrite plates are provided in certain situations to reduce friction on sliding support* assemblies in Columbia in-scope structural components.

They are used in association with such components as the radial beam seat connections on the vessel shell high temperature piping supports. Lubrite is the trade name for a low friction lubricant material used. in applications where relative motion (sliding) is desired. The Lubrite proprietary lubricant is a custom compound mixture of metals, metal oxides, minerals, and other lubricating materials combined with a lubricating binder. Lubrite material resists deformation, has a low coefficient of friction, resists softening at elevated temperatures, absorbs grit and abrasive particles, is not susceptible to corrosion, withstands high intensities of radiation, and will not score or mar. Additionally, Lubrite products are solid, permanent, completely self lubricating, and require no maintenance. The Lubrite lubricants used in nuclear applications are designed for the environments to which they are exposed. There are no known aging effects that would lead to a loss of intended function. .Review of plant-specific operating experience identified no occurrences of Lubrite degradations. Therefore,. there are no aging effects requiring management for Lubrite plates. However, aging degradations of supports designed with or without sliding connections are managed by the Inspection (lSI) Program -IWF and the Structures Monitoring Program . 3.5.2.2.2.2 Aging Management of Inaccessible Areas 3.5.2.2.2.2.1 Below-Grade Inaccessible Concrete Areas -Freeze-Thaw Columbia is located in an area where weathering conditions are moderate (weathering index 100 to 500 day-inch per year). The structures are designed with proper drainage and slope such that ponding or prolonged exposure to standing water on concrete surfaces is not significant. , Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTMstandards. Concrete constructed to these criteria has a low cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides*a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive . concrete (sections more than 30 inches in the least dimension) a minimum slump *of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches orof the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-ta*-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specificatiofl yields concrete with low water-to-cement ratio since the average slump at the pOint of placement is less than the working limit, which is the maximum slump for es.timating the quantity of mixing water to be used in the concrete, which results in good freeze-thaw and sulfate resistance.) Aging Management Review Results Page 3.5-29 January 2010 Columbia Generating Station License Renewal Application Technical Information The design and construction of the concrete is in accordance with accepted ACI Standards that preclude freeze-thaw aging mechanism. Therefore, loss of material (spalling, scaling) and cracking due to freeze-thaw are not aging effects requiring management for the below-grade inaccessible concrete components. The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in accordance with NRC position on managing concrete, even if the AMR did not identify aging effects requiring management. The Structures Monitoring Program will include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. 3.5.2.2.2.2.2 Below-Grade Inaccessible Concrete Areas -Expansion and Reaction with Aggregates Columbia design specifications require that concrete aggregates conform to ASTM C33 and that the potential reactivity of aggregates be acceptable based on testing in accordance with ASTM Standard Test Method for Potential Alkali Reactivity of Cement-Aggregate Combinations (Mortar-Bar Method) (ASTM C227) or Standard Test Method for PotentialAlkali-Silica Reactivity of Aggregates (Chemical Method) (ASTM C289).The design and construction of the concrete is in accordance with accepted ACI Standards thereby precluding the expansion and reaction with aggregate aging mechanism. Therefore, cracking due to expansion and reaction with aggregates is not an aging effect requiring .management for the below-grade inaccessible concrete components. The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in accordance with the NRC position on managing concrete, even if the AMR did not identify aging effects requiring management. The Structures Monitoring Program will include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. 3.5.2.2.2.2.3 Below-Grade Inaccessible Concrete Areas -Settlement and Erosion Cracking due to settlement is not an aging effect requiring management for concrete components below grade because the total differential settlement experienced in the past 20 years is well within the permissible limits for these types of structures and no settlement has manifested itself via cracked walls or cracked foundations. Foundations of all Columbia plant structures are supported on structural backfill. The backfill provides safe bearing for the structural foundations, and settlements are estimated to be Aging Management Review Results Page 3.5-30 January 2010 Columbia Generating Station License Renewal Application Technical Information The design and construction of the concrete is in accordance with accepted ACI Standards that preclude freeze-thaw aging mechanism. Therefore, loss of material (spalling, scaling) and cracking due to freeze-thaw are not aging effects requiring management for the below-grade inaccessible concrete components. . The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in accordance with NRC position on managing concrete, even if the AMR did not identify aging effects requiring management. The Structures Monitoring Program will include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. 3.5.2.2.2.2.2 Below-Grade Inaccessible Concrete Areas -Expansion and Reaction with Aggregates

• Columbia design specifications require that concrete aggregates conform to ASTM C33 and that the potential reactivity of aggregates be acceptable based on testing in accordance with ASTM Standard Test Method for Potential Alkali Reactivity of Aggregate Combinations (Mortar-Bar Method) (ASTM C227) or Standard Test Method for PotentialAlkali-Silica Reactivity of Aggregates (Chemical Method) (ASTM C289).
• The design and construction of the concrete is in accordance with accepted ACI Standards thereby precluding the expansion and reaction with aggregate aging mechanism.

Therefore, cracking due to expansion and reaction with aggregates is not an aging effect requiring management for the below-grade inaccessible concrete components. The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in accordance with the NRC position on managing concrete, even if the AMR did not . identify aging effects requiring management. . The Structures Monitoring Program will include examination of exposed concrete for age-related degradation when a grade concrete component becomes accessible through excavation. 3.5.2.2.2.2.3 Below-Grade Inaccessible Concrete Areas -Settlement and Erosion Cracking dU,e to settlement is not an aging effect requiring management for concrete components below grade because the total differential settlement experienced in the past 20 years is well within the permissible limits for these types of structures and no settlement has manifested itself via cracked walls or cracked foundations. Foundations of all Columbia plant structures are supported on structural backfill. The backfill provides safe bearing for the structural foundations, and settlements are estimated to be Aging Management Review Results Page 3.5-30 January 2010 * )Columbia Generating Station License Renewal Application Technical Information minimal. In order to compare the calculated to actual settlement, measurement points were established at the corners of the substructure of the Reactor Building, Radwaste Control Building, Spray Ponds, and along the four-sides of the sub-structure of the Turbine Generator Building. These points have been monitored systematically since the beginning of construction. The settlement observation records to date for these facilities are included in the FSAR, Appendix 2.5H. The results of the settlement monitoring program show that the actual maximum differential settlements are well within the estimated differential settlements and that they remain of no consequence to the design of plant structures appurtenances. The measured settlement rate in the time frame from 1986 to 1991 has virtually leveled off (i.e., zero settlement) for the Reactor, Radwaste Control, and Turbine Generator buildings and was less than an average of 0.001 feet per year for both Spray Ponds. Therefore, commitments regarding settlement have been satisfied as any future settlements during the lifetime of the plant will not adversely affect the plant structures or appurtenances. Columbia does not employ a de-watering system in any of the site structures for control of settlement since the groundwater level at the site is sufficiently lower than the deepest foundation in the complex.Therefore, cracks and distortion due to increased stress levels from settlement and reduction of foundation strength, cracking, and differential settlement due to erosion of porous concrete subfoundations are not aging effects requiring management for the below-grade inaccessible concrete components. The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete. structures and structural components, in accordance with the NRC position on managing concrete, even if the AMR did not identify aging effects requiring management. The Structures Monitoring Program will include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. 3.5.2.2.2.2.4 Below-Grade Inaccessible Concrete Areas -Aggressive Chemical Attack and Corrosion of Embedded Steel Columbia concrete is, designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low water-to-cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACl 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however formassive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using thematerials and slump proposed for use. The slump working limit at point of placement Aging Management Review Results Page 3.5-31 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information minimal. In order to compare the calcylated to actual settlement, measurement pOints were established at the corners of the substructure of the Reactor Building, Radwaste Control Building, Spray Ponds, and along the four* sides of the of the Turbine Generator Building.

These points have been monitored systematically since the beginning of construction. The settlement observation records to date for these facilities are included in the FSAR, Appendix 2.5H. The results of the settlement monitoring program show that the actual maximum differential settlements are well within the estimated differential settlements and that they remain of no consequence to the design of plant structures appurtenances. The measured settlement rate in the time frame from 1986 to 1991 has virtually leveled off (i.e., zero settlement) for the Reactor, Radwaste Control, and Turbine Generator buildings and was less than an average of 0.001 feet' per year for both Spray Ponds. Therefore, commitments regarding settlement have been satisfied as any future settlements during the lifetime of the plant will not adversely affect the plant structures or appurtenances. Columbia does not employ a de-watering system in any of the site structures for control of settlement since the groundwater level at the site is sufficiently lower than the' deepest foundation in tile complex. Therefore, cracks and distortion due to increased stress levels from settlement and reduction of foundation strength, cracking, and differential settlement due to erosion of porous concrete subfoundations are 'not aging effects requiring management for the below-grade inaccessible concrete components. The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete. structures and structural components, in accordance with the NRC position on managing concrete, even if the AMR did not identify aging effects requiring management. The Structures Monitoring Program will include examination of exposed concrete for age-related degradation when a grade concrete component becomes accessible through excavation. 3.5.2.2.2.2.4 Below-Grade Inaccessible Concrete Areas -Aggressive Chemical Attack and Corrosion of Embedded Steel Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low cement ratio of less than 0.50 and an air entrainment betWeen 3 and. 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI.201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement Aging Management Review Results Page 3.5-31 January 2010 Columbia Generating Station License Renewal Application Technical Informationspecified in design specifications yields concrete with a low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used-in the concrete.)The below-grade environment is non-aggressive (Chlorides < 500 ppm, Sulfates< 1,500 ppm, and pH > 5.5) and has been confirmed by water chemistry analysis results. Sampling results indicate a groundwater pH minimum value of 6.9, chloride content maximum value of 36 ppm, and sulfate content maximum value of 323 ppm.The concrete components below grade are not exposed to an aggressive environment and the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding the aggressive chemical attack and embedded steel corrosion aging mechanisms. Therefore, increase in porosity and permeability, cracking, loss of material (spalling, scaling) due to aggressive chemical attack; and cracking, loss of bond, and loss of material (spalling, scaling) due to corrosion of embedded steel are not aging effects requiring management for the below-grade inaccessible concrete components. The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in accordance with the NRC position on managing concrete, even if the AMR did not identify aging effects requiring management. The Structures Monitoring Program will include review of site groundwater and raw water pH, chlorides, and sulfates in order to validate that the below-grade environment remains non-aggressive during the period of extended operation and will include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. 3.5.2.2.2.2.5u, Below-Grade Inaccessible Concrete Areas -Leaching of Calcium Hydroxide Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low water-to-cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placementspecified in design specifications yields concrete with low, water-to-cement ratio since Aging Management Review Results Page 3.5-32 January 2010 Columbia Generating Station License Renewal Application Technical Information specified in design specifications yields concrete with a low water-to-cement ratio since the average slump at the point of placement is le'ss than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.) The below-grade environment is non-aggressive (Chlorides < 500 ppm, Sulfates < 1,500 ppm, and pH >5.5) and has been confirmed by water chemistry analysis results. Sampling results indicate a groundwater pH minimum value of 6.9, chloride . content maximum value of 36 ppm, and sulfate content maximum value of 323 ppm. The concrete components below grade are not exposed to an aggressive environment' and the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding the aggressive chemical attack and embedded steel corrosion aging mechanisms. ' Therefore, increase in porosity and permeability, cracking, loss of material (spalling, scaling) due to aggressive chemical attack; and cracking, loss of bond, and loss of material (spalling, scaling) due to corrosion of embedded steel are not aging effects requiring management for the below-grade inaccessiblecon'crete components. The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in

• accordance with the NRC position on managing concrete, even if the AMR did not
• identify aging effects reqUiring management.

The S'tructures Monitoring Program will include review of site groundwater and raw water pH, chlorides, and sulfates in order to validate that the below-grade environment remains non-aggressive during the period of extended operation and will include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. 3.5.2.2.2.2.5,' Below-Grade Inaccessible Concrete Areas -Leaching of Calcium Hydroxide Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specifications yields concrete with low, water-to-cement ratio since , Aging Management Review Results Page 3.5-32 January 201 0 * / Columbia'Generating Station License Renewal Application Technical Information the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.).Leaching of calcium hydroxide from reinforced concrete becomes significant only if the.concrete is exposed to flowing water.The concrete components below grade are not exposed to flowing water and the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding the leaching of calcium hydroxide aging mechanism. Groundwater hydraulic pressure is not a concern at Columbia. Seismic Category I structures and safety-related systems and components are located above the present groundwater elevation 380 feet msl (mean sea level) and are not subject to any force effects of buoyancy and static water from this groundwater elevation. The lowest structure foundation mat, forthe Reactor Building, is at elevation 400 feet 9 inches, which is approximately 20 feet above the groundwater table elevation. Therefore, increase in porosity and permeability and loss of strength due to leaching of calcium hydroxide are not aging effects requiring management for the below-grade inaccessible concrete components. 3.5.2.2.2.3 Reduction of Strength and Modulus of Concrete Structures due to Elevated Temperature Columbia in-scope concrete structures and concrete components are not exposed to temperature limits associated with aging degradation due to elevated temperature. The general air temperatures in safety-related and other structures are maintained below the 150 °F threshold for these aging effects to be applicable. Normal temperature limits are given in FSAR Table 3.11-1. The area beneath the Reactor Pressure Vessel is a localized area and has a maximum temperature limit of 165 OF, which is below the 200 °F threshold for localized areas.Piping contained in these structures is not in direct contact with concrete and the concrete temperature surrounding hot penetrations such as the main steam line penetrations in the main steam tunnel is maintained at less than or equal to 200 OF.Columbia specifications contain required insulation thicknesses for high temperature process piping. Consequently, localized hot spots on concrete are not expected from exposure to adjacent piping.Therefore, reduction of strength and modulus of concrete due to elevated temperatures are not aging effects requiring management for the concrete components. Aging Management Review Results Page 3.5-33 January 2010* *

• Columbia/Generating Station License Renewal Application Technical Information the average slump at the point of placement is less than the working limit, which is the maximum for estimating the quantity of water to be used in the concrete.) .Leaching of calcium hydroxide from reinforced concrete becomes significant only if the .concrete is exposed to flowing water. , The concrete components below grade are not exposed to flowing water and the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding the leaching of calcium hydroxide aging mechanism.

Groundwater hydraulic pressure is not a concern at Columbia. Seismic Category I structures and related systems and components are located above the present groundwater elevation' 380 feet msl (mean sea level) and are not subject to any force effects of buoyancy and static water from this groundwater elevation. The lowest structure foundation mat, for the Reactor Building, is at elevation 400 feet 9 inches, which is approximately 20 feet' above the groundwater table elevation. Therefore, increase in porosity and permeability and loss of strength due to leaching of calcium hydroxide are not aging effects requiring management for the below-grade inaccessible concrete components. 3.5.2.2.2.3 Reduction of Strength and Modulus of Concrete Structures due to Elevated Temperature Columbia in-scope concrete structures and concrete components are not exposed to temperature limits associated with aging degradation due to elevated temperature. The general air temperature's in safety-related and other structures are maintained ,below the 150 OF threshold for these aging effects to be applicable. Normal temperature limits are, given in FSAR Table 3.11-1. The area beneath the Reactor Pressure Vessel is a localized area and has a maximum temperature limit of 165 of, which is below the 200 of threshold for localized areas. Piping contained in these structures is not in direct contact with concrete and the' concrete temperature surrounding hot penetrations such as the main steam line penetrations in the main steam tunnel is maintained at less than or equal to 200 of. Columbia specifications contain required insulation thicknesses for high temperature process piping. Consequently, localized hot spots on concrete are not expected from exposure to adjacent piping. Therefore, reduction of strength and modulus of concrete due to elevated temperatures are not aging effects requiring management for the concrete c9mponents . Aging Management Review Results Page 3.5-33 January 2010 Columbia Generating StationLicense Renewal Application Technical Information 3.5.2.2.2.4 Aging Management of Inaccessible Areas for Group 6 Structures 3.5.2.2.2.4.1 Below-Grade Inaccessible Concrete Areas -Aggressive Chemical Attack-and Corrosion of Embedded Steel The Structures Monitoring Program -Water Control Structures Inspection is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in .accordance with the NRC position on managing concrete, even if the AMR did not identify aging effects requiring management. Corrosion of structural steel components is addressed by the Structures Monitoring Program. Additional discussion of specific aging effects follows.The ultimate heat sink consists of two Spray Ponds and two Standby Service Water Pump Houses. The water control structures are the Spray Ponds, Standby Service Water Pump Houses, Circulating Water Pump House (including circulating water basin), Makeup Water Pump House, and the cooling tower basins.The below-grade environment is non-aggressive (Chlorides < 500 ppm, Sulfates< 1,500 ppm, and pH > 5.5) and has been confirmed by water chemistry analysis results. Sampling results indicate a groundwater pH minimum value of 6.9, chloride content maximum value of 36 ppm, and sulfate content maximum value of 323 ppm.Raw water sampling results indicate a raw water pH minimum value of 6.6, chloride content maximum value of 60 ppm, and sulfate content maximum value of 127 ppm.Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low water-to-cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent andprovides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump-of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.) The water control structure's concrete is not exposed to an aggressive environment and the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding the aggressive chemical attack and embedded steel corrosion aging mechanisms. Therefore, increase in porosity and permeability, cracking, loss of material (spalling, scaling)/aggressive chemical attack; and cracking, loss of bond, and loss of material Aging Management Review Results Page 3.5-34 January 2010\ Columbia Generating Station License Renewal Application Technical Information 3.5.2.2.2.4 Aging Management of Inaccessible Areas for Group 6 Structures 3.5.2.2.2.4.1 Below-Grade Inaccessible Concrete Areas -: Aggressive Chemical Attack and Corrosion of Embedded Steel The Structures Monitoring Program -Water Control Structures Inspection is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in *accordal1ce with the NRC position on . managing concrete, even if the AMR did not identify aging effects requiring management. Corrosion of structural steel components is addressed by the Structures' Monitoring Program. Additional discussion of specific aging effects follows. The ultimate heat sink consists of two Spray Ponds and two Standby Service Water Pump Houses. The water control structures are the Spray Ponds, Standby Service Water Pump Houses, Circulating Water Pump House (including circulating water basin), Makeup Water Pump House, and the cooling tower basins. The below-grade environment is non-aggressive (Chlorides < 500 ppm, Sulfates < 1,500 ppm, and pH > 5.5) and has been confirmed by water chemistry analysis results. Sampling results indicate a groundwater pH minimum value of 6.9, chloride content maximum value of 36 ppm, and sulfate content maximum value of 323 ppm. Raw water sampling results indicate a raw water pH minimum value of 6.6, chloride content maximum value of 60 ppm, and sulfate content maximum value of 127 ppm. Columbia concrete is designed in accordance with ACI 318-63 or 318-71 and constructed in accordance with ACI 301-66 or 301-72 using ingredients conforming to ACI and ASTM standards. Concrete constructed to these criteria has a low water-to-. cement ratio of less than 0.50 and an air entrainment between 3 and 6 percent and provides a good quality dense concrete with a low permeability, which meets the intent of ACI 201.2R-77. (Note: Columbia does not specify water-to-cement ratio, however for massive concrete (sections more than 30 inches in the least dimension) a minimum slump of 1 inch and a maximum slump of 3 inches is provided so that the average for all batches or of the most recent 10 batches tested, whichever is lower, does not exceed 2-1/2 inches. Water-to-cement ratio is established by tests of trial mixes using the materials and slump proposed for use. The slump working limit at point of placement specified in design specification yields concrete with low water-to-cement ratio since the average slump at the point of placement is less than the working limit, which is the maximum slump for estimating the quantity of mixing water to be used in the concrete.} The water control structure's concrete is not exposed to an aggressive environment and the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding the aggressive chemical attack and embedded steel corrosion aging mechanisms. Therefore, increase in porosity and permeability, cracking, loss of material (spalling, scaling}/aggressive chemical attack; and cracking, loss of bond, and loss of material Aging Management Review Results Page 3.5-34 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information (spalling, scaling)/corrosion of embedded steel are not aging effects requiring management for the water control structure's concrete.The absence of concrete aging effects is confirmed under the Structures Monitoring Program.3.5.2.2.2.4.2 Below-Grade Inaccessible Concrete Areas

-Freeze-Thaw Loss of material (spalling, scaling) and cracking due to freeze-thaw are aging effects requiring management for concrete components exposed to raw water because the concrete located in water control structures may become saturated and therefore could be susceptible to freeze-thaw. Concrete components submerged in raw water (e.g., spray pond foundation) are not susceptible to freeze-thaw. The Structures Monitoring Program -Water Control Structures Inspection is credited for monitoring degradation of the Spray Ponds, Standby Service Water Pump Houses, Circulating Water Pump House (including circulating water basin), Makeup Water Pump House, and the cooling tower basins. The Structures Monitoring Program will be enhanced to include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. 3.5.2.2.2.4.3 Below..Grade Inaccessible Concrete Areas -Expansion and Reaction with Aggregate and Leaching of Calcium Hydroxide Columbia design specifications require that concrete aggregates conform to ASTM C33 and that the potential reactivity of aggregates be acceptable based on testing in accordance with ASTM Standard Test Method for Potential Alkali Reactivity of Cement-Aggregate Combinations (Mortar-Bar Method) (ASTM C227) or Standard Test Method for Potential Alkali-Silica Reactivity of Aggregates (Chemical Method) (ASTM C289).Leaching of calcium hydroxide from reinforced concrete becomes significant only if the concrete is exposed to flowing water.The water control structures are exposed to flowing water, however the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding the expansion and reaction with aggregate and leaching of calciumhydroxide aging mechanisms. Groundwater hydraulic pressure is not a concern at Columbia. Seismic Category I structures and safety-related systems and components are located above the present groundwater elevation 380 feet msl (mean sea level) and are not subject to any force effects of buoyancy and static water from this groundwater elevation. The foundation slab at the bottom of the Standby Service Water Pump House pump chambers where it intersects the spray pond foundation is at elevation 404 feet 9 inches, which is approximately 24 feet above the groundwater table elevation. Aging Management Review Results Page 3.5-35 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information (spalling, scaling)/corrosion of embedded steel are not aging effects requiring management for the water control structure's concrete.

\. The absence of concrete aging effects is confirmed under the Structures Monitoring Program. , 3.5.2.2.2.4.2 Below-,Grade Inaccessible Concrete Areas -Freeze-Thaw Loss of material (spalling, scaling) and cracking due to freeze-thaw are aging effects requiring management for concrete components exposed to raw water because the concrete located in water control structures may become saturated and therefore could be susceptible to freeze-thaw. Concrete components submerged in raw water (e.g., spray pond foundation) are not susceptible to freeze-thaw. The Structures Monitoring Program -Water Control Structures Inspection is credited for monitoring degradation of the Spray Ponds, Standby Service Water Pump Houses, Circulating Water Pump House (including circulating water basin), Makeup Water Pump House, and the cooling tower basins. The Structures Monitoring Program will be enhanced to include examination of exposed concrete for age-related degradation when a grade concrete component becomes accessible through excavation. 3.5.2.2.2.4.3 Below**Grade Inaccessible Concrete Areas -Expansion and Reaction with and Leaching of Calcium Hydroxide Columbia design specifications require that concrete aggregates conform to ASTM C33 and that the potential reactivity of aggregates be acceptable based on testing in accordance with ASTMStandard Test Method for Potential Alkali Reactivlty of Aggregate Combinations (Mortar-Bar Method) (ASTM C227) or Standard Test Method for Potential Alkali-Silica Reactivity of Aggregates (Chemical Method) (ASTM C289). Leaching of calcium hydroxide from reinforced concrete becomes significant only if the concrete is exposed to flowin'g water. The water control structures are exposed to flowing water, however the design and construction of the concrete is in accordance with accepted ACI Standards, thereby precluding the expansion and reaction with aggregate and leaching of calcium hydroxide aging mechanisms. Groundwater hydraulic pressure is not a concern at Columbia. Seismic Category I structures and safety-related systems and components are located above the present groundwater elevation 380 feet ,msl (mean sea level) and are not subject to any force effects of buoyancy and static water from this groundwater elevation. The foundation slab at the bottom of the Standby Service Water' Pump House pump chambers where it intersects the spray pond foundation is at elevation 404 feet 9 inches, which is approximately 24 feet above the groundwater table elevation . Aging Management Review Results Page 3.5-35 January 2010 Columbia Generating Station License Renewal Application Technical Information Therefore, cracking due to expansion and reaction with aggregate, and increase in porosity and permeability, and loss of strength due to leaching of calcium hydroxide are not aging effects requiring management for the below-grade concrete structures. The Structures Monitoring Program -Water Control Structures Inspection is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in accordance with the NRC position on managing concrete, even if the .AMR did not identify aging effects requiring management. The Structures Monitoring Program will be enhanced to include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. 3.5.2.2.2.5 Cracking due to Stress Corrosion Cracking and Loss of Material due to Pitting and Crevice Corrosion No tanks with stainless steel liners are included in the structural reviews for aging management. Tanks subject to AMR are evaluated with the respective mechanical systems.3.5.2.2.2.6 Aging of Supports Not Covered by Structures Monitoring Program(1) Loss of material due to general and pitting corrosion for Groups B2-B5 supports Loss of material due to general and pitting corrosion for Groups B2-B5 supports is managed by the Structures Monitoring Program.(2) Reduction in concrete anchor capacity due to degradation of the surrounding concrete, for Groups B1-B5 supports Cracking due to service-induced vibration or fatigue that causes a reduction in concrete anchor capacity is not an aging effect requiring management because Columbia concrete support components are not subject to.significant cyclic loading. Reinforced concrete components are designed by the strength method per ACI 318 and structural steel components are designed by the working stress method per American Institute of Steel Construction (AISC) specification, resulting in good, low cycle fatigue properties. Failures from high cycle fatigue due to equipment vibration loads are detected early in plant life and actions would be taken to prevent reoccurrence. At Columbia, connections for supports of running machinery or other high vibration environmental applications are designed as a slip-critical connection. Vibratory and rotating equipment are supported by cast-in-place, through bolted, or grouted-in anchors. Therefore, cracking due to fatigue at locations of cast-in-place, through bolted, or grouted-in anchors is not an aging effect requiring management. The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in Aging Management Review Results Page 3.5-36 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Therefore, cracking due to expansion and reaction with aggregate, and increase in porosity and permeability, and loss of strength due to leaching of calcium hydroxide are not aging effects requiring management for the below-grade concrete structures.

The Structures Monitoring Program -Water Control Structures Inspection is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in accordance with the NRC position on managing concrete, even if the. AMR did not identify aging effects requiring management. The Structures Monitoring Program will be enhanced to include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. 3.5.2.2.2.5 Cracking due to Stress Corrosion Cracking and Loss of Material due to Pitting and Crevice Corrosion No tanks with stainless steel liners are included in the structural reviews for aging management. Tanks subject to AMR are evaluated with the respective mechanical systems. 3.5.2.2.2.6 Aging of Supports Not Covered by Structures Monitoring Program (1) Loss of material due to general and pitting corrosion for Groups 82-85 supports Loss of material due to general and pitting corrosion for Groups 82-85 supports is managed by the Structures Monitoring Program. (2) Reduction. in concrete anchor capacity due to degradation of the surrounding concrete, for Groups 81-85 supports Cracking due to service-induced vibration or fatigue that causes a reduction in concrete anchor capacity is not an aging effect requiring management because Columbia concrete support components are not subject to* significant cyclic loading. Reinforced concrete components are designed by the strength method per ACI 318 and structural steel components are designed by the working stress method per American Institute of Steel Construction (AI$C) specification, resulting in good, low cycle fatigue properties. Failures from high cycle fatigue due to equipment vibration loads are detected early in plant life and actions would be taken to prevent reoccurrence. At Columbia, connections for supports of running machinery or other high vibration environmental applications are designed as a slip-critical connection. Vibratory and rotating equipment are supported by cast-in-place, through bolted, or grouted-in anchors. Therefore, cracking due to fatigue at locations of cast-in-place, through bolted, or grouted-in anchors is not an aging effect requiring management. The Structures Monitoring Program is credited for aging management of these effects and mechanisms for the affected concrete structures and structural components, in . Aging Management Review Results Page 3.5-36 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information accordance with the NRC position on managing concrete, even if the AMR did not identify aging effects requiring management..

(3) Reduction or loss of isolation function due to degradation of vibration isolation elements for Group B4 supports Vibration isolation elements are not used on Columbia's vibratory and rotating equipment such as pumps, compressors, or air handling units. However, vibration isolators are used on certain control panels within skid mounted complex assemblies such as the diesel engine. These components are treated as sub component (e.g., panels, pipe supports, heat exchanger supports, engine anchorages, instrumentation supports on the diesel engine skid) to the host component and are managed as part of the host component during Structures Monitoring Program inspections. Degradation of vibration isolation elements for Group B4 supports is managed by the Structures Monitoring Program.3.5.2.2.2.7 Cumulative Fatigue Damage Due to Cyclic Loading Time-limited aging analyses are evaluated in accordance with 10 CFR 54.21(c) as documented in Section

4. During the process of identifying time-limited aging analyses in the current licensing basis, no fatigue analyses were identified for component support members, anchor bolts, or welds for Groups B1.1, B1.2, and B1.3.3.5.2.2.3 Quality Assurance for Aging Management of Non-safety Related Components Quality Assurance provisions applicable to license renewal are discussed in Appendix B, Section B.1.3.3.5.2.3 Time-Limited Aging Analyses The time-limited aging analyses identified below 'are associated with the Containments, Structures, and Component Supports commodities.

The section of the application thatcontains the time-limited aging analysis review results is indicated in parentheses.

• Metal Fatigue (Section 4.6, Containment Liner Plate, Metal Containments, and Penetrations Fatigue Analyses)3.5.3 Conclusions The Containments, Structures, and Component Supports subject to AMR have been identified in accordance with the criteria of 10 CFR 54.21. The aging management programs selected to manage the effects of aging on structural components and commodities are identified in the following tables and Section 3.5.2.1. A description of the 'aging management programs is provided in Appendix B, along with the demonstration that the identified aging effects will be managed for the period of extended operation.

Aging Management Review Results Page 3.5-37 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information accordance with the NRC position on managing concrete, even if the AMR did not identify aging effects requiring management.

' (3) Reduction or loss of isolation function due to degradation of vibration isolation elements for Group 84 supports Vibration isolation elements are not used on Columbia's vibratory and rotating equipment such as pumps, compressors, or air handling units. However, vibration isolators are used on c:ertain control panels within skid mounted complex assemblies such as the diesel engine. These components are treated as sub component (e.g., panels, pipe supports, heat exchanger supports, engine anchorages, , instrumentation supports on the diesel engine skid) to the host component and are managed as part of the host component during Structures Monitoring Program inspections. Degradation of vibration isolation elements for Group, 84 supports is managed by the Structures Monitoring Program. 3.5.2.2.2.7 Cumulative Fatigue Damage Due to Cyclic Loading Time-limited aging analyses are evaluated in accordance with 10 CFR 54.21(c) as documented in Section 4: During the process of identifying time-limited aging analyses in the current licensing basis, no fatigue analyses were identified for component support members, anchor bolts, or Welds for Groups 81.1, 81.2, and 81.3. 3.5.2.2.3 Quality Assurance for Aging Management of Non-safety Related Components Quality Assurance provisions applicable to license renewal are discussed in Appendix 8, Section 8.1.3. 3.5.2.3 Time-Limited Aging Analyses The time-limited aging analyses identified below 'are associated with the Containments, Structures, and Component Supports commodities. The section of the application that contains the time-limited aging analysis review results is indicated in parentheses.

• Metal Fatigue (Section 4.6, Containment Liner Plate, Metal Containments, and ' Penetrations Fatigue Analyses)

3.5.3 Conclusions

The Containments, Structures" and Component Supports subject to AMR have been identified in accordance with the criteria of 10 CFR 54.21. The aging management programs selected to manage the effects of aging on structural components and commodities are identified in the following tables and Section 3.5.2.1. A description of the 'aging manageml3nt programs is provided in Appendix 8, along with the demonstration that, the identified aging effects will be managed for the period of extended operation. Aging Management Review Results Page 3.5-37 January 2010 Columbia Generating Station License Renewal Application Technical Information Therefore, based on the demonstrations provided in Appendix B, the effects of aging associated with the Containments, Structures, and Component Supports will be managed such that there is reasonable assurance that the intended functions will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Review Results Page 3.5-38 January 2010 Aging Management Review Results Page 3.5-38 January 2010 Columbia Generating Statio"n .License Renewal Application

• Technical Information*

Therefore, based on the demonstrations provided in Appendix B, the effects of aging associated with the Containments, Structures, and Component Supports will be managed such that there is reasonable assurance that the intended functions will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Review Results Page 3.5-38 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect/ Aging Management Further Number Mechanism Programs Recommended PWR Concrete (Reinforced and Prestressed) and Steel Containments BWR Concrete and Steel (Mark I, II, and Ill) Containments 3.5.1-01 Concrete elements:

walls, Aging of accessible ISI (IWL) and for Yes, plant- The Primary Containment dome, basemat, ring girder, and inaccessible inaccessible concrete, specific, if the concrete is not exposed to an buttresses, containment (as concrete areas due an examination of environment is aggressive environment and applicable) to aggressive representative samples aggressive the design and construction of chemical attack, of below-grade the concrete is in accordance and corrosion of concrete, and periodic with accepted ACI Standards, embedded steel monitoring of thereby precluding aggressive groundwater, if the chemical attack and embedded environment is non- steel corrosion aging aggressive. A plant mechanisms. specific program is to be evaluated if Refer to Section 3.5.2.2.1.1 for environment is further information. aggressive. Aging Management Review Results Page 3.5-39 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 . Item Aging Effect/ Aging Management Further Number Component/Commodity Mechanism Programs Evaluation Discussion Recommended PWR Concrete (Reinforced and Prestressed) and Steel Containments BWR Concrete and Steel (Mark I, II, and III) Containments

-3.5.1-01 Concrete elements: walls, Aging of accessible lSI (lWL) and for Yes, plant-. The Primary Containment dome, basemat, ring girder, and inaccessible inaccessible concrete, specific, if the concrete is not exposed to an buttresses, containment (as concrete areas due an examination of environment is aggressive environment and applicable) to aggressive representative samples aggressive the design and construction of chemical attack, of below-grade the concrete is in accordance and corrosion of concrete, and periodic with accepted ACI Standards, embedded steel monitoring of thereby precluding aggressive groundwater, if the chemical attack and embedded environment is non-steel corrosion aging aggressive. A plant mechanisms. specific program is to -be evaluated if Refer to Section 3.5.2.2.1.1 for . environment is further information . aggressive. Aging Management Review Results Page 3.5-39 January 2010 ) , Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item CCAging Effectl Aging Management Further Number ComponentlCommodity Mechanism Programs Recommended D 3.5.1-02 Concrete elements; All Cracks and Structures Monitoring Yes, if not Not applicable for Columbia.distortion due to Program. If a de- within the increased stress watering system is scope of the Columbia does not employ a levels from relied upon for control applicant's de-watering system in any of settlement of settlement, then the structures the site structures for control of licensee is to ensure monitoring settlement. The total proper functioning of program or a differential settlement the de-watering system de-watering experienced in the past 20 through the period of system is relied years is well within the extended operation. upon permissible limits for these types of structures and no settlement has manifested itself via cracked walls or cracked foundations, therefore, this aging mechanism is not applicable. Refer to Section 3.5.2.2.1.2 for N further information. Aging Management Review Results Page 3.5-40 January 2010 0 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports " Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-02 Concrete elements; All Cracks and Structures Monitoring Yes, if not Not applicable for Columbia. distortion due to Program. If a de-within the increased stress watering system is scope of the Columbia does not employ a levels from relied upon for control applicant's de-watering system in any of settlement of settlement, then the structures the site structures for control of licensee is to ensure monitoring settlement. The total proper functioning of program or a differential settlement the de-watering system de-watering experienced in the past 20 through the period of system is relied years is well within the extended operation. upon permissible limits for these types of structures and no settlement has manifested itself via cracked walls or cracked foundations, therefore, this' aging mechanism is not applicable. Refer to Section 3.5.2.2.1.2 for , further information. Aging Management Review Results Page 3.5-40 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801e AFurther Item Component/Commodity Aging Effect Aging Management Evaluation Discussion Number C Mechanism Programs Recommended 3.5.1-03 Concrete elements:

foundation, Reduction in Structures Monitoring f Yes, if not The Primary Containment base sub-foundation foundation Program within the foundation slabs are not strength, cracking, If a de-watering system scope of the constructed of porous concrete differential is relied upon for applicant's below-grade and are not settlement due to control of erosion of structures subject to flowing water, erosion of porous cement from porous monitoring thereby precluding these aging concrete concrete program or a effects and mechanisms. subfoundation subfoundations, then de-watering the licensee is to system is relied Columbia does not employ a ensure proper upon de-watering system at any of functioning of the de- .the site structures for control of watering system settlement or erosion of cement through the period of from concrete subfoundations. extended operation. Refer to Section 3.5.2.2.1.2 for further information. Aging Management Review Results Page 3.5-41 January 2010* **

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III ,of NUREG-1801 Item Aging Effectl Aging Management Further Number ComponentlCommodity

-, Mechanism Programs Evaluation Discussion Recommended 3.5.1-0.3 Concrete elements: foundation, Reduction in Structures Monitoring Yes, if not The Primary Containment base sub-foundation foundation Program within the foundation slabs are not strength, cracking, If a de-watering system scope of the constructed of porous concrete differential is relied upon for applicant's below-grade and are not settlement due to control of erosion of structures subject to flowing water, erosion of porous cement from porous monitoring thereby precluding these aging concrete concrete program,or a effects and mechanisms. subfoundation subfoundations, then de-watering the licensee is to system is relied Columbia does not employ a ensure proper upon de-watering system at any of functioning of the de-. the site structures for control of watering system settlement or erosion of cement through the period of . from concrete subfoundations . . extended operation. Refer to Section 3.5.2.2.1.2 for further information. Aging Management Review Results Page 3.5-41 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801e AFurther Item Component/Commodity Aging Effect Aging Management Evaluation Discussion Number Mechanism ProgramsReomnd 3.5.1-04 Concrete elements: dome, wall, Reduction of A plant-specific aging Yes, plant- The temperature for the basemat, ring girder, strength and management program specific if Primary Containment is buttresses, containment, modulus of is to be evaluated temperature maintained below 150 °F during concrete fill-in annulus (as concrete due to limits are normal operation, 135 °F bulk applicable) elevated exceeded average maximum. The area temperature beneath the RPV is a localized area and has a maximum temperature limit of 165 °F which is below the 200 OF threshold for localized area.Piping contained in the Primary Containment is not in direct contact with concrete and the concrete temperature surrounding hot penetrations such as the main steam line penetrations is maintained at less than or equal to 200 OF.These are below the threshold temperatures for these aging effects to be applicable. Refer to Section 3.5.2.2.1.3 for further information. Aging Management Review Results Page 3.5-42 January 2010 Aging Management Review Results Page 3.5-42 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussi?n Number Mechanism Programs Recommended 3.5.1-04 Concrete elements: dome, wall, Reduction of A plant-specific aging Yes, plant-The temperature for the basemat, ring girder, strength and management program specific if Primary Containment is buttresses, containment, modulus of is to be evaluated temperature maintained below 150 of during concrete fill-in annulus (as concrete due to limits are normal operation, 135 of bulk ap'plicable) elevated exceeded average maximum. The area temperature beneath the RPV is a localized area and has a maximum temperature limit of 165 of which is below the 200 of -threshold for localized area. contained in the Primary Containment is not in direct contact with concrete and the concrete temperature surrounding hot penetrations such as the main steam line penetrations is maintained at less than or equal to 200 of. These are below the threshold temperatures for these aging effects to be applicable. Refer to Section 3.5.2.2.1.3 for .., further information . Aging Management Review Results Page 3.5-42 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further NuItem Component/Commodity Aging Effect/ Aging Management Evaluation Discussion Numbr MchaismPrograms Recommended 3.5.1-'05 Steel elements:

Drywell; torus; Loss of material I ISI (IWE), Yes, if Consistent with NUREG-1801. drywell head; embedded shell due to general, and10 CFR Part 50, corrosion is and sand pocket regions; pitting and crevice Appendix J. significant for Loss of material due to drywell support skirt; torus ring corrosion inaccessible corrosion in steel elements is girder; downcomers; liner plate, areas managed by the InserviceECCS suction header, support Inspection (ISI) Program -IWE skirt, region shielded by and the Appendix J Program.diaphragm floor, suppression. In addition, loss of material due chamber (as applicable) to pitting and crevice corrosion for steel elements exposed to treated water (i.e., suppression chamber) is managed by the BWR Water Chemistry Program.Refer to Section 3.5.2.2.1.4 for further information. 3.5.1-06 Steel elements: steel liner, liner Loss of material ISI (IWE), and Yes, if Not applicable for Columbia.anchors, integral attachments due to general, 10 CFR Part 50, corrosion is pitting and crevice Appendix J. significant for The Primary Containment is a corrosion inaccessible GE BWR Mark II steel areas containment design. This table item pertains to PWR steel containments and BWR Mark III concrete containments. Aging Management Review Results Page 3.5-43 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item / Aging Effect/ Aging Management Further Number Component/Commodity Mechanism Programs Evaluation Discussion Recommended 3.5.1':05 Steel elements:

OryweU; torus; Loss of material lSI (I WE) , Yes, if Consistent with NUREG-1801. drywell head; embedded shell due to general, and10 CFR Part 50, corrosion is and sand pocket regions; pitting and crevice Appendix J. significant for Loss of material due to drywell support skirt; torus ring corrosion inaccessible corrosion in steel elements is girder; downcomers; liner plate, areas managed by the Inservice ECCS suction header, support Inspection (lSI) Program -IWE skirt, region shielded by and the Appendix J Program. diaphragm f1oor,suppression In addition, loss of material due chamber (as applicable) to pitting and crevice corrosion for steel elements exposed to treated water (i.e., suppression chamber) is managed by the BWR Water Chemistry Program. Refer to Section 3.5.2.2.1.4 for further information . 3.5.1-06 Steel elements: steel liner, liner Loss of material lSI (lWE), and Yes, if . Not applicable for Columbia. anchors, integral attachments due to general, 10 CFR Part 50, corrosion is pitting and crevice Appendix J. significant for The Primary Containment is a corrosion inaccessible GE BWR Mark II steel areas containment design. This table item pertains to PWR steel containments and BWR Mark III -concrete containments. Aging Management Review Results Page 3.5-43 January 2010 Columbia Generating Station License Renewal Application Technical. Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further Item Component/Commodity Aging Effect Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-07 Prestressed containment Loss of prestress TLAA, evaluated in Yes, TLAA Not applicable for Columbia.tendons due to relaxation, accordance with shrinkage, creep, 10 CFR 54.21(c) The Primary Containment is a and elevated GE BWR Mark II steel temperature containment design. There are no prestressed tendons associated with the Primary Containment design.Refer to Section 3.5.2.2.1.5 for further information. 3.5.1-08 Steel and stainless steel Cumulative fatigue TLAA, evaluated in Yes, TLAA TLAAs are evaluated in elements: vent line, vent damage (CLB accordance with accordance with header, vent line bellows; fatigue analysis 10 CFR 54.21(c) 10 CFR 54.21(c) as downcomers exists) documented in Section 4.Fatigue TLAAs are evaluated as documented in Section 4.6. Refer to Section 3.5.2.2.1.6 for further information. 3.5.1-09 Steel, stainless steel elements, Cumulative fatigue TLAA, evaluated in Yes, TLAA TLAAs are evaluated indissimilar metal welds: damage (CLB accordance with -accordance with penetration sleeves, fatigue analysis 10 CFR 54.21 (c) 10 CFR 54.21 (c) as penetration bellows; exists) documented in Section 4.suppression pool shell, Fatigue TLAAs are evaluated unbraced downcomers as documented in Section 4.6.Refer to Section 3.5.2.2.1.6 for further information. Aging Management Review Results Page 3.5-44 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of ,Aging Management Programs for Structures and Component Supports -Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-07 Prestressed containment loss of prestress TLAA, evaluated in Yes, TLAA Not applicable for Columbia. tendons due to relaxation, accordance with -shrinkage, creep, 10 CFR 54.21 (c) The Primary Containment is a and elevated GE SWR Mark II steel temperature containment design. There are no prestressed tendons associated with the Primary Containment design. Refer to Section 3.5.2.2.1.5 for further information. 3.5.1-08 Steel and stainless steel Cumulative fatigue TLAA, evaluated in Yes, TLAA TLAAs are evaluated in elements: vent line, vent damage (ClS accordance with acc'ordance with header, vent line bellows; fatigue analysis 10 CFR 54.21 (c) 10 CFR 54.21 (c) as downcomers exists) documented in Section 4. Fatigue TLAAs are evaluated as documented in Section 4.6. J Refer to Section 3.5.2.2.'1.6 for further information. 3.5.1-09 Steel, stainless steel elements, Cumulative fatigue TLAA, evaluated in Yes, TLAA TLAAs are evaluated in dissimilar metal welds: damage (ClS accordance with -accordance with penetration sleeves, fatigue analysis 10 CFR 54.21 (c) 10 CFR 54.21 (c) as penetration bellows; -exists) documented in Section 4 . . suppression pool shell, Fatigue TLAAs are evaluated unbraced downcomers as documented in Section 4.6. Refer to Section 3.5.2.2.1.6 for further information. Aging Management Review Results Page 3.5-44 January 2010 / * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated inChapters II and III of NUREG-1801 Item Aging Effectl. Aging Management Further Number Component/Commodity Mechanism Programs Evaluation Discussion Number___

Mechanism ProgramRecommended 3.5.1-10 Stainless steel penetration Cracking due to ISI (IWE) and J Yes, detection Not applicable for Columbia.sleeves, penetration bellows, stress corrosion 10 CFR Part 50, of aging effects dissimilar metal welds cracking' Appendix J, and is to be The primary containment additional appropriate evaluated penetrations are of welded examinations/evaluatio steel construction without ns for bellows expansion bellows, gaskets, or assemblies and sealing compounds and are an dissimilar metal welds. integral part of the construction. The penetration sleeves, vent headers and downcomers are fabricated from carbon steel.A review of Columbia operating experience indicatesthat cracking due to SCC has not been a concern for steel containment pressure boundary. Cracking due to SCC is not applicable for the primary containment pressure boundaries. Refer to Section 3.5.2.2.1.7 for further information. Aging Management Review Results Page 3.5-45 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in *Chapters II and III of NUREG-1801 Item Aging Effect/ . Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-10 Stainless steel penetration Cracking due to lSI (IWE) and Yes, detection Not. applicable for Columbia.

sleeves, penetration bellows, stress corrosion 10 CFR Part 50, of aging effects dissimilar metal welds cracking' Appendix J, and is to be The primary containment additional appropriate evaluated penetrations are of welded examinations/evaluatio steel construction without ns for bellows expansion bellows, gaskets, or assemblies and sealing compounds and are an dissimilar metal welds. integral part of the construction. The penetration sleeves, vent headers and downcomers are fabricated from carbon steel. A review of Columbia operating -experience indicates,that cracking due to SCC has not been a concern for steel containment pressure boundary. Cracking due to -SCC is not applicable for the primary containment pressure boundaries. Refer to Section 3.5.2.2.1.7 for further information. Aging Management Review Results Page 3.5-45 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 i AFurther Item Aging Effect/ Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-11 Stainless steel vent line bellows Cracking due to ISI (IWE) and Yes, detection Not applicable for Columbia.stress corrosion 10 CFR Part 50, of aging effects cracking Appendix J, and is to be The Primary Containment is a additional appropriate evaluated GE BWR Mark II steel examination/evaluation containment design. There are for bellows assemblies no stainless steel vent line and dissimilar metal bellows associated with the welds. Primary Containment design.Refer to Section 3.5.2.2.1.7 for further information. Aging Management Review Results Page 3.5-46 January 2010 Aging Management Review Results Page 3.5-46 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of 801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-11 Stainless steel vent line bellows Cracking due to lSI (IWE) and Yes, detection Not applicable for Columbia. stress corrosion 10 CFR Part 50, of aging effects / cracking Appendix J, and , is to be The Primary Containment is a / additional appropriate evaluated GE BWR Mark II steel examination/evaluation containment design. There are for bellows assemblies no stainless steel vent line and dissimilar metal bellows associated with the welds. Primary Containment design. Refer to Section 3.5.2.2.1.7 for further information. Aging Management Review Results Page 3.5-46 January 2010 * *

• Columbia G3enerating StationLicense Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports.- Evaluated in Chapters I and III of NUREG-1801 Further Item ComponentlCommodity Aging Effectl Aging Management Evaluation Discussion Nu m ber Mechanism Programs Recommended 3.5.1-12 Steel, stainless steel elements, j Cracking due to I ISI (IWE) and Yes, detection I Not applicable for Columbia.dissimilar metal welds:

cyclic loading 10 CFR Part 50, of aging effects penetration sleeves, Appendix J, and is to be Columbia penetrations do not penetration bellows; supplemented to detect evaluated use expansion bellows and suppression pool shell, fine cracks penetration sleeves are unbraced downcomers fabricated of carbon steel.The AMR, as supported by operating experience, concluded that cyclic loading from plant heatups and cooldowns, containment testing, and from system vibration was very low or limited in numbers of cycles; therefore, additional methods of detecting postulated cracking are not warranted. This aging effect and mechanism is not applicable. Refer to Section 3.5.2.2.1.8 for further information. Aging Management Review Results Page 3.5-47 January 2010 Aging Management Review Results Page 3.5-47 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports ) " . Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-12 Steel, stainless steel elements, Cracking due to lSI (IWE) and Yes, detection Not applicable for Columbia.

dissimilar metal welds: cyclic loading 10 CFR Part 50, of aging effects penetration sleeves, Appendix J, and is to be Columbia penetrations do not penetration bellows; supplemented to detect evaluated use expansion bellows and , suppression pool shell, fine cracks penetration sleeves are unbraced downcomers fabricated of carbon steel. The AMR, as supported by operating experience, -concluded that cyclic loading from plant heatups and -cooldowns, containment testing, and from system vibration was very low or limited in numbers of cycles; therefore, additional methods of detecting postulated cracking are not warranted. This aging effect and mechanism is not applicable. Refer to Section 3.5.2.2.1.8 for further information. Aging Management Review Results Page 3.5-47 January 2010 " Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further Item Component/Commodity Aging Effect/ Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-13 Steel, stainless steel elements, Cracking due to ISI (IWE) and Yes, detection Not applicable for Columbia.dissimilar metal welds: torus; cyclic loading 10 CFR Part 50, of aging effects vent line; vent header; vent line Appendix J, and is to be The AMR, as supported by bellows; downcomers supplemented to detect evaluated operating experience, fine cracks concluded that cyclic loading from plant heatups and cooldowns, containment testing, and from system vibration was very low or limited in numbers of cycles; therefore, additional methods of detecting postulated cracking are not warranted. This aging effectand mechanism is not applicable. Refer to Section 3.5.2.2.1.8 for further information. 3.5.1-14 Concrete elements: dome, wall, Loss of material ISI (IWL). Evaluation is Yes, for Not applicable for Columbia.basemat ring girder, buttresses, (Scaling, cracking, needed for plants that inaccessible containment (as applicable) and spalling) due to are located in moderate areas of plants The Primary Containment is a freeze-thaw to severe weathering located in GE BWR Mark II steel conditions (weathering moderate to containment design located index >100 day-inch/yr) severe within the Reactor Building.(NUREG-1 557). weathering This aging effect and conditions mechanism is not applicable. Refer to Section 3.5.2.2.1.9 for further information. Aging Management Review Results Page 3.5-48 January 2010 Aging Management Review Results Page 3.5-48 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-13 Steel, stainless steel elements, Cracking due to lSI (IWE) and . Yes, detection Not applicable for Columbia. dissimilar metal welds: torus; cyclic loading 10 CFR Part 50, of aging effects vent line; vent header; vent line Appendix J,. and is to be The AMR, as supported by bellows; downcomers supplemented to detect evaluated operating experience, fine cracks concluded that cyclic loading from plant heatups and cooldowns, containment testing, and from system vibration was very low or limited in numbers of cycles; therefore, additional methods of detecting postulated cracking are not . warranted. This aging effect and mechanism is not applicable. , Refer to Section 3.5.2.2.1.8 for further information. 3.5.1-14 Concrete elements: dome, wall, Loss of material lSI (IWL). Evaluation is Yes, for Not applicable for Columbia. basemat ring girder, buttresses, (Scaling, cracking, needed for plants that inaccessible containment (as applicable) and spalling) due to are located in moderate areas of plants The Primary Containment is a freeze-thaw to severe weathering located in GE BWR Mark II steel conditions (weathering moderate to containment design located index >100 day-inch/yr) severe within the Reactor Building. (NUREG-1557). weathering This aging effect and conditions mechanism is not applicable. Refer to Section 3.5.2.2.1.9 for further information. Aging Management Review Results Page 3.5-48 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 I Further Item CoAging Effect] Aging Management Evaluation Discussion Number ComponentlCommodity Mechanism Programs Recommended Discussio 3.5.1-15 Concrete elements:

walls, Cracking due to 1ISI (IWL) for accessible Yes, if concrete The design and construction of dome, basemat, ring girder, expansion and areas. None for was not the Columbia concrete is in buttresses, containment, reaction with inaccessible areas if constructed as accordance with accepted ACI concrete fill-in annulus (as aggregate; concrete was stated for Standards. applicable) increase in constructed in inaccessible porosity, accordance with the areas Cracking due to expansion and permeability due to recommendations in reaction with aggregate, and leaching of calcium ACl 201.2R. increase in porosity and hydroxide permeability due to leaching of calcium hydroxide are not aging effects requiring management for the Primary Containment concrete components. The absence of concrete aging effects is.confirmed under the Structures Monitoring Program.Refer to Section 3.5.2.2.1.10 for further information. Aging Management Review Results Page 3.5-49 January 2010 Aging Management Review Results Page 3.5-49 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect/ Aging Management Further Number Component/Commodity

-Mechanism Programs Evaluation Discussion Recommended 3.5.1-15 . Concrete elements: walls, Cracking due to lSI (lWL) for accessible Yes, if concrete The design and construction of dome, basemat, ring girder, expansion and areas. None for was not the Columbia concrete is in buttresses, containment, reaction with inaccessible areas if constructed as accordance with accepted ACI concrete fill-in annulus (as aggregate; concrete was stated for Standards. applicable) increase in constructed in inaccessible porosity, accordance with the areas Cracking due to expansion and permeability to recommendations in reaction with aggregate, and , leaching of calcium ACI201.2R. increase in porosity and hydroxide permeability due to leaching of calcium hydroxide are not aging effects requiring management for the Primary Containment concrete components. The absence of concrete aging effects is.confirmed under the Structures Monitoring Program. Refer to Section 3.5.2.2.1.10 for further information. Aging Management Review Results Page 3.5-49 January 2010 / Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further Item Component/Commodity Aging Effect/ Aging Management Evaluation Discussion Number 'Mechanism Programs Recommended 3.5.1-16 Seals, gaskets, and moisture Loss of sealing and ISI (IWE) and No Consistent with NUREG-1801. barriers leakage through 10 CFR Part 50, containment due to Appendix J The subject aging effects are a deterioration of result of cracking and change in joint seals, gaskets, material properties. Seals and and moisture gaskets for personnel airlock, barriers (caulking, equipment hatch and CRD flashing, and other hatch are evaluated with the sealants) host component. See Item Number 3.5.1-17.The Inservice Inspection (ISI)Program -IWE and the Appendix J Program are used to manage the aging effects of cracking and change in material properties which result in loss of sealing and leakage through containment. The drywell floor peripheral seal is made of stainless steel and is welded to the primary containment vessel and to the underside of the circular closure girder embedded in the drywell floor. There are no elastomeric moisture barrier seals in the drywell floor design.Aging Management Review Results Page 3.5-50 January 2010 Aging Management Review Results Page 3.5-50 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect/ Aging Management Further Component/Commodity Evaluation Discussion Number *Mechanism Programs Recommended 3.5.1-16 Seals, gaskets,ahd moisture Loss of sealing and lSI (IWE) and No Consistent with NUREG-1801. barriers leakage through 10 CFR Part 50, containment due to Appendix J The subject aging effects are a deterioration of result of cracking and change in joint seals, gaskets, material properties. Seals and and moisture gaskets for personnel airlock, barriers (caulking, equipment hatch and CRD flashing, and other hatch are evaiuated with the sealants) host component. See Item Number 3.5.1-17. The Inservice Inspection (lSI) Program -IWE and the Appendix J Program are used to manage the aging effects of cracking and change in material properties which result in loss of sealing and leakage through containment. .. The drywell floor peripheral seal is made of stainless steel and is welded to the primary containment vessel and to the underside of the circular closure girder embedded in the drywell floor. There are no elastomeric moisture barrier seals in the drywell floor design. Aging Management Review Results Page 3.5-50 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 ItemAgig Efect Agig Mnageent Further Item b Component/Commodity Aging Effecth Aging Management Evaluation Discussion Number _ Mechanism Programs Recommended 3.5.1-17 Personnel airlock, equipment Loss of leak 10 CFR Part 50, No Consistent with NUREG-1 801.hatch and CRD hatch locks, tightness in closed Appendix J and Plant hinges, and closure position due to Technical Locks, hinges and closure mechanisms mechanical wear of Specifications mechanisms are evaluated with locks, hinges and the host component.

The closure personnel airlock, equipment mechanisms hatch and CRD removal hatch'are managed by the Inservice Inspection (ISI) Program -IWE and the Appendix J Program.Plant Technical Specification ensures that access airlocks maintain leak tightness in the closed position.3.5.1-18 Steel penetration sleeves and Loss of material ISI (IWE) and No Consistent with NUREG-1801. dissimilar metal welds; due to general, 10 CFR Part 50, personnel airlock, equipment pitting, and crevice Appendix J. The listed components are hatch and CRD hatch corrosion managed by the Inservice Inspection (ISI) Program -IWE and the Appendix J Program.3.5.1-19 Steel elements: stainless steel Cracking due to ISI (IWE) and No Not applicable for Columbia.suppression chamber shell stress corrosion 10 CFR Part 50, (inner surface) cracking Appendix J The Primary Containment is a GE BWR Mark II steel containment design. The suppression chamber is constructed of carbon steel.Aging Management Review Results Page 3.5-51 January 2010 Aging Management Review Results Page 3.5-51 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information

-Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports .Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further . ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-17 Personnel airlock, equipment Loss of leak 10 CFR Part 50, No Consistent with NUREG-1801. hatch and CRD hatch locks, tightness in closed Appendix j and Piant hinges, and closure position due to Technical Locks, hinges and closure mechanisms mechanical wear of Specifications mechanisms are evaluated with locks, hinges and the host component. The closure personnel airlock, equipment mechanisms hatch and CRD removal hatch 'are managed by the InseNice Inspection (lSI) Program -IWE and the Appendix J Program. Plant Technical Specification ensures that access airlocks , maintain leak tightness in the closed position .. 3.5.1-18 Steel penetration sleeves and Loss of material lSI (IWE) and No Consistent witbNUREG-1801. dissimilar metal welds; due to general, 10 CFR Part 50, personnel airlock, equipment pitting, and crevice Appendix J. The listed components are hatch and CRD hatch corrosion managed by the InseNice Inspection (lSI) Program -IWE and the Appendix J Program. 3.5.1-19 Steel elements: stainless steel Cracking due to lSI (lWE) and No Not applicable for Columbia. suppression chamber shell stress corrosion 10 CFR Part 50, (inner surface) cracking Appendix J The Primary Containment is a GE BWR Mark" steel containment design. The suppression.chamber is constructed of carbon steel. Aging Management Review Results Page 3.5-51 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item dity Aging Effectl Aging Management Further Number ComponentI"Commo i' Mechanism Programs Ecommen D Recommended 3.5.1-20 Steel elements: suppression Loss of material ISI (IWE) and No Not applicable for Columbia.chamber liner (interior surface) due to general, 10 CFR Part 50, pitting, and crevice Appendix J The Primary Containment is a corrosion GE BWR Mark II steel containment design. This table item pertains to BWR Mark I and BWR Mark II concrete containments. 3.5.1-21 Steel elements: drywell head Fretting or lock up ISI (IWE) No Columbia's plant operating and downcomer pipes due to mechanical experience has not identified wear fretting or lock up due to mechanical wear for the drywell head and downcomer pipes.The downcomer pipes are embedded in and supported by the reinforced concrete slab of the drywell floor.3.5.1-22 Prestressed containment: Loss of material ISI (IWL) No Not applicable for Columbia.tendons and anchorage due to corrosion components Columbia is not a prestressed containment. There are no tendons associated with the Primary Containment design.Aging Management Review Results Page 3.5-52 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect! Aging Management Further Component!.Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-20 Steel elements: suppression Loss of material lSI (IWE) and No Not applicable for Columbia. chamber liner (interior surface) due to general, 10 CFR Part 50, pitting, and crevice Appendix J The Primary Containment is a corrosion GE BWR Mark II steel containment design. This table item pertains to BWR Mark I andBWR Mark II concrete containments. 3.5.1-21 Steel elements: ,drywell head Fretting or lock up lSI (IWE) No Columbia's plant operating and downcomer pipes due mechanical experience has not identified wear fretting or lock up due to mechanical wear for the drywell head and downcomer pipes. Thedowncomer pipes are embedded in and supported by the reinforced concrete slab of the drywell floor. 3.5.1-22 Prestressed containment: Loss of material lSI (lWL) No Not applicable for Columbia. tendons and anchorage due to corrosion components Columbia is not a prestressed containment There are no tendons associated with the Primary Containment design. Aging Management Review Results Page 3.5-52 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and Ill of NUREG-1801 Further Item Component/Commodity Aging Effect/

Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-23 All Groups except Group 6: Cracking, loss of Structures Monitoring f Yes, if not The Structures Monitoring interior and above grade bond, and loss of Program within the -Program is credited for aging exterior concrete-material (spalling, scope of the management of these effects scaling) due to applicant's and mechanisms for the corrosion of structures affected concrete structural embedded steel monitoring components, in accordance program with the current NRC position, even if the-AMR did not identify aging effects requiring management. Refer to Section 3.5.2.2.2.1 for further information. 3.5.1-24 All Groups except Group 6: Increase in porosity Structures Monitoring Yes, if not The Structures Monitoring interior and above grade and permeability, Program within the Program is credited for aging exterior concrete cracking, loss of scope of the management of these effects material (spalling, applicant's and mechanisms for the scaling) due to structures affected concrete structural aggressive monitoring components, in accordance chemical attack program with the current NRC position, even if the AMR did not identify aging effects requiring management. Refer to Section 3.5.2.2.2.1 for further information. Aging Management Review Results Page 3.5-53 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG*1801 Item Aging Effectl Agil;l9 Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-23 All Groups except Group 6: Cracking, loss of Structures Monitoring Yes, if not The Structures Monitoring interior and above grade bond, and loss of Program within the -Program is credited for aging exterior concrete*

material (spalling, scope of the management of these effects scaling) due to applicant's and mechanisms for the corrosion of structures affected concrete structural embedded steel monitoring components, in accordance program with the current NRC position, even iftheAMR did not identify aging effects requiring , management. Refer to Section 3.5.2.2.2.1 for further information. 3.5.1-24 All Groups except Group 6: Increase in porosity Structures Monitoring Yes, if not The Structures Monitoring interior and above grade and permeability, Program within the Program is credited for aging* exterior concrete cracking, loss of scope of the management of these effects material (spalling, applicant's and mechanisms for the scaling) due to structures affected concrete structural aggressive monitoring components, in accordance chemical attack program with the current NRC position, even if the AMR did not identify aging effects requiring management. Refer to Section 3.5.2.2.2.1 for further information. Aging Management Review Results Page 3.5-53 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 1 Further Item Aging Effect/ Aging Management Evaluation Discussion Number Component/Commodity Mechanism Programs Recommended 3.5.1-25 All Groups except Group 6: Loss of material Structures Monitoring Yes, if not Consistent with NUREG-1 801.steel components: all structural due to corrosion Program. If protective within the steel coatings are relied scope of the The Structures Monitoring upon to manage the applicant's Program is credited for aging effects of aging, the structures management of this aging structures monitoring monitoring effect and mechanism. The program is to include program effect of coating debris on provisions to address ECCS pump suction strainers protective coating has been evaluated to have no monitoring and safety impact on strainer maintenance, operation (see FSAR Section-6.1.2). Containment coatings are subject to ongoing oversight that addresses their current status and will continue to address their status over the period of license renewal.Protective coatings are not relied upon to manage the effects of aging at Columbia.Refer to Section 3.5.2.2.2.1 for further information. Aging Management Review Results Page 3.5-54 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect/ Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-25 All Groups except Group 6: Loss of material Structures Monitoring Yes, if not -Consistent with NUREG-'1801. steel components: all structural due to corrosion Program. If protective within the steel coatings are relied scope of the The Structures Monitoring upon to manage the applicant's Program is credited for aging effects of aging, the structures management of this aging structures monitoring monitoring effect and mechanism. The program is to include program effect of coating debris on provisions to address ECCS pump suction strainers protective coating has been evaluated to have no monitoring and safety impact on strainer maintenance. operation (see FSAR Section .6.1.2). Containment coatings are subject to ongoing oversight that addresses their current status and will continue to address their status over the period of license renewal. Protective coatings are not relied upon to manage the -effects of aging at Columbia. Refer to Section 3.5.2.2.2.1 for further information. Aging Management Review Results Page 3.5-54 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item I Aging Effect/ Aging Management Further Evaluation Discussion Number ComponentCommodity Mechanism Programs Recommended 3.5.1-26 All Groups except Group 6: Loss of material Structures Monitoring

] Yes, if not The Structures Monitoring accessible and inaccessible (spailing, scaling) Program. Evaluation is within the Program is credited for aging concrete: foundation and cracking due needed for plants that scope of the management of these effects to freeze-thaw are located in moderate applicant's and mechanisms for the to severe weathering structures affected concrete structural conditions (weathering monitoring components, in accordance index >100 day-inch/yr) program with the current NRC position, (NUREG-1557). even if the AMR did not identify aging effects requiring management. Or Refer to Section 3.5.2.2.2.1 for further information. for inaccessible Refer to Section 3.5.2.2.2.2.1 areas of plants for further information. located in moderate to severe weathering conditions Aging Management Review Results Page 3.5-55 January 2010 Aging Management Review Results Page 3.5-55 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect! Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-26 All Groups except Group 6: Loss of material Structures Monitoring Yes, if not The Structures Monitoring accessible and inaccessible (spaiiing, scaiing) Program. Evaiuation is within the Program is ciedited fOi aging concrete:

foundation and cracking due needed for plants that scope of the management of these effects to freeze-thaw are located in moderate applicant's and mechanisms for the to severe weathering structures affected concrete structural conditions (weathering monitoring components, in accordance index >100 day-inch/yr) program with the current NRC position, (NUREG-1557). even if the AMR did not identify aging effects requiring management. Or Refer to Section 3:5.2.2.2.1 for further information. for inaccessible Refer to Section 3.5.2.2.2.2.1 areas of plants for further information. located in moderate to severe weathering conditions -Aging Management Review Results Page 3.5-55 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 T Further Item CCAging Effect/ Aging Management Evaluation Discussion Number ComponentlCommodity Mechanism Programs Recommended 3.5.1-27 All Groups except Group 6: Cracking due to Structures Monitoring Yes, if not The Structures Monitoring accessible and inaccessible expansion due to Program. within the Program is credited for aging interior/exterior concrete reaction with None for inaccessible scope of the management of these effects aggregates areas if concrete was applicant's and mechanisms for the constructed in structures affected concrete structural accordance with the monitoring components, in accordance recommendations in program with the current NRC position, ACI 201.2R-77. even if the AMR did not identify aging effects requiring management. Refer to Section 3.5.2.2.2.1 for further information. Or concrete was The design and construction of not constructed the Columbia concrete is in as stated for accordance with accepted ACI inaccessible Standards, thereby precluding areas the reaction with aggregates aging mechanism. Refer to Section 3.5.2.2.2.2.2 for further information. Aging Management Review Results Page 3.5-56 January 2010 0 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further i Item ComponentiCommodity Aging Effectl Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-27 All Groups except Group 6: Cracking due to Structures Monitoring Yes, if not The Structures Monitoring accessible and inaccessible expansion due to Program. within the Program is credited for aging interior/exterior concrete reaction with None for inaccessible scope of the management of these effects aggregates areas if concrete was applicant's and mechanisms for the constructed in structures affected concrete structural accordance with the monitoring components, in accordance recommendations in program with the current NRC position, ACI 201.2R-77. even if the AMR did not identify aging effects requiring . management. Referto Section 3.5.2.2.2.1 for further information. Or concrete was The design and construction of. not constructed the Columbia concrete is in as stated for accordance with accepted ACI inaccessible Standards, thereby precluding areas the reaction with aggregates aging mechanism. Refer to Section 3.5.2.2.2.2.2 for further information. , Aging Management Review Results Page 3.5-56 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further Item .Aging Effect/ Aging Management Evaluation Discussion Number Component/Commodity Mechanism Programs Recommended 3.5.1-28 Groups 1-3, 5-9: All Cracks and Structures Monitoring I Yes, if not The Structures Monitoring distortion due to Program. If a de- within the Program is credited for aging increased stress watering system is scope of the management of these effects levels from relied upon for control applicant's and mechanisms for the settlement of settlement, then the structures affected concrete structural licensee is to ensure monitoring components, in accordance proper functioning of program with the current NRC position, the de-watering system even if the AMR did not identify through the period of aging effects requiring extended operation.

management. Refer to Section 3.5.2.2.2.1 for further information. Or a de-watering Columbia does not employ a system is relied de-watering system at any of upon the site structures for control of settlement. Refer to Section 3.5.2.2.2.2.3 for further information. Aging Management Review Results Page 3.5-57 January 2010 Aging Management Review Results -Page 3.5-57 January 2010* r *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item '. Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs*

Recommended 3.5.1-28 Groups 1-3, 5-9: All Cracks and Structures Monitoring Yes, if not The Structures Monitoring distortion due to Program. If a de-within ihe Program is credited for aging increased stress watering system is scope of the management of these effects levels from relied up-on for control applicant's and mechanisms for the settlement of settlement, then the structures affected concrete structural licensee is to ensure monitoring components, in accordance proper functioning of program with the current NRC position, the de-watering system even if the AMR did not identify through the period of aging effects requiring extended operation. management. Refer to Section 3.5.2.2.2.1 for -further information. Or a de-watering Columbia does not employ a system is relied de-watering system at any of upon the site structures for control of \ settlement. Refer to Section 3.5.2.2.2.2.3 for further information. Aging Management Review Results Page 3.5-57 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 I Further Item CCAging Effectl Aging Management Evaluation Discussion Number Component/Commodity Mechanism Programs Recommended 3.5.1-29 Groups 1-3, 5-9: foundation Reduction in Structures Monitoring Yes, if not Not applicable for Columbia.foundation Program. If a de- within the strength, cracking, watering system is scope of the The concrete foundations at differential relied upon for control applicant's Columbia are not constructedsettlement due to of settlement, then the structures with porous concrete and are erosion of porous licensee is to ensure monitoring not subject to flowing water.concrete proper functioning of program subfoundation the de-watering system Refer to Section 3.5.2.2.2.1 for through the period of further information. extended operation. Or a de-watering Columbia does not employ a system is relied de-watering system at any of upon the site structures for control of settlement. Refer to Section 3.5.2.2.2.1 for further information. Aging Management Review Results Page 3.5-58 January 2010 Aging Management Review Results Page 3.5-58 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-29 Groups 1-3, 5-9: foundation Reduction in Structures Monitoring Yes, if not Not applicable for Columbia. foundation Program. If a de-within the strength, cracking, watering system is scope of the The concrete foundations at differential relied upon for control applicant's Columbia are not constructed J settlement due to of settlement, then the structures with porous concrete and are -erosion of porous licensee is to ensure monitoring not subject to flowing water. concrete proper functioning of program subfoundation the de-watering system Refer to Section 3.5.2.2.2.1 for through the period of further information. extended operation. Or a de-watering Columbia does not employ a system is relied de-watering system at any of upon the site structures for control of s.ettlement. Refer to Section 3.5.2.2.2.1 for further information. Aging Management Review Results Page 3.5-58 January 2010 * *

• Columbia Generating Station, License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect/ Aging Management Evaluation Discussion Number Cmoetomd tyMechanism ProgramsEvlainDsuio Recommended 3.5.1-30 Group 4: Radial beam seats in Lock-up due to ISI (IWF) or Structures Yes, if not Aging degradations of supports BWR drywell; RPV support wear monitoring Program within the designed with or without sliding shoes for PWR with nozzle scope of ISI or connections are managed by supports; Steam generator structures the Inservice Inspection (ISI)supports monitoring Program -IWF and the program Structures Monitoring Program.The inspection criteria for supports within the programs effectively envelope misalignment and accumulation of debris.Lubrite material resists deformation, has a low coefficient of friction, resists softening at elevated temperatures, absorbs grit and abrasive particles, is not susceptible to corrosion, withstands high intensities of radiation, and will not score or mar. The Lubrite lubricants used in nuclear applications are designed for the environments to which they are exposed.There are no known aging effects that would leadto a loss of intended function.Refer to Section 3.5.2.2.2.1 for-further information.

Aging Management Review Results Page 3.5-59 January 2010* *

• Columbia Generating Station, License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG:'1801 Item Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-30 Group 4: Radial beam seats in Lock-up due to lSI (IWF) or Structures Yes, *if not Aging degradations of supports BWR drywell; RPV support wear monitoring Program within the designed with or without sliding shoes for PWR with nozzle scope of lSI or connections are managed by . supports; .Steam generator structures the Inservice Inspection (lSI) supports monitoring Program -IWF and the program Structures Monitoring Program. The inspection criteria for supports within the programs.

effectively envelope misalignment and accumulation of debris. Lubrite material resists deformation, has a low .. coefficient of friction, resists softening at elevated temperatures, absorbs grit and abrasive particles, is not susceptible to corrosion, . withstands high intensities of , radiation, and will not score or mar. The Lubrite lubricants used in nuclear applications are designed for the environments to which they are exposed. There are no known aging effects that would lead,to a loss of intended function. , Refer to Section 3.5.2.2.2.1 for -further information. Aging Management Review Results Page 3.5-59 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item 1 Aging Effect/ Aging Management Further Number Component/Commodity Mechanism Programs Evaluation Discussion Recommended 3.5.1-31 Groups 1-3, 5, 7-9: below- Increase in porosity Structures Monitoring Yes, plant- The Structures Monitoring grade concrete components, and permeability, Program; Examination specific, if Program is credited for aging such as exterior walls below cracking, loss of of representative environment is management of these effects grade and foundation material (spalling, samples of below- aggressive and mechanisms for the scaling)/ grade concrete, and affected concrete structural aggressive periodic monitoring of components, in accordance chemical attack; groundwater, if the with the current NRC position, Cracking, loss of environment is non- even if the AMR did not identify bond, and loss of aggressive. A plant aging effects requiring material (spalling, specific program is to management. The Structures scaling)/corrosion be evaluated if Monitoring Program will include of embedded steel environment is review of site ground water and aggressive, raw water pH, chlorides, and sulfates in order to validate that the below-grade environment remains non-aggressive during the period of extended operation and will include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. Refer to Section 3.5.2.2.2.2.4 for further information. Aging Management Review Results Page 3.5-60 January 2010 Columbia Generating Station License Renewal Application Technical Information Table Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-31 Groups 1-3, 5, 7-9: below-Increase in porosity Structures Monitoring Yes, plant-The Structures Monitoring grade concrete components, and permeability, Program; Examination specific, if Program is credited for aging such as exterior walls below cracking, loss of of representative environment is management of these effects grade and foundation material (spalling, samples of below-aggressive and mechanisms for the scaling)! grade concrete, and affected concrete structural -aggressive periodic monitoring of components, in accordance chemical attack; groundwater, if the with the current NRC position, Cracking, loss of environment is non-even if the AMR did not identify bond, and loss of aggressive. A plant aging effects requiring material (spalling, specific program is to management. The Structures scaling)!corrosion be evaluated if Monitoring Program will include of embedded steel environment is review of site ground water and aggressive. raw water pH, chlorides, and sulfates in order to validate that the below-grade environment remains non-aggressive during the period of extended operation and will include examination of exposed concrete for age-related degradation when a below-grade concrete component becomes accessible through excavation. Refer to Section 3.5.2.2.2.2.4 for further information. Aging Management Review Results Page 3.5-60 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 1 Further Item Aging Effect/

Aging Management Euatis s CmoetCmoiyEvaluation Discussion Number Mechanism Programs Recommended 3.5.1-32 Groups 1-3, 5, 7-9: exterior Increase in porosity Structures monitoring Yes,.if concrete The design and construction of above and below grade and permeability, 'Program for accessibie was not the Columbia concrete is in reinforced concrete foundations and loss of areas. None for constructed as accordance with accepted ACI strength due to inaccessible areas if stated for Standards, thereby precluding leaching of calcium concrete was inaccessible the leaching of calcium hydroxide constructed in areas hydroxide aging mechanism. accordance with the recommendations in Columbia concrete is not ACI 201.2R-77. exposed to flowing water or groundwater hydraulic pressure, therefore, these aging effects and mechanisms do not require management for the below-grade inaccessible concrete structural components. Refer to Section 3.5.2.2.2.2.5 for further information. 3.5.1-33 Groups 1-5: concrete Reduction of A plant-specific aging Yes, plant- Columbia in-scope concrete strength and management program specific if structures and concrete modulus of is to be evaluated, temperature components are not exposed to concrete due to limits are temperature limits associated elevated exceeded with aging degradation due to temperature elevated temperature. Refer to Section 3.5.2.2.2.3 for further information. Aging Management Review Results Page 3.5-61 January 2010 e_ e e Columbia Generating Station License Renewal Application Technical Information .' Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 , Further Item ComponentlCommodity Aging Effectl Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-32 Groups 1-3, 5,7-9: exterior Increase in porosity Structures monitoring Yes,if concrete The design and construction of above and below grade and permeability, . Program for accessibie was noi the Columbia concrete is in reinforced concrete foundations and loss of areas. None for constructed as accordance with accepted ACI strength due to inaccessible areas if stated for Standards, thereby precluding leaching of calcium concrete was inaccessible the leaching of calcium hydroxide constructed in areas hydroxide aging mechanism. accordance with the recommendations in Columbia concrete is not ACI 201.2R-77. exposed to flowing water or -groundwater hydraulic pressure, therefore, these aging effects and mechanisms . do not require management for the below-grade inaccessible concrete structural components. Refer to Section 3.5.2.2.2.2.5 for further information. 3.5.1-33 Groups 1-5: concrete Reduction of A plant-specific aging Yes, plant-Columbia in-scope concrete strength and management program specific if structures and concrete modulus of is to be evaluated. temperature components are not exposed to concrete due to limits are temperature limits associated elevated exceeded with aging degradation due to temperature elevated temperature. Refer to Section 3.5.2.2.2.3 for further information. Aging Management Review Results Page 3.5-61 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 j Further Item Aging Effect/ Aging Management Euatiss Itm Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-34 Group 6: Increase in porosity Inspection of Water- Yes, plant- The Columbia Group 6 Concrete; and permeability, Control Structures or specific if structures concrete is not all cracking, loss of FERC/US Army Corps environment is exposed to an aggressive material due to of Engineers dam aggressive environment and the design aggressive inspections and and construction of the chemical attack; maintenance programs concrete is in accordance with cracking, loss of and for inaccessible accepted ACI Standards, bond, loss of concrete, an thereby precluding aggressive material due to examination of chemical attack and embedded corrosion of representative samples steel corrosion aging embedded steel of below-grade mechanisms. concrete, and periodic monitoring of, The absence of concrete aging groundwater, if the effects is confirmed under the environment is non- Structures Monitoring Program aggressive. A plant -Water Control Structures specific program is to Inspection. be evaluated if environment is Columbia is not committed to aggressive. Regulatory Guide (RG) 1.127, Inspection of Water-ControlStructures Associated with Nuclear Power Plants. The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection. Refer to Section 3.5.2.2.2.4.1 for further information. Aging Management Review Results Page 3.5-62 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Progr:ams Recommended 3.5.1-34 Group 6: , Increase in porosity Inspection of Water-Yes, plant-The Columbia Group 6 Concrete; and permeability, Control Structures or specific if structures concrete is not all cracking, loss of FERC/US Army Corps environment is exposed to an aggressive material due to of Engineers dam aggressive environment and the design aggressive inspections and and construction of the chemical attack; maintenance programs concrete is in accordance with cracking, loss of and for inaccessible accepted ACI Standards, bond, loss of concrete, an thereby precluding aggressive material due to examination of chemical attack and embedded corrosion of _. representative samples steel corrosion aging embedded steel of below-grade mechanisms. concrete, and periodic monitoring of, The absence of concrete aging groundwater, if the effects is confirmed under the environment is non-Structures Monitoring Program aggressive. A plant -Water Control Structures specific program is to Inspection. . be evaluated if environment is Columbia is not committed to aggressive. Regulatory Guide (RG) 1.127, Inspection of Water-Control Structures Associated with Nuclear Power Plants. The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection. Refer to Section 3.5.2.2.2.4.1 for further information. Aging Management Review Results Page 3.5-62 January 2010 * *

• 0 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further Item ComponentCommodity Aging Effect/ Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-35 Group 6: exterior above and Loss of material Inspection of Water- Yes, for The Structures Monitoring below grade concrete (spalling, scaling) Control Structures or inaccessible Program -Water Control foundation and cracking due FERC/US Army Corps areas of plants Structures Inspection is to freeze-thaw of Engineers dam located in credited for aging management inspections and moderate to and includes the 10 elements maintenance programs.

severe evaluation for the NUREG-1 801 Evaluation is needed weathering XI.S7 aging management for plants that are conditions program.located in moderate to severe weathering Columbia is not committed to conditions (weathering Regulatory Guide (RG) 1.127,index >100 day-inch/yr) Inspection of Water-Control (NUREG-1557). Structures Associated with, Nuclear PowerPlants. The Structures Monitoring Program encompasses and implements the Water Control Structures inspection. Loss of material (spalling, scaling) and cracking due to freeze-thaw are aging effects requiring management for concrete components exposed to raw water because the concrete may become saturated and therefore could be susceptible to freeze-thaw.

• Refer to Section 3.5.2.2.2.4.2 for further information.

Aging Management Review Results Page 3.5-63 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters \I and 11\ of NUREG-1801 Item Aging Effectl Aging Management Further / . ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-35 Group 6: exterior above and Loss of material Inspection of Water-Yes, for The Structures Monitoring below grade concrete (spalling, scaling) Control Structures or inaccessibie Program -Water ContiOl foundation and cracking due FERC/US Army Corps areas of plants Structures Inspection is to freeze-thaw of Engineers dam located in credited for aging management inspections and moderate to and includes the 10 elements maintenance programs.

severe evaluation for the NUREG-1801 Evaluation is needed weathering XI.S7 aging management for plants that are conditions program. located in moderate to severe weathering Columbia is not committed to conditions (weathering Regulatory Guide (RG) 1.127, index> 100 day-inch/yr) Inspection of Water-Control (NUREG-1557). Structures Associated with' Nuclear Power Plants. The Structures Monitoring Program encompasses and implements the Water Control Structures ,Inspection. Loss of material (spalling, scaling) and cracking due to freeze-thaw are aging effects requiring management for concrete components exposed to raw water because the concrete may become . saturated and therefore could be susceptible to freeze-thaw. -Refer to Section 3.5.2.2.2.4.2 for further information. Aging Management Review Results . Page 3.5-63 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further 3.5.1-36 Group 6: all accessible/ Cracking due to Accessible areas: Yes, if concrete The design and construction of inaccessible reinforced expansion/ reaction Inspection of Water- was not the Columbia concrete is in concrete with aggregates Control Structures or constructed as accordance with accepted ACI FERC/US Army Corps stated for Standards, thereby precluding of Engineers dam inaccessible the expansion and reaction with inspections and areas aggregate aging mechanism. maintenance programs.The absence of concrete aging None for inaccessible effects is confirmed under the areas if concrete was Structures Monitoring Program constructed in -Water Control Structures accordance with the Inspection. The Structures recommendations in Monitoring Program includes ACI 201.2R-77. the 10 elements evaluation for the NUREG-1801 XI.S7 aging management program.Columbia is not committed to Regulatory Guide (RG) 1.127, Inspection of Water-Control Structures Associated with Nuclear Power Plants. The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection. Refer to Section 3.5.2.2.2.4.3 for further information. Aging Management Review Results Page 3.5-64 January 2010 9 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-36 Group 6: all accessible! Cracking due to Accessible areas: Yes, if concrete The design and construction of inaccessible reinforced expansion! reaction Inspection of Water-was not the Columbia concrete is in concrete with aggregates Control Structures or constructed as accordance with accepted ACI FERC!US Army Corps stated for Standards, thereby precluding of Engineers dam inaccessible the expansion and reaction with inspections and areas aggregate aging mechanism. maintenance programs. , The absence of concrete aging None for inaccessible effects is confirmed under the areas if concrete was Structures Monitoring Program constructed in -Water Control Structures accordance with the Inspection. The Structures recommendations in Monitoring Program includes ACI 201.2R-77. the 10 elements evaluation for the NUREG-1801 XI.S7 aging management program. Columbia is not committed to Regulatory Guide (RG) 1.127, Inspection of Water-Control Structures Associated with Nuclear Power Plants. The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection. Refer to Section 3.5.2.2.2.4.3 for further information. Aging Management Review Results Page 3.5-64 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item ComponentlCommodity Aging Effect/ Aging Management Further Number _ _ _ _ _ Mechanism Programs Ecommended Recommended 3.5.1-37 Group 6: exterior above and. Increase in porosity For accessible areas, Yes, if concrete j The design and construction of below grade reinforced and permeability, inspection of VVater- was not the Columbia concrete is in concrete foundation interior loss of strength Control Structures or constructed as accordance with accepted ACI slab due to leaching of FERC/US Army Corps stated for Standards, thereby precluding calcium hydroxide of Engineers dam inaccessible leaching of calcium hydroxide.

inspections and- areas aging mechanisms. maintenance programs.None for inaccessible The absence of concrete aging areas if concrete was effects is confirmed under the constructed in Structures Monitoring Program accordance with the -Water Control Structures recommendations in Inspection. The Structures ACI 201.2R-77. Monitoring Program includes the 10 elements evaluation for the NUREG-1 801 XI.S7 aging management program.Columbia is not committed to Regulatory Guide (RG) 1.127, Inspection of Water-Control Structures Associated with Nuclear Power Plants. The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection. Refer to Section 3.5.2.2.2.4.3 for further information. Aging Management Review Results Page 3.5-65 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect! Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-37 Group 6: exterior above and. Increase in porosity For accessible areas, Yes, if concrete The design and construction of below grade reinforced and permeability, inspection of Water-was not the Columbia concrete is in concrete foundation interior loss of strength Control Structures or constructed as accordance with accepted ACI slab due to leaching of FERC/US Army Corps stated for Standards, thereby precluding calcium hydroxide of Engineers dam inaccessible leaching of calcium hydroxide.

inspections and_ areas aging mechanisms. maintenance programs. None for inaccessible The absence of concrete aging areas if concrete was effects is confirmed under the constructed in Structures Monitoring Program accordance with the -Water Control Structures recommendations in Inspection. The Structures ACI 201.2R-77. Monitoring Program includes the 10 elements evaluation for the NUREG-1801 XI.S7 aging management program. Columbia is not committed* to Regulatory Guide (RG) 1.127, Inspection of Water-Control Structures Associated with Nuclear Power Plants. The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection. Refer to Section 3.5.2.2.2.4.3 for further information. Aging Management Review Results Page 3.5-65 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-18011 1 Further Item i Aging Effect/ Aging Management Evaluation Discussion Number ComponentCommodit Mechanism Programs Recommended3.5.1-38 Groups 7, 8: Tank liners Cracking due to A plant-specific aging Yes, plant No tanks with stainless steel stress corrosion management program specific liners are included in the cracking; loss of is to be evaluated structural AMRs. Tanks subject material due to to AMR are evaluated with their pitting and crevice respective mechanical systems.corrosion Refer to Section 3.5.2.2.2.5 for further information. 3.5.1-39 Support members; welds; Loss of material Structures Monitoring Yes, if not Consistent with NUREG-1 801.bolted connections; support due to general and Program within the anchorage to building structure pitting corrosion scope of the Loss of material due to general applicant's and pitting corrosion for Groups structures B2-B5 supports is managed by monitoring the Structures Monitoring program Program.Refer to Section 3.5.2.2.2.6 for further information. Aging Management Review Results Page 3.5-66 January 2010 Columbia Generating Station* License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-38 Groups 7, 8: Tank liners Cracking due to A plant-specific aging Yes, plant No tanks with stainless steel stress corrosion. management program specific liners are included in the cracking; loss of is to be evaluated structural AMRs. Tanks subject material due to to AMR are evaluated with their pitting and crevice respective mecha*nical systems. corrosion Refer to Section 3.5:2.2.2.5 for further information. 3.5.1-39 Support members; welds; Loss of material Structures Monitoring Yes, if not Consistent with NUREG-1801. bolted connections; support due to general and Program within the anchorage to building structure pitting corrosion scope of the Loss of material due to general applicant's and pitting corrosion for Groups structures 82-85 supports is managed by monitoring the Structures Monitoring program Program. Refer to Section 3.5.2.2.2.6 for further information. Aging Management Review Results Page 3.5-66 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters 11 and III of NUREG-1801 Further Item Component/Commodity Aging Effecth Aging Management Evaluation Discussion Mechanism Programsed 3.5.1-401 Building concrete at locations of Reduction in Structures Monitoring Yes, if not The Structures Monitoring expansion and grouted concrete anchor Program Mwithin the Program is credited for aging anchors; grout pads for support capacity due to scope of the management of these effects base plates local concrete applicant's and mechanisms for the degradation/

structures affected concrete structural service-induced monitoring components, in accordance cracking or other program with the current NRC position, concrete aging even if the AMR did not identify mechanisms ,aging effects requiring management. Refer to Section 3.5.2.2.2.6 for further information. Aging Management Review Results Page 3.5-67 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended r 3.5.140 Building concrete at locations of Reduction in Structures Monitoring Yes, if not The Structures Monitoring expansion and grouted concrete anchor Program within the Program is credited for aging anchors; grout pads for support capacity due to scope of the management of these effects base plates local concrete applicant's and mechanisms for the degradation/

structures affected concrete structural -/ service-induced monitoring components, in accordance cracking or other program with the current NRC position, concrete aging even if the AMR did not identify mechanisms ,aging effects requiring management. Refer to Section 3.5.2.2.2.6 for further information. Aging Management Review Results Page 3.5-67 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further Item Component/Commodity Aging Effect! Aging Management Evaluation Discussion Number iMechanism Programs Recommended 3.5.1-41 Vibration isolation elements Reduction or loss Structures Monitoring Yes, if not Degradation of vibration of isolation Program within the isolation elements for Group B4 function/radiation scope of the supports is managed by the hardening, applicant's Structures Monitoring Program.temperature, structures humidity, sustained monitoring Vibration isolation elements are vibratory loading program not used on Columbia's vibratory and rotating equipment such as pumps, compressors, or air handling units. However, vibration isolators are used on certain control panels within skidmounted complex assemblies such as the diesel engine.These components are treated as sub component to the host component and are managed as part of the host component during Structures Monitoring Program inspections. Refer to Section 3.5.2.2.2.6 for further information. Aging Management Review Results Page 3.5-68 January 2010 Aging Management Review Results Page 3.5-68 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-41 Vibration isolation elements Reduction or loss Structures Monitoring Yes, if not Degradation of vibration of isolation Program within the isolation elements for Group B4 function/radiation scope of the supports is managed by the hardening, applicant's Structures Monitoring Program. temperature, structures humidity, sustained monitoring Vibration isolation elements are vibratory loading program not used on Columbia's vibratory and rotating equipment such as pumps, compressors, or air handling units. However, vibration isolators are used on certain control panels within skid mounted complex assemblies such as the diesel engine. These components are treated "--as sub component to the host component and are managed as part of the host component during Structures Monitoring Program inspections. Refer to Section 3.5.2.2.2.6 for further information. Aging Management Review Results Page 3.5-68 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further Item Component/Commodity Aging Effect/ Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-42 Groups B1.1, B1.2, and B1.3: Cumulative fatigue TLAA, evaluated in j Yes, TLAA No fatigue analyses were,support members:

anchor bolts, damage (CLB accordance with identified for component welds fatigue analysis 10 CFR 54.21(c) support members, anchor bolts, exists) and welds for Groups B13.1, B1.2, and B1.3.Refer to Section 3.5.2.2.2.7 for further information. 3.5.1-43 Groups 1-3, 5, 6: all masonry Cracking due to Masonry Wall Program No Masonry block walls are block walls restraint shrinkage, managed by the Structures creep, and Monitoring Program -Masonry aggressive Wall Inspection. The environment Structures Monitoring Program includes the 10 elements evaluation for the NUREG-1 801.XI.S5 aging management program.Masonry block walls with a fire barrier intended function arealso managed by the Fire Protection Program.The Structures Monitoring Program encompasses and implements the Masonry Wall Inspection. Aging Management Review Results Page 3.5-69 January 2010* * * \-Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for. Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 , Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-42 Groups 81.1, 81.2, and B1.3: Cumulative fatigue TlAA, evaluated in Yes, TlAA No fatigue analyses were* support members: anchor bolts, damage (CLB acco(dance with identified for component welds fatigue analysis 10 CFR 54.21 (c) support members, anchor bolts, exists) and welds for Groups 81.1, B1.2, and 81.3. Refer to Section 3.5.2.2.2.7 for further information. 3.5.1-43 Groups 1-3, 5,6: all masonry Cracking due to Masonry Wall Program No Masonry block walls are block walls restraint shrinkage, managed by the Structures creep, and Monitoring Program -Masonry aggressive Wall Inspection. The environment Structures Monitoring Program includes the 10 elements evaluation for the NUREG-1801 . XI.S5 aging management program. " Masonry block walls with a fire barrier intended function are also managed by the Fire Protection Program. The Structures Monitoring Program encompasses and , implements the Masonry Wall Inspection. Aging Management Review Results Page 3.5-69 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 1 Further Nuem b r Aging Effect] Pron g rMan gms n Recom mende Item Component/Commodity Mechanism Aging Management Evaluation Discussion Numbr Mchaism rogams Recommended 3.5.1-44 Group 6 elastomer seals, Loss of sealing due Structures Monitoring No Consistent with NUREG-1 801.gaskets, and moisture barriers to deterioration of Programseals, gaskets, and Elastomeric components formoisture barriers Groups 1-3, 5, 6 structures are (caulking, flashing, managed by the Structures and other sealants) Monitoring Program.Seals with a fire barrier intended function are managed by the Fire Protection Program.See Item Number 3.3.1-61.Loss of sealing is not an aging effect, but rather a consequence of elastomer degradation. Loss of sealing may be caused by cracking or change in material properties aging effects for elastomeric material.Aging Management Review Results Page 3.5-70 January 2010-Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect! Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recoinmended 3.5.1-44 Group 6 elastomer seals, Loss of sealing due Structures Monitoring No Consistent with NUREG-1801. gaskets, and moisture barriers to deterioration of Program seals, gaskets, and Elastomeric components for moisture barriers Groups 1-3, 5, 6 structures are (caulking, flashing, managed by the Structures and other sealants) Monitoring Program. -Seals with a fire barrier intended function are managed by the Fire Protection Program. See Item Number 3.3.1-61. Loss of sealing is not an aging effect, but rather a consequence of elastomer degradation. Loss of sealing may be caused by cracking or change in material properties aging effects for elastomeric material. Aging Management Review Results Page 3.5-70 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801e AFurther Item Component/Commodity Aging Effect Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-45 Group 6: exterior above and Loss of material Inspection of Water- No Loss of material due to below grade concrete due to abrasion, Control Structures or abrasion or cavitation is not an foundation; interior slab cavitation FERC/US Army Corps aging effect requiring of Engineers dam management for concrete inspections and components exposed to raw maintenance water because the Spray Pond water does not contain abrasive material and flow velocity in water control structures is less than the cavitation threshold.

The absence of concrete aging effects is confirmed under the Structures Monitoring Program-Water Control Structures Inspection .The Structures Monitoring Program includes the 10 elements evaluation for the NUREG-1801 XI.S7 aging management program.Columbia is not committed toRegulatory Guide (RG) 1.127, Inspection of Water-Control Structures Associated with Nuclear Power Plants. The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection. Aging Management Review Results Page 3.5-71 January 2010 Aging Management Review Results Page 3.5-71 January 2010*

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-45 Group 6: exterior above and Loss of material Inspection of Water-No Loss of material due to below grade concrete due to abrasion, Controi Structures or abrasion Oi cavitation is not an foundation; interior slab cavitation

-FERC/US Army Corps aging effect requiring of Engineers dam management for concrete inspections and components exposed to raw maintenance water because the Spray Pond water does not contain abrasive material and flow velocity in water control structures is less than the cavitation threshold. The absence of concrete aging effects is confirmed under the Structures Monitoring Program -Water Control Structures Inspection. The Structures Monitoring Program includes ' the 10 elements evaluation for the NUREG-1801 XI.S7 aging management program. Columbia is not committed to Regulatory Guide (RG) 1.127, Inspection of Water-Control Structures Associated with Nuclear Power Plants. The '0 Structures Monitoring Program encompasses and implements the Water Control Structures Inspection. Aging Management Review Results Page 3.5-71 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further Item Aging Effect] Aging Management Evaluation Discussion Number ComponentlCommodity Mechanism Programs Recommended 3.5.1-46 Group 5:-Fuel pool liners Cracking due to Water Chemistry and No Consistent with NUREG-1 801.stress corrosion monitoring of spent fuel cracking; loss of pool water level in Loss of material is managed by material due to accordance with the BWR Water Chemistry pitting and crevice technical specifications Program, monitoring of spent corrosion and leakage from the fuel pool water level in leak chase channels. accordance with Technical Specifications, and monitoring of leak chase channels. The leak chase channels are designed to permit free gravity drainage to the radioactive drain system, the flow of which is monitored via operator rounds under the CLB as stated in FSAR Section 9.1.2.2.2. Cracking due to SCC is not an aging effect requiring management because SCC occurs through the combination of high stress (both applied and residual tensile stresses), acorrosive environment and temperature, which are not found in the spent fuel pool.The spent fuel pool water temperature is below the 140°F threshold during normal operation. Aging Management Review Results Page 8.5-72 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect/ Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-46 Group 5:-Fuel pool liners Cracking due to Water Chemistry and No Consistent with NUREG-1801. stress corrosion monitoring of spent fuel -, cracking; loss of pool water level in Loss of material is managed by material due to accordance with . the BWR Water Chemistry pitting and crevice technical specifications Program, monitoring of spent corrosion and leakage from the fuel pool water level in leak chase channels. accordance with Technical . Specifications, and monitoring of leak chase channels. The leak chase channels are designed to permit free gravity drainage to the radioactive drain system, the flow of which is monitored via operator rounds under the CLB as stated in FSAR Section 9.1.2.2.2. Cracking due to SCC is not an aging effect requiring management because SCC occurs through the combination of high stress (both applied and residual tensile stresses), a "' corrosive environment and temperature, which are not found in the spent fuel pool. The spent fuel pool water temperature is below the 140°F threshold during normal J operation. Aging Management Review Results Page 3.5-72 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect/ A g Further Component/Commodity m I Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-47 Group 6: all metal structural Loss of material Inspection of Water- No Metal structural components members due to general Control Structures or within Group 6 structures are (steel only), pitting FERC/US Army Corps managed by the Structures and crevice of Engineers dam Monitoring Program -Water corrosion inspections and Control Structures Inspection.

maintenance. If The Structures Monitoring protective coatings are Program includes the 10 relied upon to manage elements evaluation for the aging, protective NUREG-1801 XI.S7 aging coating monitoring and management program.maintenance provisions should be included. Columbia is not committed to Regulatory Guide (RG) 1.127, Inspectiori of Water-Control Structures Associated with Nuclear Power Plants. The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection. ASME metal structural components associated with Group 6 structures are managed by the Inservice Inspection (ISI) Program -IWF.Aging Management Review Results Page 3.5-73 January 2010* *

• Columbia Generating Station . License Renewal Application Technical Information . Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters" and'" of NUREG-1801 Item Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism

-Programs Recommended 3.5.1-47 Group 6: all metal structural Loss of material Inspection of Water-No Metal structural components members due to general Controi Structures or within Group 6 structures are (steel only), pitting FERC/US Army Corps managed by the Structures and crevice of Engineers dam Monitoring Program -Water corrosion inspections and Control Structures Inspection. maintenance. If The Structures Monitoring protective coatings are Program includes the 10 relied upon to manage elements evaluation for the aging, protective NUREG-1801 XI,S7 aging coating monitoring and management program. maintenance provisions should be included. Columbia is not committed to Regulatory Guide (RG) 1.127, 'Inspection of Water-Control Structures Associated with Nuclear Power Plants. The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection. ASME metal structural components associated with GroLip 6 structures are managed by the Inservice Inspection (lSI) Program -IWF. Aging Management Review Results Page 3.5-73 January 2010 Columbia Generating StationLicense Renewal Application Technical Information table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further Item Component/Commodity Aging Effect/ Aging Management Evaluation Discussion Reomendedj NubrMechanism Programs Recommene 3.5.1-48 Group 6: earthen water control Loss of material, Inspection of Water- No Not applicable for Columbia.structures -dams, loss of form due to Control Structures or embankments, reservoirs, erosion, FERC/US Army Corps There are no earthen structures channels, canals, and ponds settlement, of Engineers dam associated with the standby sedimentation, inspections and Service Water Pump House or frost action, waves, maintenance programs the-Spray Pond.currents, surface runoff, seepage Under the current licensing bases the Spray Pond includes a 6-inch sedimentation allowance for water inventory considerations. This allowance includes all forms of accumulation, such as dust, silt,or volcanic ash. The sprayponds are cleaned whenever the sedimentation reaches 3 inches, which ensures adequate water supply even in the event of a design basis ashfall.Aging Management Review Results Page 3.5-74 January 2010 Aging Management Review Results Page 3.5-74 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Mariagement Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-48 Group 6: earthen water control Loss of material, Inspection of Water-No Not applicable for Columbia. structures -dams, loss of form due to Control Structures or embankments, reservoirs, erosion, FERC/US Army Corps There are no earthen structures channels, canals, and ponds settlement, of Engineers dam associated with the standby sedimentation, inspections and Service Water Pump House or -frost action, waves, maintenance programs -the*Spray Pond. currents, surface \ runoff, seepage Under the current licensing bases the Spray Pond includes a 6-inch sedimentation allowance for water inventory considerations. This allowance includes all forms of accumulation, such as dust, silt, or volcanic ash. The spray ponds are cleaned whenever the sedimentation reaches 3 inches"which ensures adequate water supply even in the event of a design basis ashfall. Aging Management Review Results Page 3.5-74 January 2010 * * .' 0 0 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Further Item Component/Commodity Aging Effectl Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-49 Support members; welds; Loss of material/ Water Chemistry and No Consistent with NUREG-1 801.bolted connections; support general, pitting, ISI(IWF) anchorage to building structure and crevice The listed structural corrosion components exposed to treated water are managed by the Inservice Inspection (ISI)Program -IWF and the BWR Water Chemistry Program.Non ASME structural components exposed to treated water are managed by the Structures Monitoring Program.3.5.1-50 Groups B2, and B4: galvanized Loss of material Structures Monitoring No Consistent with NUREG-1 801.steel, aluminum, stainless steel due to pitting and Programsupport members; welds; crevice corrosion The listed structural bolted connections; support components are managed by anchorage to building structure the Structures Monitoring Program.Aging Management Review Results Page 3.5-75 January 2010* *

• Columbia Generating Station . License Renewal Application. , Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity

-Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-49 Support members; welds; Loss of material! Water Chemistry and No Consistent with NUREG-1801. bolted connections; support general, pitting, ISI(IWF) anchorage to building structure and crevice The listed structural corrosion components exposed to treated ,/ water are managed by the Inservice Inspection (lSI) -Program -IWF and the BWR Water Chemistry Program. Non ASME structural components exposed to treated water are managed by the Structures Monitoring Program. 3.5.1-50 Groups B2, and 84: galvanized Loss of material Structures Monitoring No Consistent with NUREG-1801. steel, aluminum, stainless steel due to pitting and Program support members; welds; crevice corrosion The listed structural bolted connections; support components are managed by anchorage to building structure the Structures Monitoring Program. Aging Mariagement Review Results Page 3.5-75 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect/ Aging Management Evaluation Discussion Number Component/Commodity Mechanism Programs Recommended 3.5.1-51 Group B1.1: high strength low- Cracking due to Bolting Integrity No Three parameters are required alloy bolts stress corrosion for stress corrosion cracking cracking; loss of (SCC) to occur: (1) a corrosive material due to environment, (2) a susceptible general corrosion material, and (3) tensile stresses greater than or equal to the yield strength of the material.Corrosive environments containing sodium hydroxide, seawater, nitrate solutions, sulfuric acids, or aggressive groundwater (chlorides > 500 ppm, sulfates > 1,500 ppm) are not present at Columbia. The internal environment of in-scope structures does not contain aggressive chemicals or contaminants under normal operating conditions. Therefore, the environmental conditions necessary for SCC to occur do not exist.Review of plant-specific. operating experience identified no occurrences of SCC on high strength structural bolting.Aging Management Review Results Page 3.5-76 January2010 Aging Management Review Results Page 3.5-76 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-51 Group B1.1: high strength low-Cracking due to Bolting Integrity No Three parameters are required alloy bolts stress corrosion for stress corrosion cracking cracking; loss of (SCC) to occur: (1) a corrosive material due to environment, (2) a susceptible general corrosion material, and (3) tensile stresses greater than or equal to the yield strength of the material. Corrosive environments containing sodium hydroxide, seawater, nitrate solutions, sulfuric acids, or aggressive groundwater (chlorides> 500 ppm, sulfates> 1,500 ppm) are . not present at Columbia. The internal environment of in-scope structures does not contain aggressive chemicals or contaminants under normal operating conditions. Therefore, the environmental conditions necessary for SCC to occur do not exist. Review of plant-specific operating experience identified no occurrences of SCC on high strength structural bolting. Aging Management Review Results Page 3.5-76 January 2010 * *

• 0 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 J Further Item Aging Effect/ Aging Management Evaluation Discussion Number Component/Commodity Mechanism Programs Ecommended Recommended 3.5.1-52 Groups B2, and B4: sliding [Loss of mechanical

[Structures Monitoring )-.No Aging degradations of supports support bearings and sliding function due to Program designed with or without sliding support surfaces corrosion, connections are managed by distortion, dirt, the Structures Monitoring overload, fatigue Program.due to vibratory and cyclic thermal The inspection criteria for loads supports within the programs effectively envelope misalignment and accumulation of debris.3.5.1-53 Groups B1.1, B1.2, and B1.3: Loss of material ISI (IWF) No Consistent with NUREG-1801.support members: welds; due to general and bolted connections; support pitting corrosion The listed structural anchorage to building structure components are managed by the Inservice Inspection (ISI)Program -IWF.AgngMnaemn RviwReulsPae .-7 Jnar 21 Aging Management Review Results Page 3.5-77 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended Groups B2, and B4: sliding Loss of mechanical Structures Monitoring ) No Aging degradations of supports support bearings and sliding function due to Program designed with Oi without sliding support surfaces corrosion, connections are managed by distortion, dirt, the Structures Monitoring overload, fatig ue Program. due to vibratory and cyclic thermal The inspection criteria for loads supports within the programs -effectively envelope misalignment and accumulation of debris. 3.5.1-53 Groups B1.1, B1.2, and B1.3: Loss of material lSI (lWF) No Consistent with NUREG-1801.

support members: welds; due to general and bolted connections; support pitting corrosion The listed structural anchorage to building structure components are managed by the Inservice Inspection (lSI) Program -IWF. Aging Management Review Results Page 3.5-77 January 2010 Columbia Generating Station* License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 1 ] Further I Item Aging Effect/ Aging Management Fute Number Component/Commodity Mechanism Programs Evaluation Discussion Recommended 3.5.1-54 Groups B1.1, B1.2, and B1.3: Loss of mechanical ISI (IWF) No Loss of mechanical function Constant and variable load function due to due to the listed mechanisms is spring hangers; guides; stops; corrosion, not an aging effect identified in distortion, dirt, the Structural Tools or atoverload, fatigue Columbia. Proper design due to vibratory prevents distortion, overload, and cyclic thermal and fatigue due to vibratory and loads cyclic thermal loads.However, aging degradations on Groups B1.1, B1.2, and B1.3 constant and variable load spring hangers; guides; stops are managed by the Inservice Inspection (ISI) Program -IWF.The inspection criteria for supports within the programs effectively envelope misalignment and accumulation of debris.3.5.1-55 PWR Only Aging Management Review Results Page 3.5-78 January 2010 Aging Management Review Results Page 3.5-78 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 Item Aging Effect/ Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-54 Groups 81.1, 81.2, and 81.3: Loss of mechanical lSI (IWF) No Loss of mechanical function Constant and variable load function due to due to the listed mechanisms is spring hangers; guides; stops; corrosion, not an aging effect identified in distortion, dirt, the Structural Tools or at overload, fatigue Columbia. Proper design due to vibratory -prevents distortion, overload, and cyclic thermal and fatigue due to vibratory and loads cyclic thermal loads. However, aging degradations on Groups 81.1, 81.2, and 81.3 constantand variable load spring hangers; guides; stops are managed by the Inservice Inspection (lSI) Program -IWF. The inspection criteria for supports within the programs effectively envelope misalignment and accumulation of debris. 3.5.1-55 PWR Only Aging Management Review Results Page 3.5-78 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.1 Summary ,of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801 1 Further Item ComponentCommodity Aging Effect/ Aging Management Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-56 Groups B1.1, B1.2, and B1.3: Loss of mechanical ISI (IWF) No Aging degradations of Groups Sliding surfaces function due to B1.1, B61.2, and B1.3 supports corrosion, designed with or without sliding distortion, dirt, connections are managed byoverload, fatigue -the Inservice Inspection (ISI)due to vibratory Program -IWF.and cyclic thermal loads The inspection criteria for supports within the programs effectively envelope misalignment and accumulation of debris.3.5.1-57 Groups B13.1, 81.2, and B1.3: Reduction or loss ISI (IWF) No Not applicable for Columbia.Vibration isolation elements of isolation function/radiation There were no Groups B1.1, hardening, 81.2, and. 81.3 vibration temperature, isolation elements identified at humidity, sustained Columbia.vibratory loading3.5.1-58 Galvanized steel and aluminum None None NA- NoAEM Consistent with NUREG-1801.

support members; welds; or AMP bolted connections; support anchorage to building structure exposed to air -indoor uncontrolled 3.5.1-59 Stainless steel support None None NA -No AEM Consistent with NUREG-1801. members; welds; bolted or AMP connections; support anchorage to building structure Aging Management Review Results Page 3.5-79 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.1 Summary ,of Aging Management Programs for Structures and Component Supports Evaluated in Chapters II and III of NUREG-1801

-Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.5.1-56 Groups 81.1,81.2, and 81.3: Loss of mechanical lSI (IWF) No Aging degradations of Groups Sliding surfaces function due to B1.1, Bf2,and 81.3 supports corrosion, designed with or without sliding distortion, dirt, connections are managed by overload, fatigue the Inservice Inspection (lSI) due to vibratory Program -IWF. and cyClic thermal . loads The inspection criteria for supports within the programs effectively envelope misalignment and accumulation of debris. 3.5.1-57 Groups 81.1,81.2, and 81.3: Reduction or loss .ISI (IWF) No Not applicable for Columbia. Vibration isolation elements of isolation function/radiation There were no Groups 81.1, hardening, / 81.2, and 81.3 vibration temperature, isolation elements identified at humidity, sustained Columbia. vibratory loading 3.5.1-58 Galvanized steel and aluminum None None NA-NoAEM Consistent with NUREG-1801. support members; welds; orAMP bolted connections; support anchorage to building structure exposed to air -indoor uncontrolled 3.5.1-59 Stainless steel support None None NA-NoAEM Consistent with NUREG-1801. members; welds; bolted orAMP connections; support anchorage to building structure Aging Management Review Results Page 3.5-79 -January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment NUREG-Row Component! Intended Aging Effect Aging Management 1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Inservice Inspection III.B1.2-10 3.5.1-53 A Downome BraingProgram-IWF Downcomer Bracing SSR Carbon Steel Air -indoor Loss of material and Supports Structures Monitoring III.A4-5 3.5.1-25 A Program Inservice Inspection Downcomer Bracing Program-IWF C 2 SSR Carbon Steel Treated water Loss of material 111.B1.1-11 3.5.1-49 and Supports BWR Water Chemistry 0509 Program Downcomer Jet HELB, SSR Carbon Steel Air- indoor Loss of material Structures Monitoring Deflectors Program II1.A4-5 3.5.1-25 A SSR Galvanized Air- indoor None None 111.11.1-7 3.5.1-58 C Decking Steel Drywell Floor DF, EN, Inservice Inspection 5 Peripheral Seal EXP, SPB, Stainless Steel Air -indoor None Program-IWE N/A N/A 0501, Assembly SSR Appendix J Program 0502 Drywell Floor Structures Monitoring 6 Peripheral Seal Jet HELB, SSR Carbon Steel Air -indoor Loss of material Program II1.A4-5 3.5.1-25 A Deflectors Inservice Inspection 7 Drywell Floor Shear SSR Carbon Steel Air -indoor Loss of material Program-IWE 11.B2.1-1 3.5.1-05 A Lugs 0502 Appendix J Program I Aging Management Review Results Page 3.5-80 January 2010 Aging Management Review Results Page 3.5-80 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Inservice Inspection III.B1.2-10 3.5.1-53 A , Program-IWF 1 Downcomer Bracing SSR Carbon Steel Air -indoor Loss of material and Supports Structures Monitoring III.A4-5 3.5.1-25 A Program Inservice Inspection Q Downcomer Bracing \ Program-IWF C 2 SSR Carbon Steel Treated water Loss of material III.B1.1-11 3.5.1-49 Supports BWR Water Chemistry 0509 Program 3 Downcomer Jet HELB, SSR Carbon Steel Air -indoor Loss of material Structures Monitoring III.A4-5 3.5.1-25 A Deflectors Program 4 Drywell Floor SSR Galvanized Air -indoor None None III.B1.1-7 3.5.1-58 C Decking Steel Drywell Floor OF, EN, Inservice Inspection I 5 Peripheral Seal EXP, SPB, Stainless Steel Air -indoor None Program-IWE N/A N/A 0501, fA,ssembly SSR Appendix J Program 0502 Drywell Floor Structures Monitoring 6 Peripheral Seal Jet HELB, SSR Carbon Steel Air -indoor Loss of material Program III.A4-5 3.5.1-25 A Deflectors Inservice Inspection 7 Drywell Floor Shear . SSR Carbon Steel Air -indoor Loss of material Program-IWE II.B2.1-1 3.5.1-05 A Lugs 0502 Appendix J Program Aging Management Review Results Page 3.5-80 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment NUREG-Aging Effect i n UREN-Row Component

/ Intended Aging Management 1801 Table No No. Commodity Function 1 Requiring Program Volume 2 Item Management Item Drywell Head I I Inservice Inspection I.including d EN, SPB, Carbon Steel! Air- indoor Loss of material Program-IWE A 3 8 head flanges, lifting SSR.2.1-1 3.5.1-05 0502 lugs, support feet, Appendix J Program and double o-rings)Structures Monitoring Program 9 Drywell Sump Liners SSR Stainless Steel Raw water Loss of material N/A N/A BWR Water Chemistry Program Equipment Hatch Inservice Inspection and CRD Removal Program-IWE 10 Hatch (including EN, SPB, Carbon Steel/ Air -indoor Loss of material Appendix J Program II.B4-5 3.5.1-17 A flange gaskets and SSR Elastomer I1.B4-6 3.5.1-18 0506 mlosure Plant Technical Specification Penetrations Inservice Inspection (Mechanical and EN, SPB, Carbon Steel/ AProgram-IWE II.B4-1 3.5.1 A 11 Electrical, primary SSR Elastomer -indoor Lossofmaterial -18 containmentry) Appendix J Program boundary)Penetrations Inservice Inspection (Mechanical and EN, SPB, Program-IWE 1 12 Electrical, primary S StainlessSteel Air-Rindoor None N/A N/A 0501, SSR 0505 rontainment Appendix J Program boundary) I IIIIII Aging Management Review Results Page 3.5-81 January 2010 Aging Management Review Results Page 3.5-81 January 2010 e. e

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment

\ Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Drywell Head Inservice Inspection (including drywe!! EN, SPB, Carbon Steeii Program-IWE 1\ 8 head flanges, lifting Air -indoor Loss of material II.B2.1-1 3.5.1-05 r\ SSR Elastomer 0502 lugs, support feet, Appendix J Program double o-rings) -Structures Monitoring Program J 9 Drywell Sump Liners SSR Stainless Steel Raw water Loss of material N/A N/A 0508 BWR Water Chemistry Program Equipment Hatch .Inservice Inspection and CRD Removal . Program-IWE 10 Hatch (including EN, SPB, Carbon Steell Air-indoor Loss of material Appendix J Program II.B4-5 3.5.1-17 A flange gaskets and SSR Elastomer II.B4-6 3.5.1-18 0506 Plant Technical mechanisms) Specification Penetrations Inservice Inspection (Mechanical and 11 Electrical,* primary EN, SPB, Carbon Steell Air-indoor Loss of material Program-IWE II.B4-1 3.5.1-18 A SSR Elastomer 0505 containment Appendix J Program boundaryl Penetrations Inservice Inspection (Mechanical and I 12 Electrical, primary EN, SPB, Stainless Steel Air-indoor None Program-IWE N/A N/A 0501, SSR Fontainment Appendix J Program 0505 boundary) Aging Management Review Results Page 3.5-81 January 201 0 Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment dAging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table 1 Notes NO. Commodity Function' Program Volume 2 Item Management Item Personnel Access Inservice Inspection Lock (including Program-IWE 13 gaskets, hatch EN, SPB, Carbon Steel/ Air -indoor Loss of material Appendix J Program II.B4-5 3.5.1-17 A locks, hinges and SSR Elastomer I1.B4-6 3.5.1-18 0506 closure Plant Technical mechanisms) Specification Pipe Whip 1 PipecWip EN PW Structures Monitoring 14 Protection Support SSR Carbon Steel Air -indoor Loss of material Program III.A4-5 3.5.1-25 A RingsSRPrgaInservice Inspection Primary EN, SPB, Porm4EA 15 Carbon Steel Air- indoor Loss of material

• Program-IWE I1.B2.1-1 3.5.1-05 0 Containment Vessel SRE, SSR 0502 Appendix J Program Primary 16 Containment Vessel SPB, SSR Carbon Steel Concrete None None VII.J-21 3.3.1-96 C Inner and Outer Support Skirts I Inservice Inspection Program-IWF C 17 Quencher Support SSR Carbon Steel Treated water Loss of material I1.B1.1-11 3.5.1-49 0 BWR Water Chemistry Program 18Radial BeamStutrsMnoig 1 Framing System EN, SSR Carbon Steel Air -indoor Loss of material Structures Monitoring .A4-5 3.5.1-25 A 19 a g SyI.A4-5 3.5.1-259 19 Reactor Vessel EN, PR, Stainless Steel/ Air-indoor None None III.B1.1-9 3.5.1-59 C Thermal Insulation SSR Aluminum A on.B1.1-6 3.5.1-58 C C 20 Refueling Bellows EXP, FLB, S A Structures Monitoring III.B1.1-9 3.5.1-59 0501 Seals SSR Stainless Steel Air -indoor None Program 0503 Agin MaageentRevew esuts age3.582 anury 0103 Aging Management Review Results Page 3.5-82 January 2010 Columbia Generating Station -License Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Personnel Access Inservice Inspection Lock (including Program-IWE 13 gaskets, Hatch EN, SPB, Carbon Steell Air -indoor Loss of material Appendix J Program II.B4-5 3.5.1-17 A locks, hinges and SSR Elastomer II.B4-6 3.5.1-18 0506 dosure Plant Technical mechanisms) , Specification Pipe Whip EN,PW, Structures Monitoring 14 Protection Support SSR Carbon Steel Air -indoor Loss of material -Program III.A4-5 3.5.1-25 A Rings Inservice Inspection 15 Primary EN, SPB, Carbon Steel Air-indoor Loss of material Program -IWE II.B2.1-1 3.5.1-05 A Containment Vessel SRE, SSR 0502 Appendix J Program Primary 16 Containment Vessel SPB, SSR Carbon Steel Concrete None None VII.J-21 3.3.1-96 C Inner and Outer Support Skirts Inservice Inspection Program-IWF C 17 Quencher Support SSR Carbon Steel Treated water Loss of material III.B1.1-11 3.5.1-49 0509 BWR Water Chemistry Program 18 Radial Beam EN, SSR Carbon Steel -Air -indoor Loss of material Structures Monitoring III.A4-5 3.5.1-25 A Framing System Program 1_9 Reactor Vessel EN, PR, Stainless Steell Air -indoor None None III.B1.1-9 3.5.1-59 C -Thermal Insulation SSR Aluminum III.B1.1-6 3.5.1-58 C Refueling Bellows EXP, FLB, Structures Monitoring C 20 Stainless Steel Air -indoor None 111.81.1-9 3.5.1-59 0501 Seals SSR Program 0503 Aging Management Review Results Page 3.5-82 -January 2010 * *
• Columbia Generating Station License Renewal Application Technical Information

-* Table 3.5.2-1 Aging Management Review Results -Primary Containment Aging Effect NUREG-Row ComponentE Intended M Aging Management 1801 TableI Notes No. Commodity Funtin aterial Environment Requiring Program Volume 2 Item No.___ Commodity___ _ Fn n Management Item 21 Refueling Bulkhead ,FLB, SSR Carbon Steel Air -indoor Loss of material Structures Monitoring II.A4-5 3.5.1-25 A Seal Plate Program Sacrificial Shield Wall Inner and Outer Skins CabonStel Arruindorsossoftateia 22 (including EN, SHD, Carbon Steel Air -indoor Loss of material uctures Monitoring II.A4-5 3.5.1-25 A removable plugs, SNS, SSR Program shield doors, and removable panels)Sand Filled Pocket Inservice Inspection A 23 Area (including DF, FLB, Carbon Steel Air -indoor Loss of material Program-IWE I1.B2.1-1 3.5.1-05 0502 losure ring) Appendix J Program 0504 Inservice Inspection III.B.1.3-10 3.5.1-53 A Program-IWF 24 Stabilizer Truss SSR Carbon Steel Air -indoor Loss of material Structures Monitoring II1.A4-5 3.5.1-25 A Program Structural Steel: Beams, Columns, EN, SNS, CarbStructures Monitoring 25Plates, and Trusses SRPrga (includeswld andTrse SSR Cron Steel Air -indoor Loss of material StutreMonitring ll.A4-5 3.5.1-25 A (includes welds and bolted connections) Structural Steel: Beams, Columns, EN, SNS, Galvanized 26 Plates, and Trusses SSR Steel- indoor None None III.B1.1-7 3.5.1-58 C (includes welds and bolted connections) Aging Management REiview Results Page 3.5-83 January 2010-. *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item 21 Refueling Bulkhead 'FLB,SSR Carbon Steel Air -indoor Loss of material Structures Monitoring III.A4-5 3.5.1-25 A Plate Program .

Shield and .. Outer Skins EN, SHO, Structures Monitoring 22 (including Carbon Steel Air -indoor Loss of material III.A4-5 3.5.1-25 A removable plugs, SNS,SSR Program shield doors, and , removable panels) Sand Filled Pocket Inservice Inspection A 23 Area (including OF, FLB, Carbon Steei Air -indoor Loss of material Program-IWE II.B2.1-1 3.5.1-05 0502 SSR ¢Iosure ring) Appendix J Program 0504 -Inservice Inspection III.B.1.3-10 3.5.1-53 A Truss Program-IWF 24 SSR Carbon Steel Air -indoor Loss of material Structures Monitoring III.A4-5 3.5.1-25 A Program Structural Steel: Beams, Columns, EN, SNS, Structures Monitoring 25 Plates, and Trusses Carbon Steel Air -indoor Loss of material III.A4-5 3.5.1-25 A (includes welds and SSR . Program bolted connections) Structural Steel: Beams, Columns, EN, SNS, Galvanized 26 Plates, and Trusses Air -indoor None None III.B1.1-7 3.5.1-58 C (includes welds and SSR Steel bolted connections) . Aging Management Review Results Page 3.5-83 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment TAging Effect NUREG-Row Component / Intended Material Environment Requiring Aging Management 1801 Table I Notes No. Commodity Function' M Program Volume 2 Item ManagmentItem Suppression Chamber Inservice Inspection (including vertical EN, HS, Program-IWE A 27 stiffeners and SPB, SRE, Carbon Steel Air -indoor Loss of material r1. B2.1-1 3.5.1-05 0502horizontal stiffener SSR Appendix J Program rings)Suppression Inservice Inspection Chamber Program-IWE (including vertical EN, HS, A 28 stiffeners and SPB, SRE, Carbon Steel Treated water Loss of material Appendix J Program II.B2.1-1 3.5.1-05 0502 horizontal stiffener SSRBWR Water Chemistry0507 rings) Program Suppression EN, HS, 29 Chamber SPB SRE, Carbon Steel Concrete None None VII.J-21 3.3.1-96 C (bottom ellipsoidal SPBR head)Suppression Inservice Inspection Chamber Access Program-IWE Hatch (including EN, SPB, Carbon Steel/ Air- indoor Loss of material Appendix J Program II.B4-5 3.5.1-17 A flange gaskets and SSR Elastomer II.B4-6 3.5.1-18 0506 closure Plant Technical mechanisms) Specification 31 Concrete Under the Air- indoor None Structures Monitoring N/A N/A I 31 Ellipsoidal Head SSR Concrete Program N 0501 EN, FLB, 32 Drywell Floor MB, SSR, Concrete Air -indoor None Structures Monitoring N/A N/A 0501 1 _ SRE I I IProgram Aging Management Review Results Page 3.5-84 January 2010 Aging Management Review Results Page 3.5-84 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Chamber EN, HS, Inservice Inspection 27 (including vertical SPB, SRE, Carbon Steel Air-indoor Loss of material Program-IWE II.B2.1-1 3.5.1,*05 A and SSR 0502 horizontal stiffener Appendix J Program rings) , Suppression Inservice Inspection Chamber Program-IWE (including vertical EN, HS, A 28 SPB, SRE, Carbon Steel Treated water Loss of material Appendix J Program II.B2.1-1 3.5.1-05 0502 stiffeners and SSR 0507 horizontal stiffener BWR Water Chemistry rings) Program EN, HS, 29 Chamber SPB, SRE, Carbon Steel Concrete None None VILJ-21 3.3.1-96 C (bottom ellipsoidal head) . SSR Inservice Inspection Chamber Access Program-IWE 30 Hatch (including EN, SPB, Carbon Steel! Air -indoor Loss of material Appendix J Program II.B4-5 3.5.1-17 A gaskets and SSR Elastomer II.B4-6 3.5.1-18 0506 Plant Technical mechanisms) , Specification -31 Concrete Under the SSR Concrete Air -indoor None Structures Monitoring N/A N/A I Ellipsoidal Head Program -0501 EN, FLB, Structures Monitoring I 32 Drywell Floor MB, SSR, Concrete Air -indoor None N/A N/A SRE Program 0501 Aging Management Review Results Page 3.5-84 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment NUREG-Row Component Intended Aging Effect Aging Management 1801 Table 1 No. Commodity Function Material Environment Requiring Program Volume 2 Item Notes Management Prgrmtolme2 tm Item 3 Drywell Floor J Cne 1 1 None Structures Monitoring N/A N/AI 3 Support Columns SS Concrete Air- indoor N Program 0501 34Drywell Floor Structures Monitoring N/A N/A I 34 rSweporFloorumn SSR Concrete Treated water None Program 0501___Support Columns Porm00 DF, FLB Structures Monitoring N/A N/A 1 35RDrywell Sumps DL Concrete Air -indoor None Program N/AN/A 0501 36 Floor Trench DF, SSR Concrete Air -indoor None Structures Monitoring N/A N/A I Program 0501 37Reactor Pedestal SSR Concrete Air -indoor None Program 00 38 Reactor Pedestal SSR Concrete Tireatendowatr None Structures Monitoring N/A N/AI Program 00 Structures Monitoring 1/ /38 Reactor Pedestal SSR Concrete Treated water None Program NA/A 0501 Reinforced Concrete Lining Inside the Structures Monitoring 1 39 Bottom Head of the SSR Concrete Treated water None S ronrin N/A N/A Primary Program 0501 Containment Vessel acrificial Shield EN, MB, Structures Monitoring I 40 all SHD, SNS, Concrete Air -indoor None Program N/A N/A 0501 41 S tMSSR Sand Filled Pocket DF, FLB, Concrete Air- indoor Structures Monitoring 050 4 Area SSR (w/ Sand) Program N050 Refer to Table 2.0-1 for intended function descriptions.

Aging Management Review Results.Page 3.5-85 January 2010* * '. Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-1 Aging Management Review Results -Primary Containment Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Itein Notes Management Item 33 Orywell Floor SSR Concrete Air -indoor None Structures Monitoring N/A N/A I Support Coiumns Program 0501 34 Orywell Floor SSR Concrete Treated water None Structures Monitoring N/A N/A I Support Columns Program 0501 35 Orywell Sumps OF, FLB, Concrete Air -indoor None Structures Monitoring N/A N/A I SSR Program 0501 36 Floor Trench OF, SSR Concrete Air -indoor None Structures Monitoring N/A N/A I Program 0501 37 Reactor Pedestal SSR Concrete Air -indoor None Structures Monitoring N/A N/A I Program 0501 38 Reactor Pedestal SSR Concrete Treated water None Structures Monitoring N/A N/A I Program 0501 ReinfOrced Concrete Lining Inside the Structures Monitoring I 39 Bottom Head of the SSR Concrete Treated water None N/A N/A Primary Program 0501 iContainment Vessel iSacrificial Shield EN,MB, Structures Monitoring I 40 SHO, SNS, Concrete Air -indoor None Program N/A N/A 0501 SSR iSand Filled Pocket OF, FLB, Concrete Structures Monitoring I 41 Air -indoor None ' N/A N/A 0501 fA,rea SSR (wi Sand) Program 0504 1 Refer to Table 2.0-1 for intended function descriptions. -Aging Management Review Results Page 3.5-85 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-2 Aging Management Review Results -Reactor Building NUREG-Aging Effect nURE1-Row Component I Intended Material Environment Requiring Aging Management 1801 Table 1 Notes No. Commodity Function 1 M Program Volume 2 Item ManagmentItem 1 Blowout Panels SPB, SSR Carbon Steel Air -indoor Loss of material Structures Monitoring III.A2-12 3.5.1-25 A Program 2 Blowout Panels SPB, SSR Carbon Steel Air -outdoor Loss of material Structures Monitoring III.A2-12 3.5.1-25 A Program Cranes, including Material Handling 3 Bridge, Trolley, SNS, SSR Carbon Steel Air- indoor Loss of material System Inspection VII.B-3 3.3.1-73 A Rails, and Girders Program Elevated Release Structures Monitoring .A2-12 3.5.1-25 A 4 Stack RP, SSR Carbon Steel Air -outdoor Loss of material Programo ing C 5 Lead Shield Panels SHD, SNS Stainless Steel Air -indoor None None II1.B5-5 3.5.1-59 0 0516 6 Metal Siding EN, SPB, Galvanized Air -indoor None None I1.B5-3 3.5.1-58 C SSR Steel 7 EN, SPB, alvanized .Structures Monitoring lIB-Metal Siding EN, SPB, Galvanized Air -outdoor Loss of material reog r.2-7 .5.1-50 C SSR Steel Program II1.B5-2 3.5.1-58 C Aluminum/ 0511 8 New Fuel Racks EN, SSR Stainless Steel Air -indoor None None fasteners 11.B5-5 3.5.1-59 A 0511 Reactor Well and 9 Dryer-Separator SSR Aluminum Air -indoor None None I1l.B5-2 3.5.1-58 C Storage Pool Gates II Reactor Well and 10 Dryer-Separator SSR Stainless Steel Air- indoor None None III.B5-5 3.5.1-59 C_ Storage Pool Liners _ I I Aging Management Review Results Page 3.5-86 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-2 Aging Management Review Results -Reactor Building Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 . Material Environment Requiring Program Volume 2 Item Notes Management Item 1 Blowout Panels SPB, SSR Carbon Steel Air-indoor Loss of material Structures Monitoring III.A2-12 3.5.1-25 A Program 2 Blowout Panels SPB, SSR Carbon Steel Air -outdoor Loss of material Structures Monitoring III.A2-12 3.5.1-25 A Program Cranes, including Material Handling 3 Bridge, Trolley, SNS, SSR Carbon Steel Air -indoor Loss of material System Inspection VII. B-3 3.3.1-73 A Rails, and Girders Program 4 Elevated Release RP, SSR Carbon Steel Air -outdoor Loss of material Structures Monitoring III.A2-12 3.5.1-25 A Stack Program 5 Lead Shield Panels SHD, SNS Stainless Steel Air -indoor None None III.B5-5 3.5.1-59 C 0516 6 Metal Siding EN, SPB, Galvanized Air -indoor None None II I. B5-3 3.5.1-58 C SSR Steel 7 Metal Siding EN, SPB, Galvanized Air -outdoor Loss of material Structures Monitoring III.B2-7 3.5.1-50 C SSR Steel Program II I. B5-2 3.5.1-58 C Aluminum/ 0511 8 New Fuel Racks EN, SSR Stainless Steel Air -indoor None None fasteners II I. B5-5 3.5.1-59 A 0511 Reactor Well and 9 Dryer-Separator SSR All,Iminum Air -indoor None None II I. B5-2 3.5.1-58 C Storage Pool Gates Reactor Well and 10 Dryer-Separator SSR Stainless Steel Air-indoor None None III.B5-5 3.5.1-59 C . Storage Pool Liners Aging Management Review Results Page 3.5-86 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-2 Aging Management Review Results -Reactor Building Aging Effect NUREG-Row Component/

Intended *Aging Management 1801 Table 1 oe No. Commodity Function 1 Material Environment Requiring PV Management Program olume 2 Item__ _*_ _ _ _ _ __ _ _I Item _ __T -_ _11 -Roof Deckinq EN, SPB, Galvanized Air- indoor None None III1.B5-3 3.5.1-58 C SSR Steel 12 Roof Masts SRE Galvanized Air -outdoor Loss of material Structures Monitoring I1.B2-7 3.5.1-50 C Steel Program Secondary Containment Air 13 Locks (includes MB, SPB, Carbon Steel Air -indoor Loss of material Structures Monitoring II.A2-12 3.5.1-25 A railroad bay and SSR Program double air lock.doors)Secondary Containment Air 14 Locks (includes MB, SPB, Carbon Steel Air -outdoor Loss of material Structures Monitoring II.A2-12 3.5.1-25 A railroad bay and SSR Program double air lock doors)15 Spent Fuel Pool SSR Aluminum Air -indoor None None 111.15-2 3.5.1-58 C Gates Gate"BW'3..1-C .16 Spent Fuel Pool SSR Aluminum Treated water Loss of materia BWR Water Chemistry VIrA4-5 3.3.1- 0513 1Gates .1 ,Program 1 24 01 Aging Management Review Results Page 3.5-87 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-2 Aging Management Review Results -Reactor Building -NUREG-Aging Eff,ect Row Component I Intended Material Environment Requiring Aging Management 1801 Table 1 Notes No. Commodity Function 1 Program Volume 2 Item Management Item 11 -Roof Decking EN, SPB, Galvanized Air -indoor None None III.B5-3 3.5.1-58 C SSR Steel 12 Roof Masts SRE Galvanized Air -outdoor Loss of material Structures Monitoring III.B2-7 3.5.1-50 C Steel Program Secondary , Containment Air 13 Locks (includes MB, SPB, Carbon Steel Air -indoor Loss of material Structures Monitoring III.A2-12 3.5.1-25 A railroad bay and SSR , Program, double air lock, doors) Secondary Containment Air 14 Locks (includes MB, SPB, Carbon Steel Air -outdoor Loss of material Structures Monitoring III.A2-12 3.5.1-25 A railroad bay and SSR Program double air lock doors) 15 Spent Fuel Pool SSR Aluminum Air -indoor None None II I. B5-2 3.5.1-58 C Gates Spent Fuel Pool .' '," BWR Water Chemistry 3.3.1-C 16 SSR Aluminum Treated water Loss of material VII.A4-5 0513 Gates Program 24 0514 Aging Management Review Results Page 3.5-87 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-2 Aging Management Review Results -Reactor Building i Ec NUREG-Row ComponentMaterial Environment Requiring Aging Management 1801 Table 1 Notes No.. Commodity Function' Manlgvien RProgram Volume 2 Item I Management Item BWR Water Chemistry Program Spent Fuel Pool Water 17Spent Fuel Pool SSR Stainless Steel Treated water Loss of material Monitoring per Tech IILA5-13 3.5.1-46 A Liner Spec 0512Monitoring of leakage from the leak chase channels 18 Spent Fuel Storage SSR Stainless Steel Treated water Loss of material BWR Water Chemistry VII.A4-11 3.3.1- C Racks Program 24 0514 Structural Steel: Beams, Columns, Structures Monitoring 19 Plates, and Trusses EN, SSR Carbon Steel Air -indoor Loss of material PrograIIm.A2-12 3.5.1-25 A (includes welds and Program bolted connections)

Structural Steel: Beams, Columns, Galvanized 20 Plates, and Trusses EN, SSR Steel Air- indoor None None I1.B5-3 3.5.1-58 C (includes welds and bolted connections) 21 Sump Liners SNS Stainless Steel Air -indoor None None III.B5-5 3.5.1-59 C 22 Sump Liners SNS Stainless Steel Raw water Loss of material Structures Monitoring VII.C3-7 3.3.1-78 E Program 0515 23 Biological Shield EN, MB Structures Monitoring N/A N/A Wall SHD, SSR Concrete Air -indoor None Program 0501 Aging Management Review Results Page 3.5-88 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-2 Aging Management Review Results -Reactor Building Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No.-Commodity FunCtion 1 Material Environment Requiring Program Volume 2 Item Notes Management Item BWR Water Chemistry Program , / Spent Fuel Pool Water 17 Spent Fuel Pool SSR Stainless Steel Treated water Loss of material Monitoring per Tech IILA5-13 3.5.1-46 A Liner Spec 0512 -Monitoring of leakage from the leak chase channels 18 Spent Fuel Storage SSR Stainless Steel Treated water Loss of material BWR Water Chemistry VII.A4-11 3.3.1-C Racks Program 24 0514 Structural Steel: Beams, Columns, -19 Plates, and Trusses EN, SSR Carbon Steel Air -indoor Loss of material Structures Monitoring III.A2-12 3.5.1-25 A (includes welds and Program bolted connections) Structural Steel: Beams, Columns, Galvanized . 20 Plates, and Trusses EN, SSR Steel Air -indoor None None II I. B5-3 3.5.1-58 C (includes welds and bolted connections) 21 Sump Liners SNS Stainless Steel Air -indoor None None III.B5-5 3.5.1-59 C 22 Sump Liners SNS Stainless Steel Raw water Loss of material Structures Monitoring VII.C3-7 3.3.1-78 E Program 0515 23 Biological Shield EN, MB, Concrete Air -indoor None Structures Monitoring N/A' N/A I Wall SHD, SSR Program 0501 Aging Management Review Results Page 3.5-88 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-2 Aging Management Review Results -Reactor Building Aging Effect NUREG-Row Component!I Intended Aging Management 1801 Table I Notes No. Commodity Funten'ed Material Environment Requiring Program Volume 2 Item Management Item*Elevated Release RP/MonitoringA 24 a RP, SSR Concrete Air -outdoor None N/A N/A Stack Orogram 0501 25 Exterior Walls EN, MB, Concrete Air -indoor None Structures Monitoring N/A N/A (above grade) SSR Program 0501 26 Exterior Walls EN, MB, Concrete Air -outdoor None Structures Monitoring N/A N/A I(above grade)

SSR Program 0501 27 Exterior Walls Structures Monitoring N/A N/A I (below grade) EN, SSR Concrete Soil None Program 0501 28 Foundations EN, EXP, Concrete SoilS None Structures Monitoring N/A N/A I SSR Program 0501EN, HELB, Structures Monitoring 1 29 Main Steam Tunnel MB, PW, Concrete Air -indoor None Program N/A N/A 0501 SHD, SSR New Fuel Storage Structures Monitoring N 30 Vault and Cover EN, SSR Concrete Air -indoor None ProgramN/A N/A 0501 31 Pipe Chase SSR Structures Monitoring NANA 00 31 Pipe Chase EN, SHD, Concrete Air -indoor None r orN/A NA SSR Program 0501 32 Pump Pits SSR Concrete Air -indoor None Structures Monitoring N/A N/A I Program 0501 Refueling pools 33 (spent fuel, reactor EN, SHD, Concrete Air -indoor None Structures Monitoring N/A N/A I well, dryer- SSR Program 0501 separator pools)Aging Management Review Results Page 3.5-89 January 2010 Aging Management Review Results Page 3.5-89 January 2010* Table 3.5.2-2 Row Component I Intended No. Commodity Function 1 24 Elevated Release RP, SSR Stack 25 Exterior Walls EN, MS, (above grade) SSR 26 Exterior Walls EN, MS, (above grade) SSR 27 Exterior Walls EN, SSR (below grade) 28 Foundations EN, EXP, SSR EN, HELS, 29 Main Steam Tunnel MS,PW, SHD, SSR 30 New Fuel Storage EN,SSR Vault and Cover 31 Pipe Chase EN, SHD, SSR 32 Pump Pits SSR Refueling pools 33 (spent fuel, reactor EN, SHD, well, dryer-SSR separator pools) Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Reactor Building Aging Effect NUREG--Aging Management 1801 Table 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Concrete Air -outdoor . None Structures*

Monitoring N/A N/A I Program 0501 Concrete Air-indoor None Structures Monitoring N/A N/A I Program 0501 Concrete Air -outdoor None Structures Monitoring N/A N/A I Program 0501 Concrete Soil None Structures Monitoring N/A N/A I Program 0501 Concrete Soil . None Structures Monitoring N/A N/A I Program 0501 Structures Monitoring I Concrete Air-indoor None N/A N/A Program 0501 Concrete Air -indoor None Structures Monitoring N/A N/A I Program 0501 Concrete Air -indoor None Structures Monitoring N/A N/A I Program 0501 Concrete Air-indoor None Structures Monitoring N/A N/A I Program 0501 Concrete Air -indoor None Structures Monitoring N/A N/A I Program 0501 Page 3.5-89 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-2 Aging Management Review Results -Reactor Building IAging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table I Notes No. Commodity Function Management Program Volume 2 ItemMa eItem EN, FB, Structures Monitoring Reinforced FLB, HELB, Program I 34 Concrete: Walls, MB, SHD, Concrete Air- indoor None N/A N/A 0501 floors, and ceilings SNS, SRE, Fire Protection SSR Program 35 Shield PlugsEN, SHD Structures Monitoring N/A N/A 1 EN SSR Concrete Air -indoor None Program 0501 Concrete Structures Monitoring 1 36 Shield Walls SHD, SNS (solid blocks or Air -indoor None N/A N/A 0501 bricks) Program 0517 37 ~~Structures Monitoring N/ / 51 37 Sumps SNS Concrete Air -indoor None rorN/A N/A Program 0501 Boron Carbide None None N/A N/A J 0510 38 Spent Fuel Rack Neutron Absorbers ABN, SSR Stainless Steel Treated water Loss of material BWR Water Chemistry VII.A4-11 3.3.1-24 C (sheathing) Program 0510 0514 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-90 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-2 Aging Management Review Results -Reactor Building Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item EN, FB, Structures Monitoring Reinforced FLB, HELB, Program I 34 Concrete: Walls, MB, SHO, Concrete Air -indoor None N/A N/A 0501 floors, and ceilings SNS, SRE, Fire Protection SSR Program 35 Shield Plugs EN, SHO, Concrete Air -indoor None Structures Monitoring N/A N/A I SSR Program 0501 Concrete Structures Monitoring I 36 Shield Walls SHO, SNS (solid blocks or Air -indoor None N/A N/A 0501 bricks) Program 0517 37 Sumps SNS* Concrete Air -indoor None Structures Monitoring N/A N/A I Program 0501 Boron Carbide None None N/A N/A J 0510 38 Spent Fuel Rack ABN,SSR Neutron Absorbers Stainless Steel Treated water Loss of material BWR Water Chemistry VII.A4-11 3.3.1-24 C (sheathing) Program 0510 0514 --. 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-90 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-3 Aging Management Review Results --Standby Service Water Pump House 1A and lB and Spray Pond_1A and 1B Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table I Notes No. Commodity Function' Program Volume 2 ItemN. C mdy Fci -Management Item Structures Monitoring Bulkhead Fixed Program -Water E Screens SRE, SSR Stainless Steel Water-flowing Loss of material Control Structures 0518 Inspection Structures Monitoring 2 Bulkhead Fixed SRE, SSR Galvanized Water-flowing Loss of material Programructures III.A6-11 3.5.1-47 W Screen Frames Steel Control Structures 0518 Inspection Structures Monitoring Bulkhead Screen Program -Water EIIA611 3517 GuideS SRE, SSR Carbon Steel Water-flowing Loss of material Control Structures

.0518 GuidesCotoStutrs01 Inspection Inservice Inspection Ill.B1.3-10 3.5.1-53 A Program-IWF Spray pond circular heSpae spond lrt SRE, SSR Carbon Steel Air-outdoor Loss of material Structures Monitoring II1.A6-11 3.5.1-47 EProgram -Water 0518 Control Structures Inspection Inservice Inspection IlI.B1.3-10 3.5.1-53 A Program-IWF Spray pond circular SRE, SSR Carbon Steel Raw water Loss of material Structures Monitoring III.A6-1 1 3.5.1-47 E header supports Program-Wateru0518 ~~Program -Wtr0518 Control Structures _______ ~~~~~Inspection I______________ Aging Management Review Results Page 3.5-91 January 2010 Aging Management Review Results Page 3.5-91 January 2010) * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-3 Aging M'1lnagement Review Results --Standby Service Water Pump House 1Aand 18 and Spray Pond 1A and 18 Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 ---Material Environment Requiring Program Volume 2 Item Notes Management Item Structures Monitoring Bulkhead Fixed -Program -Water E 1 SRE, SSR Stainless Steel Water-flowing Loss of material Control Structures III.A6-11 3.5.1-47 0518 Inspection Structures Monitoring 2 Bulkhead Fixed SRE, SSR Galvanized Water-flowing Loss of material Program -Water III.A6-11 3.5.1-47 E Screen Frames Steel Control Structures 0518 Inspection Structures Monitoring

\ 3 Bulkhead Screen SRE, SSR Carbon Steel Water-flowing Loss of material Program -Water III.A6-11 3.5.1-47 E Guides Control Structures .0518 Inspection Inservice Inspection III.B1.3-10 3.5.1-53 A Program-IWF , 4 Spray pond circular SRE, SSR Carbon Steel Air-outdoor Loss of material Structures Monitoring III.A6-11 3.5.1-47 E header supports" Program -Water 0518 Control Structures Inspection -Inservice Inspection III.B1.3-10 3.5.1-53 A Program-IWF 5 Spray pond circular SRE, SSR Carbon Steel Raw water Loss of material Structures Monitoring III.A6-11 3.5.1-47 E headersuppqrts Program -Water 0518 Control Structures -Inspection Aging Management Review Results Page 3.5-91 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-3 Aging Management Review Results -Standby Service Water Pump House 1A and 1B and Spray Pond 1A and 1B Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table I Notes No. Commodity Function' Management Program Volume 2 Item MaagmetItem Inservice Inspection Program-IWF Spray pond circular Teflon J header supports SRE, SSR (Fluorogold) Air-outdoor Cracking Structures Monitoring N/A N/A 0 Program -Water 0518 Control Structures InspectionStructural Steel: Structures Monitoring Blates, andlTrusses N,SRE, Carbon Steel' Air-indoor Loss of material Pontrogra-ter IIl.A6-11 3.5.1-47 (includes welds and InSpection bolted connections) Inspection Loss of material Structures Monitoring E 8 Barrier Skimmer SRE, SSR Concrete Water-flowing Program -Water II1.A6-5 3.5.1-35 0518 Vall Crcig Control Structures 0519 lCracking Inspection Structures Monitoring 1 9 Foundations EN, SRE, Concrete Soil -None Program -Water N/A N/A 0501, SSR o Control Structures 051,___Inspection Loss of material Structures Monitoring E Pm Intakete WaCW,-floRiProgram -Water 10 Chambers SSR Concrete Water-flowing Cracking Control Structures Il1.A6-5 3.5.1-35 05198 Cracking Inspection 01 Reinforced EN, MB, Structures Monitoring I 11 Concrete: Walls, SNS, SRE, Concrete Air-indoor None Program-Water N/A N/A 0501 loors and ceilings SSR Control Structures 0518__loors,_andceilingsSSR___ Inspection Aging Management Review Results Page 3.5-92 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-3 Aging Management Review Results -Standby Service Water Pump House 1A and 18 and Spray Pond 1A and 18 Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Inservice Inspection Program-IWF 6 Spray pond circular SRE, SSR Teflon Air-outdoor Cracking Structures Monitoring N/A N/A _ J header supports (Fluorogold) Program -Water 0518 Control Inspection Structural Steel: Structures Monitoring Beams, Columns, 7 Plates, and Trusses EN, SRE, Carbon Steel' Air-indoor Loss of material . Program -Water III.A6-11 3.5.1-47 E (includes welds and SSR Control Structures 0518 bolted connections) Inspection Loss of material Structures Monitoring E 8 Barrier Skimmer . SRE, SSR Concrete Water-flowing Program -Water III.A6-5 3.5.1-35 0518 Wall Cracking Control Structures 0519 Inspection Structures Monitoring I 9 Foundations EN, SRE, Concrete Soil Program -Water N/A N/A 0501, SSR Control Structures Inspection 0518 Loss of material Structures Monitoring E 10 . Pump Intake SCW, SRE, Concrete Water-flowing Program -Water III.A6-5 3.5.1-35 0518 Chambers SSR Control Structures Cracking Inspection 0519 Structures Monitoring Reinforced EN, MB, I 11 Concrete: Walls, SNS, SRE, Concrete Air-indoor None Program -Water N/A N/A 0501 Control Structures loors, and ceilings SSR --Inspection 0518 Aging Management Review Results Page 3.5-92 January 2010 * * * , \ Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-3 'Aging Management Review Results -Standby Service Water Pump.House 1A and 1B and Spray Pond 1A and 11B Aging Effect NUREG-Row Component I Intended Material Environment Requiring Aging Management 1801 Table 1 Notes No. Commodity Function' Management Program Volume 2 Item MItem EN, MB, I Structures Monitoring I 12 Roof Slabs SNS, SRE, Concrete Air-outdoor None Program-Water N/A N/A 0501 SSR *Control Structures 0518 Inspection EN, HS, Structures Monitoring I SprayHPondProgram -.Water 0501 13 Spray Pond SCW, SRE, Concrete Raw water None Crol Strutur N/A N/A 051 13Depressed Sump *Control Structures -0518 " SSR Inspection 0520 Structures MonitoringSpa odEN, HS, ConrolgSruc Wtues 05018 14 Spray Pond SCW, SRE, Concrete Raw water None Program-Water N/A N/A 0501 Foundation SRControl Structures 0518 SSR Inspection 0520 EN, HS, Structures Monitoring 1 15 Spray Pond SCW, SRE, Concrete Soil None Programs-Water N/A N/A 0501 Foundation SSR Control Structures 0518 Inspection EN, HS, Structures Monitoring Ipray Pond Sand Program -Water N/A N/A 0501 rap SCW, SRE, Concrete Raw water None Control Structures 0518 SSR Inspection 0520 EN, HS, Structures Monitoring Spray Pond Walls EN, S, Program -Water N I-17 (below grade) SCW, SRE, Concrete Soil None Control Structures N/A N/A 0501 SSR "npeti 0518 Inspectiorn EN, HS, Structures Monitoring I 18 Spray Pond Walls EN, S, Program -Water N/A N/A 0501(above grade) SCW, SRE, Concrete Air-outdoor None Control Structures 0518 SSR ' Inspection Aging Management Review Results Page 3.5-93 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-3 'Aging Management Review Results -Standby Service Water Pump.House 1A and 18 and Spray Pond 1A and 18 Aging Effect , NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity . Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item EN, Structures Monitoring I 12 Roof Slabs SNS, SRE, Concrete Air-outdoor None Program -Water N/A N/A 0501 SSR Control Structures , 0518 -Inspection EN, HS, Structures Monitoring I 13 Spray Pond SCW, SRE, Concrete Raw water None Program -Water N/A N/A 0501 Depressed Sump SSR Control Structures 0518* Inspection 0520 Structures Monitoring

/ I Spray Pond EN, HS, Program -Water 0501 14 SCW, SRE, Concrete Raw water None N/A N/A Foundation SSR . Control Structures 0518 Inspection 0520 Pond EN, HS, I Structures Monitoring I 15 SCW, SRE, Concrete Soil None Program -Water N/A N/A 0501 Foundation Control Structures SSR Inspection 0518 EN, HS, Structures Monitoring I 16 Pond Sand SCW, SRE, Concrete Raw'water None Program -Water N/A N/A 0501 ITrap SSR Control Structures 0518 Inspection 0520 ppray Pond Walls EN, HS, Structures Monitoring , I 17 SCW, SRE, Concrete Soil None Program -Water N/A N/A 0501 (below grade) Control Structures / SSR Inspection 0518 EN, HS, Structures Monitoring I 18 -ppray Pond Walls SCW, SRE, Concrete Air-outdoor _ None Program -Water N/A -. N/A 0501 (above grade) SSR Control Structures 0518 Inspection . Aging Management Review Results Page 3.5-93 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-3 Aging Management Review Results -Standby Service Water Pump House 1A and 1B and Spray Pond 1A and 1B dAging Effect NUREG-Row Component/ I Material Environment Requiring Aging Management 1801 Table I Notes No. Commodity Function1 Matanlagveoment -eurn Program Volume 2. Item Noe Management j Item EN, HS, Loss of material Structures Monitoring E 19 Spray Pond Walls SCW, SRE, Concrete Water-flowing Program -Water Ill.A6-5 3.5.1-35 0518~Control Structures SSR Cracking Cnstrcture 0519___________ Inspection Standby Service Structures Monitoring 20 Water Pump House EN, MB, Concrete Air-outdoor None Program-Water N/A N/A 0501 Exterior Walls SRE, SSR Control Structures (above grade) Inspection Standby Service Structures Monitoring I 21 Water Pump House EN, SRE, Concrete Soil None Program-Water N/A N/A 0501 Exterior Walls SSR Control Structures 0518 (below grade) Inspection Structures Monitoring 22 Sumps SNS Concrete Air-indoor None Program.- Water N/A N/A 0501 Control Structures ______Inspection -Structures Monitoring I 23 rumps SNS Concrete <Raw water None Programu-Water N/A N/A 0501 Control Structures 01 Inspection L 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-94 January 2010 Aging Management Review Results Page 3.5-94 January 2010-Columbia Generating Station Licen*se Renewal Application Technical Information Table 3.5.2-3 Aging Management Review Results -Standby Service Water Pump House 1A and 18 and Spray Pond 1A and 18 Aging Effect NUREG-.. Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1. Material Environment Requiring Program Volume 2 Item Notes Management -Item EN, HS, Loss of material Structures Monitoring._ E 19 Spray Pond Walls SCW, SRE, . Concrete Water-flowing Program -Water III.A6-5 3.5.1-35 0518 Control Structures SSR Cracking Inspection 0519 Service. Structures Monitoring I 20 Pump House EN, MB, Concrete Air-outdoor None Program -Water N/A N/A 0501 Exterior Walls SRE, SSR -Control Structures above grade) Inspection 0518 Service Structures Monitoring I 21 Pump House EN, SRE, Concrete Soil None Program -Water N/A N/A 0501 Exterior Walls SSR Control Structures below grade) Inspection 0518 . Structures Monitoring I 22 Sumps SNS Concrete Air-indoor None Program-Water N/A N/A 0501 Control Structures Inspection 0518 -. Structures Monitoring I 23 SNS Concrete /' Raw water None Program -Water N/A N/A 0501 Control Structures 0518 Inspection 1 Refer to Table 2.0-1 for intended function descriptions. / Aging Management Review Results Page 3.5-94 January 2010 * *

• 0 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-4 Aging Management Review Results -Circulating Water Pump HouseAging Effect NUREG-1 Material Environment Requiring Aging Management 1801 Volume Table Notes No. Commodity Function Management Program 2 Item Item Structures Monitoring
• ro- ragramWater 1.E Battery Racks SRE Carbon Steel Air-indoor Loss of material Control Structures EI.A6-i1 3.5.1-47 0518 Inspection Structures Monitoring 2 Bulkhead Screen SRE Galvanized Water- Loss of material Program -Water II1.A6-11 3.5.1-47 E Frames Steel flowing Control Structures 0518 Inspection Structures Monitoring 3 Bulkhead Screens SRE Stainless Steel Water- Loss of material Program -Water III.A6-11 3.5.1-47 E flowing Control Structures 0518 Inspection Structures Monitoring 4 Bulkhead Screen ClWater- Program -Water E Guides cSteel Loss of material Control Structures 0518 GudsSRE Carbon Selflowing II1.A6-11 0518-4 Inspection Structures Monitoring 5 Metal Sel Air-outdoor Loss of material Program -Water I III.A6-11 3.5.1-47 0 Siding SRE Control Structures 0518 Inspection 6 Roof Decking SRE Galvanized Air-indoor None None Ill.B5-3 3.5.1-58 C SteelStructural Steel:

Monitoring Beams, Columns, PrograM-WateriE 7 Plates, and Trusses SRE Carbon Steel Air-indoor Loss of material Control Structures II1.A6-11 3.5.1-47 0518 (includes welds and InSpection bolted connections) Inspection Aging Management Review Results Page 3.5-95 January 2010* 3.5.2-4 "-Row Component I Intended No. Commodity Function 1 . 1 Battery Racks SRE 2 Bulkhead Screen SRE Frames 3 Bulkhead Screens SRE Bulkhead Screen 4 SRE Guides 5 Metal Siding SRE 6 Roof Decking SRE Structural Steel: Beams, Columns, 7 Plates, and Trusses SRE (includes welds and bolted connections) Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Circulating Water Pump House Aging Effect Aging Management NUREG-Table 1 Material Environment Requiring Program 1801 Volume Item Notes Management 2 Item Structures Monitoring Carbon Steel Air-indoor Loss of material Program -Water ili.A6-11 3.5.1-47 E Control Structures 0518 Inspection Structures Monitoring Galvanized Water-Loss of material Program -Water III.A6-11 3.5.1-47 E Steel . flowing Control Structures 0518 J Inspection Structures Monitoring Stee Water-Loss of material Program -Water III.A6-11 3.5.1-47 E flowing Control Structures 0518 Inspection Structures Monitoring Carbon Steel Water-Loss of material Program -Water III.A6-11 3.5.1-47 E flowing Control Structures 0518 Inspection Structures Monitoring Galvanized Air-:C)utdoor Loss of material Program -Water "III.A6-11 3.5.1-47 E Steel Control Structures 0518 Inspection Galvanized Air-indoor None None II I. B5-3 3.5.1-58 C Steel Structures Monitoring Carbon Steel Air-indoor Loss of material Program -Water III.A6-11 3.5.1-47 E Control Structures 0518 Inspection Page 3.5-95 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-4 Aging Management Review Results -Circulating Water Pump HouseAging Effect NUREG- Table 1 Row Component Intended Material Aging Management 1801 Volume Item No. Commodity Function' Management Program 2 Item j ~Managements Prga Item Structural Steel: Beams, Columns, Galvanized 8 Plates, and Trusses SRE Steel Air-indoor None None 1.B5-3 3.5.1-58 C (includes welds and bolted connections)

Loss of material Structures Monitoring E Program -Water IlA- ..-5 01 9 Foundation SRE Concrete Water-flowing Controlructes II1.A6-5 3.5.1-35 0518 Cracking Inspection0519 Structures Monitoring I 10 Foundation SRE Concrete Soil None Programu-Water N/A N/A 0501 Control Structures 0518 Inspection Reinforced Structures Monitoring I 11 Concrete: Walls, SRE Concrete Air-indoor None Program -Water N/A N/A 0501 floors, and ceilings Control Structures 0518 Inspection Structures Monitoring III.A6-10 3.5.1-43 A Program -Masonry 12 Malsnry Block FB, SRE Concrete Air-indoor Cracking Wall Inspection Fire Protection II1.A6-10 3.5.1-43 E Program 11 *Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-96 January 2010 Aging Management Review Results Page 3.5-96 January 2010 Columbia Generating Station License Renewal Application Technical Information -Table 3.5.2-4 Aging Management Review Results -Circulating Water Pump House Row Component I Intended Aging Effect Aging Management NUREG-Table 1 No. Commodity Function 1 Material Environment Requiring Program 1801 Volume Item Notes Management 2 Item [Structural Steel: Beams, Columns, Galvanized 8 Plates, and Trusses SRE Steel Air-indoor None None III.B5-3 3.5.1-58 C (includes welds and bolted connections) Loss of material Structures Monitoring E -Program -Water 9 Foundation SRE Concrete Water-flowing Control Structures '1I1.A6-5 3.5.1-35 0518 Cracking Inspection 0519 Structures Monitoring I 10 Foundation SRE Concrete Soil None Program -Water N/A N/A 0501 Control Structures 0518 Inspection Reinforced Strl;lctures Monitoring I 11 Concrete: Walls, SRE Concrete Air-indoor None Program -Water N/A N/A 0501 and ceilings Control Structures 0518 Inspection Structures Monitoring III.A6-10 3.5.1-43 A Program -Masonry. 12 Masonry Block FB,SRE Concrete Air-indoor Cracking Wall Inspection twalls Blocks Fire Protection III.A6-10 3.5.1-43 E Program . 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-96 January 2010 * *

• 0 Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-5 Aging Management Review Results -Diesel Generator Building Aging Effect NUREG-Row Component

/ Intended Material Environment Requiring Aging Management 1801 Table I Notes No. Commodity Function' Program Volume 2 Item Management Item Battery Racks SSR Carbon Steel Air-indoor Loss of material Str..tures Monitoring lII.B3-7 3.5.1-39 C Program Structural Steel: Beams, Columns, Structures Monitoring 2 Plates, and Trusses EN, SSR Carbon Steel Air-indoor Loss of material Program III.A3-12 3.5.1-25 A (includes welds and bolted connections) Structural Steel: Beams, Columns, Galvanized Air-indoor None None II1.B5-3 3.5.1-58 C 3 Plates, and Trusses EN, SSR Steel (includes welds and-bolted connections) 4 Diesel Generator EN, MB, Concrete Air-outdoor None Structures Monitoring N/A N/A IExhaust Plenums SRE, SSR Program 0501 Diesel Generator EN, MB, Concrete Air-outdoor None Structures Monitoring N/A N/A Intake Plenums SRE, SSR Program 0501 6 Diesel Generator EXP, EN, Structures Monitoring 6 PdsasislGneao X~sE, Concrete Soil None Program N/A N/A 0501 Pedestals SSR Porm00 7 Exterior Walls EN, MB Concrete Air-outdoor None r Monitoring N/A N/A 7 (above grade) SRE, SSR Program 0501 EN, EP, .Structures Monitoring 8 Foundations EXP, Concrete Soil None Program N/A N/A 08 -udtosSRE,*SSR Porm0501 Structures Monitoring Reinforced EN, FBI MB, Program 9 Concrete: Walls, E, FB, Concrete Air-indoor None N/A N/A 0501 floors, and ceilings Fire Protection Program Aging Management Review Results Page 3.5-97 January 2010* . Table 3.5.2-5 Row Component I Intended No. Commodity Function 1 1 Battery Racks SSR Steel: Beams, Columns, 2 Plates, and Trusses EN,SSR (includes welds and bolted connections) Steel: Beams, Columns, 3 Plates, and Trusses EN, SSR' (includes welds and connections) 4 Diesel Generator EN, MB, Exhaust Plenums SRE, SSR 5 Diesel Generator EN, MB, Intake Plenums SRE, SSR 6 Diesel Generator EXP, EN, Pedestals SSR 7 Exterior Walls EN, MB, (above grade) SRE, SSR 8 Foundations EN, EXP, SRE,.SSR Reinforced EN, FB, MB, 9 Concrete: Walls, floors, and ceilings SRE, SSR Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Diesel Generator Building Aging Effect NUREG-Aging Management 1801 Table 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Carbon Steel Air-indoor*

Loss of material Structures Program-III.B3-7 3.5.1-39 C Structures Monitoring Carbon Steel Air-indoor Loss of material III.A3-12 3.5.1-25 A Program Galvanized , Steel* Air-indoor None None III.B5-3 3.5.1-58 C Concrete Air-outdoor None Structures Monitoring N/A N/A I Program 0501 Concrete Air-outdoor None Structures Monitoring N/A N/A I Program 0501 Concrete Soil None Structures Monitoring N/A N/A I Program 0501 Concrete Air-outdoor None Structures Monitoring N/A N/A I Program 0501 Concrete Soil None Structures Monitoring N/A N/A I Program 0501 Structures Monitoring Program I Concrete Air-indoor None N/A N/A Fire Protection 0501 Program Page 3.5-97 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-5 Aging Management Review Results -Diesel Generator Building dAging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table I Notes No. Commodity Function Program Volume 2 Item S Management Item EN, T Structures Monitoring N 10 Roof EN, MB, Concrete Air-indoor None Program N/A N/A 0501 R0 RE, i e f0526 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-98 January 2010 Aging Management Review Results Page 3.5-98 January 2010 Columbia Generating Station license Renewal Application Technical Information Table 3.5.2-5 Aging Management Review Results -Diesel Generator Building Aging Effect NUREG-Row Component I Intended Aging Management 1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item EN, MB, Structures Monitoring I 10 Roof SRE, SSR Concrete . Air-indoor None Program N/A N/A 0501 0526 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-98 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-6 Aging Management Review Results -Fresh Air Intake Structure No. 1 and 2 Aging Effect NUREG-1801T Row Component/

Intended Material Environment Requiring Aging Management Volume 2 G8 Table I Notes No. Commodity Function1 Mata M int Program Item 2 Item~Management Item Ie Concrete Air Structures Monitoring I EN, SSR Concrete Air-outdoor NoneProgram N/A N/A Plenum 0501m 2 Exterior Walls EN, MB Structures Monitoring N/A N/AI (above grade) SSR Concrete Air-outdoor None Program 0501 Exterior Walls Structures Monitoring 1 3 Ebelow grade) EN, SSR Concrete Soil None Program N/A N/A 0501; ~Structures MonitoringI 4 Foundations. EN, SSR Concrete Soil None Pr oram N/A N/A I NoneProgram 0501 Structures N/Ait0501 5 Roof EN, MB Concrete Air-outdoor None Program N/A N/A SSR Porm0501 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-99 January 2010* * .

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-6 . Aging Management Review Results -Fresh Air Intake Structure No.1 and 2 Row Component I Intended Aging Effect Aging Management NUREG-1801 , Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes . ' Management Item 1 Concrete Air EN, SSR Concrete Air-outdoor None Structures Monitoring N/A N/A I I Plenum Program 0501 2 Exterior Walls EN, MB, Concrete Air-outdoor None Structures Monitoring N/A N/A I (above grade) SSR Program 0501 3 Exterior Walls EN,SSR Concrete Soil None* Structures Monitoring N/A N/A I (below grade) Program 0501 ; Structures Monitoring I 4 Foundations, EN,SSR Concrete Soil None Program N/A N/A 0501 5 Roof EN,MB, Concrete Air-outdoor None Structures Monitoring N/A N/A I SSR Program 0501 1 Refer to Table 2.0-1 for intended function descriptions.

Aging Management Review Results Page 3.5-99 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-7 Aging Management Review Results -Makeup Water Pump House Row Component Intended Aging Effect AgingManagemeNUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring AngMame Volume 2 Item Notes Management Item Structural Steel: Structures Monitoring Beams, Columns, Program -Water iE 1 Plates, and Trusses SNS Carbon Steel Air-indoor Loss of material CnrolII.A6-11 3.5.1-47t (nldswlsadControl Stry~ctures 0518 (includes welds and Iseto bolted connections) Inspection Structural Steel: Beams, Columns, G laie BePlates, and Trusses SNS Galvanized Air-indoor None None III.B5-3 3.5.1-58 C 2 Pltes an Truses SNSSteel (includes welds and bolted connections) Structures Monitoring IExterior Walls Program -Water N/A N/A 0501 (above grade) MB, SNS Concrete Air-outdoor None Control Structures N Inspection 0518 Structures Monitoring I 4 ~~~Program -Water NANA 00 4 Pump Pit SNS Concrete Air-indoor None Control Structures N/A N/A 0501 Inspection Structures Monitoring 1 5 Foundations SNS Concrete Soil None Program -Water N/A N/A 0501 Control Structures 0518 Inspection Reinforced Structures Monitoring 1 6 Concrete: Walls, SNS Concrete Air-indoor None Program -Water N/A N/A 0501 floors, and ceilings Control Structures0518 Inspection 0518 Structures Monitoring I Program -Water 05017 Roof MB, SNS Concrete Air-indoor None -Control Structures N/A N/A 0518 Inspection 0526 Aging Management Review Results Page 3.5-100 January 2010 Table 3.5.2-7 Row Component I Intended No. Commodity Function 1 Structural Steel: Beams, Columns, 1 Plates, and Trusses SNS (includes welds and bolted connections) Structural Steel: Beams, Columns, 2 Plates, and Trusses SNS (includes welds and bolted connections) 3 Exterior Walls MB, SNS (above grade) 4 Pump Pit SNS 5 Foundations SNS Reinforced 6 Concrete: Walls, SNS loars, and ceilings 7 Roof MB, SNS Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review .Results -Makeup Water Pump House Aging Effect Aging Management NUREG-1801 Table 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Structures Monitoring Program -Water, E Carbon Steel Air-indoor Loss of material III.A6-11 3.5.1-47 Control Stryctures 0518 Inspection Galvanized Steel Air-indoor None None III.B5-3 3.5.1-58 C Structures Monitoring I Concrete Air-outdoor None Program -Water N/A N/A 0501 Control Structures 0518' Inspection Structures Monitoring I Concrete Air-indoor None Program -Water N/A N/A 0501 Control Structures Inspection 0518 Structures Monitoring I Concrete Soil None Program -Water N/A N/A 0501 Control Structures 0518 Inspection Structures Monitoring I Concrete Air-indoor None Program":'

Water N/A N/A 0501 Control Structures Inspection 0518 Structures Monitoring I Concrete Air-indoor None* Program -Water N/A N/A 0501 Control Structures ' 0518 Inspection 0526 Page 3.5-100 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-7 Aging Management Review Results -Makeup Water Pump House Aging Effect AigManagement VoumeG-2 Notes Row Componentl Intended Aging Efntct Aging 2aaeetNUE-0 TablelI No. Commodity Functiond Material Environment Requiring Program Volume Item Management Item Refer to Table 2.0-1 for intended function descriptions.

Aging Management Review Results Page 3.5-101 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-7 Aging Management Review Results -Makeup Water Pump House' Row "Component I "Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item ; 1 Refer to Table 2.0-1 for intended function descriptions.

Aging Management Review Results Page 3.5-101 January 2010 Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results Page 3.5-1 02 January 2010 Aging Management Review Results Page 3.5-102 January 2010 Table 3.5.2-8 Row Component I Intended No. Commodity Function 1 1 Battery Racks SSR 2 Control Room SSR Ceiling _ 3 Metal Siding SNS 4 Partition Walls SRE Steel: Beams, Columns, EN, SSR, 5 Plates, and Trusses (includes welds and SRE bolted connections) Steel: Beams, Columns, EN, SSR, 6 Plates, and Trusses SRE (includes welds and bolted connections) 7 Sump Liners SNS Exterior Walls EN, MB, 8 (above grade) SHD, SRE, SSR 9 Foundations EN, EXP, SRE, SSR Aging Management Review Results

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Radwaste Control Building Aging Effect Aging Management NUREG-1801 Table 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Carbon Steel Air-indoor Loss of material Structures Monitoring II I. B3-7 3.5.1-39 C Program . Carbon Steel Air-indoor Loss of material Structures Monitoring liLA 1-12 3.5.1-25 A Program Galvanized Air-outdoor Loss of material Structures Monitoring . III.B2-7 3.5.1-50 C Steel Program Galvanized Air-indoor None None 111.85-3 3.5.1-58 C Steel Structures Monitoring Carbon Steel Air-indoor Loss of material liLA 1-12 3.5.1-25.

A Program Galvanized Steel Air-indoor None None III.B5-3 3.5.1-58 C Stainless Steel Air-indoor None None II I. B5-5 3.5.1-59 C Structures Monitoring I Concrete Air-outdoor None Program N/A N/A 0501 Concrete Soil None Structures Monitoring N/A N/A I Pro_gram 0501 Page 3.5-102 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-8 Aging Management Review Results -Radwaste Control Building Aging Effect Aging Management NUREG-1801 Table N Row Component y Intended Material Environment Requiringg Volume 2 Ite Notes No. Commodity Function 1 Management Item M Structures Monitoring III.A3-11 3.5.1-43 Program -Masonry 10 Masonry Block FB, SHD, Concrete Air-indoor Cracking Wall Inspection alls SRE Blocks Fire Protection II1.A3-11 3.5.1-43 E Program Structures Monitoring Reinforced EN, FB, Program I 11 Concrete:

Walls, SHD, SPB, Concrete Air-indoor None N/A N/A oors, and ceilings SRE, SSR Fire Protection Program I Reinforced Concrete: Walls, Cracking Structures Monitoring floors, and ceilings EN, FB, Program H 12 (Radwaste Control SHD, SPB, Concrete Air-indoor Change in N/A N/A 0521 Building Zone E at SRE, SSR material Fire Protection

1. 437'-0" and Zone properties Program K at el. 467' 0")Structures Monitoring I 13EN, MB, Concrete Air-indoor None Program N/A N/A 0501 SSR 0526 Structures Monitoring 1/ /14 Sumps SNS Concrete Air-indoor None Program N/A N/A 0501 Refer to Table 2.0-1 for intended function descriptions.

Aging Management Review Results Page 3.5-1 03 January 2010 Aging Management Review Results Page 3.5-103 January 2010 , * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-8 Aging Management Review Results -Radwaste Control Building Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management . Item Structures Monitoring III.A3-11 3;5.1-43 A Program -Masonry 10 Masonry Block FB, SHO, Concrete Air-indoor Cracking Wall Inspection Walls SRE Blocks Fire Protection III.A3-11 3.5.1-43 E ProQram Structures Monitoring Reinforced EN, FB, Program I 11 Concrete:

Walls, SHO,SPB, Concrete Air-indoor None N/A N/A 0501 and ceilings SRE, SSR Fire ProteCtion Program Reinforced Concrete: Walls, Cracking Structures Monitoring floors, and ceilings EN, FB, Program H 12 (Radwaste Control SHO, SPB, Concrete Air-indoor Change in N/A N/A 0521 Building Zone E at SRE, SSR material Fire Protection el. 437'-0" and Zone properties . Program K at el. 467' 0") EN, MB, Structures Monitoring I 13 Roof SSR Concrete Air-indoor None Program N/A N/A 0501 0526 14 Isumps SNS Concrete Air-indoor None Structures Monitoring N/A N/A I Program 0501 1 Refer toTable 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-103 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-9 Aging Management Review Results -Service Building Row Component / intended Aging Effect Aging Management NUREG-1801 Table I Notes No. Commodity Function 1 Material Environment Requiring Volume 2 Item Management Program Item Item 1 Roof Decking SNS Galvanized Air-indoor None None 11I.B5-3 3.5.1-58 C Steel Structural Steel: Beams, Columns, 2 Plates, and Trusses SNS Carbon Steel Air-indoor Loss of material Structures Monitoring II1.A3-12 3.5.1-25 A (includes welds and Program bolted connections) Structural Steel: Beams, Columns, 3 Plates, and Trusses SNS Galvanized Air-indoor None None III.B5-3 3.5.1-58 C (includes welds and bolted connections)Exterior Walls Structures Monitoring N (above grade) EN, SNS Concrete Air-outdoor None Program N/A N/A 0501 EN, EXP, Structures Monitoring I 5 Foundations SNS Concrete Soil None Program N/A N/A 0501 Reinforced Structures Monitoring 1 6 Concrete: Walls, EN, SNS Concrete Air-indoor None Program N/A N/A 0501 floors, and ceilings 0501 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-1 04 January 2010 Aging-Managern , ent Review'Results Page 3.5-104 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-9 Aging Management Review Results -Service Building Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1. Material Environment Requiring Program Volume 2 Item Notes Management Item 1 Roof Decking SNS Galvanized Air-indoor None None 111.85-3 3.5.1-58 C Steel Steel: Beams, Columns, Structures Monitoring 2 Plates, and Trusses SNS Carbon Steel Air-indoor Loss of material III.A3-12 3.5.1-25 A (includes welds and Program bolted connections) Structural Steel: Beams, Columns, Galvanized 3 Plates, and Trusses SNS Steel Air-indoor None None III.B5-3 3.5.1-58 C (includes welds and bolted connections) 4 Exterior Walls EN,SNS Concrete Air-outdoor None Structures Monitoring N/A N/A I (above grade) Program 0501 5 Foundations EN, EXP, Concrete Soil None Structures Monitoring N/A N/A I' SNS Program 0501 Reinforced Structures Monitoring I 6 Concrete: Walls, EN,SNS Concrete Air-indoor None Program N/A N/A 0501 and ceilings 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review' Results Page 3.5-104 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3&5.2-10 Aging Management Review Results -Turbine Generator Building Row *Component

~ Intended Aging Effect Aging Management NUREG-1801 Table I Notes Row Component Intended 1 Material Environment Requiring Program Volume 2 Item No. Commodity -Function Prga Maagmetete_____ ___ _ _____Management j___ Item _ ___ G Structures Monitoring 1 Metal Siding .RF Galvanized- Air-outdoor Loss of material 111.B2-7 3.5.1-50 C.Steel Program~u~ura Steel: StelvmatriazPrgra 2 Roof Decking SRE Galvanized Air-indoor None None I1.B5-3 3.5.1-58 C 3 Shield Walls MB Carbon Steel Air-indoor Loss of material Structures Monitoring 111.B3-7 3.5.1-39 C Program 0517 Structural Steel: Bears, Columns, 4 Plates, and Trusses SNS, SRE Carbon Steel Air-indoor Loss of material Structures Monitoring II1.A3-12 3.5.1-25 A (includes welds and Program bolted connections) Structural Steel: Beams, Columns, 5 Plates,. and Trusses SNS, SRE Galvanized Air-indoor None None 111.B5-3 3.5.1-58 C (includes welds and Steel bolted connections)- 6 Sump Liners SNS Stainless Steel Air-indoor None None 111.B5-5 3.5.1-59 C 7 Sump Liners SNS Stainless Steel Raw water Loss of material Structures Monitoring E* ~~Program V.C- 33178 0515 8 Exterior Walls EN, SNS, Concrete Air-outdoor None Structures Monitoring N/A N/A 0 ( (above grade) SRE Program 0501 9 EN, EXP, Concrete Soil Structures Monitoring N/A N/AI Foundations SNS, SRE None Program 0501 1 lain Steam Tunnel EN, HELB, Structures Monitoring I 10 Extension MB, PW, Concrete Air-indoor None Program N/A N/A 0501 SHD, SSR Aging Management Review Results Page 3.5-105 January 2010* Table 0 Row Componentl Intended No. Commodity Function 1 1 Meta! Siding SRE, SNS 2 Roof Decking SRE 3 Shield Walls MB Structural Steel: Beams, Columns, 4 Plates, and Trusses SNS, SRE (includes welds and bolted connections) Structural Steel: Beams, Columns, 5 Plates,. and Trusses SNS, SRE (includes welds and bolted connections)* 6 Sump Liners SNS 7 Sump Liners SNS 8 Exterior Walls EN, SNS, (above grade) SRE 9 Foundations EN, EXP, SNS, SRE Main Steam Tunnel EN, HELB, 10 MB,PW, Extension SHO, SSR Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Turbine Generator Building ,-Aging Effect NUREG-1801 Material Environment Requiring Aging Management Volume 2 Table 1 Notes -' Program Item Management Item Galvanized Air-outdoor Loss of material Structures Monitoring III.B2-7 3.5.1-50 C Steei Program Galvanized Air-indoor None None II I. B5-3 3.5.1-58 C Steel , Carbon Steel Air-indoor Loss of material Structures Monitoring III.B3-7 3.5.1-39 C __ Program _ 0517 Structures Monitoring Carbon Steel Air-indoor Loss of material III.A3-12 3.5.1-25 A Program Galvanized Steel Air-indoor-None None II I. B5-3 3.5.1-58 C Stainless Steel -Air-indoor None None III.B5-5 3.5.1-59 C Stainless Steel . Raw water Loss of material Structures Monitoring VII.C3-7 3.3.1-78 E Program 0515 Concrete Air-outdoor None Structures Monitoring N/A N/A I Program 0501 Concrete Soil None Structures Monitoring N/A N/A I Program 0501 Structures Monitoring I Concrete Air-indoor None N/A N/A Program 0501 Page 3.5-105 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-10 Aging Management Review Results -Turbine Generator Building Aging Effect Management NUREG-1801 Notes Row Component I Intended Material Environment Requiring Aging I Volume 2 Table Notes No. Commodity Function Management Program mItem Structures Monitoring III.A3-11 3.5.1-43 A Program -Masonry 11 Masonry Block EN, FB, SRE Concrete Airindoor Cracking Wall Inspection Wails Blocks Fire Protection II1.A3-11 3.5.1-43 E Program Structures Monitoring 2Reinforced E Program I 12 Concrete:

Walls, EN, FB, Concrete Air-indoor None N/A N/A 0501 SNS, SRE 00oors, and ceilings Fire Protection Program EN, MB, Structures Monitoring 13 Shield Walls SHE D Concrete Air-indoor None Program N/A N/A 0501 14 SilConcrete Structures Monitoring 1 SHD (solid blocks or Air-indoor None Program N/A N/A 0501 bricks) 0517 15 Sumps SNS Concrete Air-indoor None Structures Monitoring N/A N/A I Program 0501 16 Turbine Generator EN, SRE, Concrete Air-indoor None Structures Monitoring N/A N/A I Pedestals SNS Program 0501 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-106 January 2010 Columbia Generating Station License Renewal Application Technical Information '. Table 3.5.2-10 Aging Management Review Results -Turbine Generator Building Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management , Item Structures Monitoring III.A3-11 3.5.1-43 A Program -Masonry 11 Masonry Block EN, FB, SRE Concrete Air-indoor Cracking Wall Inspection Walls Blocks Fire Protection III.A3-11 3.5.1-43 . E Program Structures Monitoring Reinforced EN, FB, Program I 12 Concrete:'Walls, Concrete Air-indoor None N/A N/A . floors, and ceilings SNS, SRE Fire Protection 0501 Program 13 Shield Walls EN, MB, Concrete* Air-indoor None Structures Monitoring N/A N/A I SHD Program 0501 EN,MB, Concrete Structures Mon.itoring I 14 Shield Walls SHD (solid blocks or Air-indoor None Program N/A N/A 0501 bricks) 0517 15 Sumps SNS Concrete Air-indoor None Structures Monitoring N/A N/A I Program 0501 16 r-urbine Generator EN, SRE, Concrete Air-indoor None Structures Monitoring N/A N/A I Pedestals SNS Program 0501 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-106 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-11 Aging Management Review Results -Water Filtration Building Aging Effect AigManagement NoumeG- 802 Notes Row Component

/ Intended Mgin Efftct Aging 2 Tablel No. Commodity Functioni Material Environment Requiring Program Volume Item Management ItemStructures Monitoring 3513 1 lBattery Racks SRE Carbon Steel Air-indoor Loss of material S M i I1.B3-7 3.5.1-39 C....... rograin 2 Metal Siding SRE Galvanized Air-outdoor Loss of material Structures Monitoring lll32-7 3.5.1-50 C Steel Program 3 Roof Decking SRE Galvanized Air-indoor None None II.B5-3 3.5.1-58 C Steel Structural Steel: Beams, Columns, 4 Plates, and Trusses SRE Carbon Steel Air-indoor Loss of material Structures Monitoring Ili.A3-12 3.5.1-25 A (includes welds and Program bolted connections) Structural Steel: Beams, Columns, Galvanized 5 Plates, and Trusses SRE Steel Air-indoor None None II1.B5-3 3.5.1-58 C (includes welds and bolted connections) 6 Foundations SRE Concrete Soil None Structures Monitoring N/A N/A I Program 0501 7 Structures Monitoring N/A N/A I Sums SRE Concrete Air-indoor None Program 0501 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-107 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-11 Aging Management Review Results -Water Filtration Building Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item ... Batter, Racks SRE Carbon Steel Air-indoor Loss of material Structures Monitoring III.B3-7 3.5.1-39 C I Piogiam 2 Metal Siding SRE Galvanized Air-outdoor Loss of material Structures Monitoring II I. B2-7 3.5.1-50 C Steel Program 3 Roof Decking SRE Galvanized Air-indoor None None III.B5-3 3.5.1-58 C Steel IStructural Steel: " Beams, Columns, Structures Monitoring 4 Plates, and Trusses SRE Carbon Steel Air-indoor Loss of material Program III.A3-12 3.5.1-25 A (includes welds and bolted connections)

Structural Steel: Beams, Columns, . Galvanized 5 Plates, and Trusses SRE Steel Air-indoor None None II I. B5-3 3.5.1-58 C (includes welds and . bolted connections) 6 Foundations SRE Concrete Soil None Structures Monitoring N/A N/A I Program 0501 7 lSumps SRE Concrete Air-indoor None Structures Monitoring N/A N/A I Program 0501 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-107 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-12 Aging Management Review Results -Yard StructuresRow Component/Comm Intended Aging Effect Aging Management NUREG-1801 Table I No. om nt/ Functiond Material Environment Requiring ProgramVolume 2 te Notes Management Item 1 she Relay House SRE Carbon Steel Air-outdoor Loss of material Structures Monitoring III.A3-12 3.5.1-25 A Metal Siding Program 2 ,she Relay House SRE Galvanized Air-indoor None None 1.B5-3 3.5.1-58 C Roof Decking Steel 3 she Relay House Galvanized Structures Monitoring Rof3ekigSRE Sel Air-outdoor Loss of material Structures3.5.1-50iC Roof Decking Steel Program ,she Relay House Structural Steel: 4 Beams, Columns, SRE Carbon Steel Air-indoor Loss of Structures Monitoring II1.A3-12 3.5.1-25 A Plates, and Trusses material Program (includes welds'and bolted connections) Fire Water Bladder 5 ank (FP-TK-110) SRE Aluminum Air-outdoor None Structures Monitoring N/A N/A 0522__ ent Line Enclosure Program 6 Manhole Covers EN, SNS, Carbon Steel Air-outdoor Loss of material Structures Monitoring II1.A3-12 3.5.1-25 A SRE, SSR Program 7 Transmission SRE Galvanized Air-outdoor Loss of material Structures Monitoring I1.B2-7 3.5.1-50 C towers Steel Program Structures Monitoring 8 eir Box SRE Carbon Steel Water-flowing Loss of material Program -Water E Control Structures III.A6-11 3.5.1-47 0518 Inspection9 she Relay House SRE Concrete Soil None Structures Monitoring N/A N/A Foundation Program 0501 Aging Management Review Results Page 3.5-108 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-12 Aging Management Review Results -Yard Structures Row ComponentlComm Intended Aging Effect Aging Management NUREG-1801 Table 1 No. odity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item 1 Ashe Relay House* SRE Carbon Steel Air-outdoor Loss of material Structures Monitoring III.A3-12 3.5.1-25 A Metal Siding Program 2 Ashe Relay House SRE Galvanized Air-indoor None None II I. B5-3 3.5.1-58 C Roof Decking Steel 3 Ashe Reiay House SRE Galvanized Air-outdoor Loss of material Structures Monitoring II I. B2-7 3.5.1-50 C Roof Decking Steel Program Ashe Relay House Structural Steel: 4 Beams, Columns, SRE Carbon Steel Air-indoor Loss of Structures Monitoring III.A3-12 3.5.1-25 A Plates, and Trusses material Program (includes welds*and bolted connections) Fire Water Bladder Structures Monitoring I 5 Tank (FP-TK-11

0) SRE Aluminum Air-outdoor None N/A N/A Vent Line Enclosure Program 0522 6 Manhole Covers EN, SNS, Carbon Steel Air-outdoor Loss of material Structures Monitoring III.A3-12 3.5.1-25 A SRE, SSR Program 7 Transmission SRE Galvanized Air-outdoor Loss of material Structures Monitoring

• III.B2-7 3.5.1-50 C Towers Steel Program Structures Monitoring 8 Weir Box SRE Carbon Steel Water-flowing Loss of material Program -Water III.A6-11 3.5.1-47 E Control Structures 0518 Inspection 9 Ashe Relay House SRE Concrete Soil None Structures Monitoring N/A N/A I Foundation Program 0501 Aging Management Review Results Page 3.5-108 January 2010 . * *
• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-12 Aging Management Review Results -.Yard Structures Row Component/CommIntet Aging Management NUREG-1801 Table I Notes No. odity Function' Material Environment Requiring PAogi Volume 2 Item______ _______JManagement Program Item Ie Cicltn ae Structures Monitoring 10 Basin Wate Program -Water N/A N/A I 10 Cicuating ae SNS, SRE Concrete Soil 1 None Cotl Structures Moitrng01 Basin ~Control Structures j NA/A I0501 Inspection Structures Monitoring 11 Circulating Water SNS, SRE Concrete Air-outdoor None Program -Water N/A N/A 0 Basin Control Structures 0501 Inspection Cicltn WaerLoss of material Structures Monitoring E 12 Circulating Water SNS, SRE Concrete Raw water Program -Water IlI.A6-5 3.5.1-35 0518 Basin C Control Structures 0519 Cracking Inspection 0520 Condensate Storage tutrsMntrn 13 Tank Foundation SNS, SRE Concrete Air-outdoor None Structures Monitoring N/A N/A 0 (ring wall) Program 0501 Condensate Storage FLB SRE Structures Monitoring 14 ank Retaining Area , SR Concrete Soil None Program N/A N/A 0_ (slab) 050R Condensate Storage FLB, SRE Co Structures Monitoring 15 Tank Retaining Area SSR 0501______ (slab) 0501 Condensate Storage Structures Monitoring 16 ank Retaining Area FLB, SRE, Concrete Air-outdoor None Program N/A N/A-___(walls) 05 Structures Monitoring 17 Cooling Tower SNS Concrete SoilNone Program-Water N/A N/A Basins Control Structures 0501 Inspection Structures Monitoring 18 Cooling Tower SNS Concrete Air-outdoor None Program -Water N/A N/A Basins Control Structures 0501 Inspection Aging Management Review Results Page 3.5-109 January 2010* *
• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-12 Aging Management Review Results -. Yard Structures Row Component/Comm Intended Aging Effect Aging Management NUREG-1801 Table 1 No. .odity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Structures Monitoring 10 Circulating Water SNS,SRE Concrete Soil None Program -Water N/A N/A I Basin Control Structures 0501 Inspection Structures Monitoring , 11 Circulating Water SNS, SRE Concrete Air-outdoor None Program -Water N/A N/A I Basin Control Structures 0501 , Inspection j Loss of material Structures Monitoring E 12 Circulating Water SNS, SRE Concrete Raw water. Program -Water III.A6-5 3.5.1-35 0518 Basin Control Structures 0519 Cracking Inspection 0520 Condensate Storage Structures Monitoring . I 13 Foundation SNS, SRE Concrete Air-outdoor None N/A N/A I/ring wall) Program 0501 Condensate Storage FLB, SRE, Structures Monitoring I 14 Retaining Area Concrete Soil None Program N/A N/A slab) SSR 0501 Condensate Storage FLB, SRE, Structures Monitoring I 15 Retaining Area Concrete Air-outdoor None* Program N/A N/A I'slab) SSR 0501 Condensate Storage FLB, SRE, Structures Monitoring I 16 Retaining Area Concrete Air-outdoor None Program N/A N/A walls) SSR 0501 Structures Monitoring Cooling Tower -Program -Water I 17 Basins SNS Concrete Soil None Control Structures N/A N/A 0501 Inspection Structures Monitoring 18 Cooling Tower SNS Concrete Air-outdoor None Program -:-Water N/A N/A I Basins Control Structures 0501 Aging Management Review Results Page 3.5-109 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-12 Aging Management Review Results -Yard Structures Agig Efec MaageentNUREG-1801 Notes Row Component/Comm Intended Effect Aging Management Volume 2 Table I No. odity Function' Material Environment Requiring Program Item Management Item Loss of material Structures Monitoring ECooling Tower SNS Concrete Raw water Program -Water IlI.A6-5 3.5.1-35 0518 1 oglins Tower Control Structures 0519 Cracking Inspection 0520 20 Duct banks EN, SNS, Concrete Soil None Structures Monitoring N/A N/A SRE, SSR Program 0501 Fire Water Bladder Structures Monitoring 1 21 Tank (FP-TK-1 10) SRE Concrete Air-outdoor None S ronrin N/A N/A 0501 Embankment Apron Program Fire Water Bladder Structures Monitoring I22 Tank (FP-TK-110)

SRE Concrete Soil None S ronrin N/A N/A 0501 Support Pads Program HSSF Liquid Structures Monitoring23 Hydrogen Storage Program 1 Tank Foundation SNS Concrete Soil None N/A N/A 0501 (slab)HSSF Liquid Structures Monitoring 24 Hydrogen Storage SNS Concrete Air-outdoor None Program N/A N/A I Tank Foundation 0501 (raised pedestals) 25 Manholes EN, SNS, Concrete Soil None Structures Monitoring N/A N/A 25 _Manholes._SRE, SSR Program 0501 Structures Monitoring N 26 Manholes EN, SNS, Concrete Air-outdoor None Program N/A N/A 0501 26 ManholesSRE, SSR 00 Structures Monitoring N 27 Thrust Blocks SRE Concrete Soil None Program N/A N/A 0501 Transformer/ Structures Monitoring I 28 Breaker SRE Concrete Soil None Program N/A N/A 0501 Foundations (SBO)Aging Management Review Results Page 3.5-110 January 2010 0 0 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-12 Aging Management Review Results -Yard Structures Row ComponentlComm Intended Aging Effect Aging Management NUREG-1801 Table 1 No. odity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Loss of material Structures Monitoring E 19 Cooling Tower SNS Concrete Raw water Program -Water III.A6-5 3.5.1-35 0518 Basins Cracking Control Structures 0519 Inspection 0520 20 Duct banks EN, SNS, Concrete Soil None Structures Monitoring N/A N/A I SRE, SSR Program 0501 Fire Water Bladder Structures Monitoring I 21 Tank (FP-TK-11

0) SRE Concrete Air-outdoor None N/A N/A, Embankment Apron Program 0501 Fire Water Bladder Structures Monitoring I , 22 (FP-TK-110)

SRE Concrete Soil None N/A N/A Pads Program 0501 HSSF Liquid Structures Monitoring 23 Hydrogen' Storage SNS Concrete Soil None Program N/A N/A I Tank Foundation 0501 slab) HSSF Liquid Structures Monitoring 24 lHydrogen Storage SNS Concrete Air-outdoor None Program N/A N/A I Foundation -0501 I/raised 25 Manholes EN, SNS, Concrete Soil None Structures Monitoring N/A N/A I SRE, SSR Program 0501 26 Manholes EN, SNS, Concrete Air-outdoor None Structures Monitoring N/A N/A I SRE, SSR Program 0501 27 Thrust Blocks SRE Concrete Soil None Structures Monitoring N/A N/A I . Program 0501 Transformerl Structures Monitoring I 28 Breaker SRE Concrete Soil None Program N/A N/A 0501* Foundations(SBO) Aging Management Review Results Page 3.5-110 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-12 Aging Management Review Results -Yard Structures Aging Effect NUREG-1801 Notes Row Component/Comm Intended Material Environment Requiring i Volume 2 No. odity Function' Management Program Item Item Transformer/

Structures Monitoring 1 29 Breaker SRE Concrete Air-outdoor None Program N/A N/A 0501 Foundations (SBO) I Transmission Tower Structures Monitoring I 30 Foundations SRE Concrete Soil None Program N/A N/A 0501 Transmission Tower Structures MonitoringI 31 Foundation SRE Concrete Air-outdoor None Program N/A N/A 0501 Foundations Porm00 Fire Water Bladder 32 Tank (FP-TK-110) SRE Earthen Air-outdoor Loss of form Structures Monitoring N/A N/A G-Embankment Program 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-111 January 2010 Aging Management Review Results Page 3.5-111 January 20,10* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-12 Aging Management Review Results -Yard Structures Row Component/Comm Intended Aging Effect Aging Management NUREG-1801 Table 1 No. odity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item rrransformerl Structures Monitoring I 29 Breaker SRE Concrete Air-outdoor None Program N/A N/A 0501-Foundations (S80) 30 !Transmission Tower SRE Concrete Soil None Structures Monitoring N/A N/A I Foundations Program 0501 31 !Transmission Tower SRE Concrete Air-outdoor None Structures Monitoring N/A N/A I Foundations Program 0501 Fire Water Bladder Structures Monitoring 32 Tank (FP-TK-110)

SRE Earthen Air-outdoor Loss of form N/A N/A G -Embankment Program 1 Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-111 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities R Aging Effect Aging Management NUREG-1801 Table Row Componenty Intended Material Environment Requiring A gg Volume2 tem Notes No. Commodity Function 1 Maaeet Program ItmItem j__Management Item Steel and Other Metals Aging Management Review Results Page 3.5-112 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item . Notes Management Item Steel and Other Metals III.B2-10 1 Anchorage/Embed SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B3-7 3.5.1-39 A ments SSR Program III.B4-10 III.B5-7 III.B2-5 2 Anchorage/Embed SNS, SRE, Galvanized Air-indoor None None III.B3-3 3.5.1-58 A ments SSR Steel III.B4-5 III.B5-3 III.B2-8 3 Anchorage/Embed SNS, SRE, Stainless Steel Air-indoor None None . III.B3-5 3.5.1-59 A ments SSR III.B4-8 III.B5-5 III.B2-10 4 Anchorage/Embed SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring II I. B3-7 3.5.1-39 ments SSR . Program III.B4-10 A III.B5-7 5 Anchorage/Embed SNS, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring II I. B2-7 3.5.1-50 ments SSR Steel Program III.B4-7 A 6 Anchorage/Embed SNS, SRE, Stainless Steel Air-outdoor None Structures Monitoring III.B2-7 3.5.1-50 I ments SSR Program III.B4-7 0525 7 Anchorage/Embed SNS, SRE, Carbon Steel Raw water Loss of material Structures Monitoring III.A6-11 3.5.1-47 E ments SSR Program Aging Management Review Results Page 3.5-112 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-13 Aging Management Review Results -Bulk Commodities Row Component Intended Aging Effect Aging Management NUREG-1801 Table INotes No. Commodity Function' Material Environment Requiring Program Volume 2 Item Management Item*8 Anchorage/Embed SNS, SRE, Galvanized Srcue oioig VIC-ments SSR Steel .Raw water Loss of material Structures Monitoring II.A6-11 3.5.1-47 E Iet S te Program 9 Anchorage/Embed SNS, SRE, Stainless Steel Raw water Loss of material Structures Monitoring VI1.C3-7 3.3.1-78 E ments SSR Program 0524 1I1.132-8 10 Cable Tie Wraps S , SRE, 111.B3-5 3.5.1-59 C S10 SRC, Stainless Steel Air-indoor None None Ill.B4-58 I11.B5-5 11 Cable Tray and. SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring 111.12-10 3.5.1-39 A Conduit Supports SSR Program 12 Cable Tray and SNS, SRE, Galvanized Air-indoor None None 111.B2-5 3.5.1-58 A Conduit Supports SSR Steel 13 Cable Tray and SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring 111.12-10 3.5.1-39 A.Conduit Supports SSR Program Cable Tray and SNS, SRE, Galvanized Air-outdoor Loss of material Pr oram _.1- 3510 A Conduit Supports SSR Steel aProgram EN, FB, 15 Cable Trays and SNS, SRE, Aluminum Air-indoor None None 111.B3-2 3.5.1-58 C Conduits SSR Cable Trays and EN, FB, Structures Monitoring 16 Conduits SNS, SRE, Carbon Steel Air-indoor Loss of material rMor1.2-10 3.5.1-39 C SSR Program Cable d EN, FB, Galvanized A 17 Conduits SNS, SRE, Steel Air-indoor None None III.B2-5 3.5.1-58 C SSR Aging Management Review Results Page 3.5-113 January 2010 N* *
• Columbia Generating Station License Renewal Application Technical Information Table3.S.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item 8 Anchorage/Embed SNS, SRE, Galvanized . Raw water Loss of material Structures Monitoring III.A6-11 3.5.1-47 E ments SSR Steel Program Anchorage/Embed SNS, SRE, Loss of material Structures Monitoring VII.C3-7 E 9 ments SSR Stainless Steel Raw water Program 3.3.1-78 0524 111.82-8 10 SNS, SRE, Stainless Steel Air-indoor None None III.B3-5 3.5.1-59 C Cable Tie Wraps SSR III.B4-8 III.B5-5 11 Cable Tray and. SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 A Conduit Supports SSR . Program 12 . Cable Tray and SNS, SRE, Galvanized Air-indoor None None III.B2-5 3.5.1-58 A Conduit Supports SSR . Steel 13 Cable Tray and* SNS, SRE, . Carbon Steel Air-outdoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 A Conduit Supports SSR 0 Progr<;lm 14 Cable Tray and SNS, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring III.B2-7 3.5.1-50 A Conduit Supports SSR Steel Program Cable Trays and EN, FB, 15 SNS, SRE, Aluminum Air-indoor None None II I. B3-2 3.5.1-58 C Conduits SSR Cable Trays and EN, FB, Structures Monitoring 16 Conduits SNS, SRE, Carbon Steel Air-indoor Loss of material Program III.B2-10 3.5.1-39 C SSR Cable Trays and EN, FB, Galvanized 17 SNS, SRE, Air-indoor None None II I. B2-5 3.5.1-58 C Conduits SSR Steel Aging Management Review Results Page 3.5-113 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Aging Effect NUREG-1801 Row Component I intended ing Aging Management Table i No. Commodity Function' Manage nvromentReurn Program tluem2 Item Noe MaaeetItem Ie oe 18 Cable Trays and EN, FB, Srcue oioi 18 Conduits SNS, SRE, Aluminum Air-outdoor None Structures Monitoring

.12-7 3.5.1-50 CodisSNSRE Program I1B- 3.150 0525 SSR EN, FB, 19 Cable Trays and SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring II1.32-10 3.5.1-39 C Conduits SSR Program 20 Cable Trays and -SNS 'RE, Galvanizedstuurs.Mnoig 20 Ca ts aeN, FB Air-outdoor Loss of material Structures Monitoring3.5.1-50 C Conduits SSR Steel Program Component and Ill.B13.1-13 21 Piping Supports SRE, SSR Carbon Steel Air-indoor Loss of material Inservice Inspection III.B1.2-10 3.5.1-53 A (ASME Class 1, 2, Program-IWF 3 and MC) 111.B1.3-10 Component and 111.B1.1-7 Piping Supports Galvanized Air-indoor None None III.B1.2-5 3.5.1-58 A 22 (ASME Class 1, 2, SRE, SSR Steel 3 and MC) 111.B1.3-5 Component and 111.B1.1-9 23 Piping Supports SRE, SSR Stainless Steel Air-indoor None None 111.813.2-7 3.5.1-59 A 23 (ASME Class 1, 2, 3 and MC) II1.B1.3-7 Component and 24 Piping Supports SRE, SSR Carbon Steel Air-outdoor Loss of material Inservice Inspection 111.B1.2-10 3.5.1-53 A (ASME Class 1, 2, Program-IWF 3 and MC) I I I Aging Management Review Results Page 3.5-114 January 2010 Aging Management Review Results Page 3.5-114 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging.Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Cable Trays and EN, FB, Structures Monitoring I 18 Conduits SNS, SRE, Aluminum Air-outdoor None Program III.B2-7 3.5.1-50 0525 SSR Cable Trays and EN, FB, Structures Monitoring 19 SNS, SRE, Carbon Steel Air-outdoor Loss of material III.B2-10 3.5.1-39 C Conduits SSR Program . Cable Trays and ' EN, FB, Galvanized Structures Monitoring 20 SNS, SRE, Air-outdoor Loss of material II I. B2-7 3.5.1-50 C Conduits SSR Steel Program Component and III.B1.1-13 21 Piping Supports SRE, SSR Carbon Steel Air-indoor Loss of material Inservice Inspection III.B1.2-10 3.5.1-53 A (ASME Class 1, 2, Program-IWF 3 and MC) ) III.B 0 Component and III.B1.1-7 22 Piping Supports SRE, SSR Galvanized Air-indoor None None III.B1.2-5 3.5.1-58 A (ASME Class 1, 2, Steel 3 and MC) III.B1.3-5 Component and III.B1.1-9 23 Piping Supports SRE, SSR Stainless Steel Air-indoor None None III.B1.2-7 3.5.1-59 A (ASME Class 1, 2, 3 and MC) III.B1.3-7 Component and 24 Piping Supports SRE, SSR Carbon Steel Air-outdoor Loss of material Inservice Inspection III.B1.2-10 3.5.1-53 .A (ASME Class 1, 2, Program-IWF 3 and MC) Aging Management Review Results Page 3.5-114 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Aging Effect NUREG-1801 Row, Effet IAging Management Table 1mNotes No. Fnnctindd Material Environment Requiring Program V 2 Item No. Commodity Function' Management P Item T Component and 25 Piping Supports Galvanized Air-outdoor Loss of materialnservice Inspection (ASME Class 1, 2, Steel Prograi,"1-lWF 3 and MC)Component and Piping Supports SRE, SSR Carbon Steel Raw water Loss of material Inservice Inspection I.A6-11 3.5.1-47 E (ASME Class 1, 2, Program-IWF 3 and MC)Component and 27 Inservice Inspection llA-1 3514 Piping Supports SRE, SSR Galvanized Raw water Loss of material r Ie II.A6-11 3.5.1-47 E (ASME Class 1, 2, Steel Program-lWF 3 and MC) --Inservice Inspection Component and Program-IWF 28 Piping Supports SRE, SSR Carbon Steel Treated water Loss of material l1l.B1.1-11 3.5.1-49 A (ASME Class 1, 2, 3 and MC) BWR Water Chemistry Program Inservice Inspection Component and Program-IWF.

29 Piping Supports SRE, SSR Galvanized Treated water Loss of material 111.11.1-11 3.5.1-49 A (ASME Class 1, 2, Steel 3 and MC) BWR Water Chemistry ProgramInservice Inspection Component and Program-IWF 30 Piping Supports SRE, SSR Stainless Steel Treated water Loss of material I1.B1.1-11 3.5.1-49 A (ASME Class 1,2, 3 and MC) CBWR Water and MC)Chemistry Program Aging ManagementReview Results Page 3.5-115 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Component and 25 Piping Supports SRE, SSR Galvanized Air-outdoor Loss of material Inservice Inspection III.B1.2-10 3.5.1-53 A (ASME Class 1, 2, Steei PiOgiam-IVVF 3 and MC) Component and 26 Piping Supports SRE, SSR Carbon Steel Raw water Loss of material Inservice Inspection III.A6-11 3.5.1-47 E (ASME Class 1, 2, Program-IWF 3 and MC) Component and 27 Piping Supports SRE, SSR Galvanized Raw water Loss of material Inservice Inspection III.A6-11 3.5.1-47 E (ASME Class 1, 2, Steel Program-IWF 3 and MC) .. Component and Inservice Inspection Program-IWF 28 Piping Supports SRE, SSR Carbon Steel Treated water Loss of material III.B1.1-11 3.5.1-49 A (ASME Class 1, 2, 3 and MC) BWR Water Chemistry Program Component and Inservice Inspection I Program-IWF 29 Piping Supports SRE, SSR Galvanized Treated water Loss of material III.B1.1-11 3.5.1-49 A (ASME Class 1, 2, Steel 3 and MC) BWRWater Chemistry .Program -Inservice Inspection Component and Program-IWF 30 Piping Supports SRE, SSR Stainless Steel Treated water Loss of material III.B1.1-11 3.5.1-49 A (ASME Class 1, 2, 3 and MC) BWRWater Chemistry Program Aging ManagementHeview Results Page 3.5-115 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Aging Effect NUREG-1801 Table N Row Component I Intended 1 M Iaterial Environment Requiring Agn aae et Volume 2 T beI Notes No. Commodity Function Management Program Item Item 31 Damper Framing SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring amI.B2-10 3.5.1-39 A (in-wall)

SSR Program 32 Damper Framing SNS, SRE, Galvanized Air-indoor None None 111.B2-5 3.5.1-58 C (in-wall) SSR Steel Electrical and EN, SNS, Structures Monitoring 33 Instrument Panels Carbon Steel Air-indoor Loss of material Src.133-7 3.5.1-39 CM& Enclosures SRE, SSR Program Electrical and 34 Instrument Panels EN, SNS, Galvanized Air-indoor None None 1II.B3-3 3.5.1-58 C& Enclosures SRE, SSR Steel Electrical and EN, SNS, Structures Monito ring 35 Instrument Panels Carbon Steel Air-outdoor Loss of material 111.S32-10 3.5.1-39 C& Enclosures SRE, SSR Program Electrical and 36 Instrument Panels EN,Air-outdoor Loss of materialuctures Monitoring 1.B2-7 3.5.1-50 C& Enclosures SRE, SSR Steel Program 37 Electrical Bus EN, SRE, Aluminum Air-indoor None None I1.B3-2 3.5.1-58 C Ducts SSR 38 Electrical Bus EN, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring VI.A-13 3.6.1-09 A Ducts SSR Program 39 Electrical Bus EN, SRE, Galvanized Air-indoor None None 111.B3-3 3.5.1-58 C Ducts SSR Steel 40 Electrical Bus EN, SRE, Aluminum Air-outdoor None Structures Monitoring H1.B2-7 3.5.1-50 Ducts SSR Program 0525 41 Electrical Bus EN, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring VI.A-13 3.6.1-09 A Ducts SSR Program Aging Management Review Results Page 3.5-116 January 2010 Columbia Generating Station License Renewal Application Technical Information -Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Erivironment Requiring Program Volume 2 Item Notes Management Item 31 Damper Framing SNS, SRE, Carbon Steel Air-indoor Loss*of material Structures Monitoring III.B2-10 3.5.1-39 A (in-wall) SSR . Program 32 Damper Framing SNS, SRE, Galvanized Air-indoor None None III.B2-5 3.5.1-58 C (in-wall) SSR Steel Electrical and EN, SNS, Structures Monitoring 33 Instrument Panels Carbon Steel Air-indoor Loss of material II I. B3-7 3.5.1-39 C* & Enclosures SRE, SSR Program Electrical and EN, SNS, Galvanized 34 Instrument Panels SRE, SSR Steel Air-indoor None None " III.B3-3 3.5.1-58 C & Enclosures Electrical and EN, SNS, Structures Monitoring 35 Instrument Panels Carbon Steel Air-outdoor Loss of material II I. B2-10 3.5.1-39 C & Enclosures SRE, SSR Program Electrical and EN,SNS, Galvanized Structures Monitoring 36 Instrument Panels Air-outdoor Loss of material II I. B2-7 3.5.1-50 C & Enclosures SRE, SSR Steel Program 37 Electrical Bus EN, SRE, Aluminum Air-indoor None None 3.5.1-58 C Ducts SSR 38 Electrical Bus EN, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring VI.A-13 3.6.1-09 A. Ducts SSR Program 39 Electrical Bus EN, SRE, Galvanized Air-indoor None None II I. B3-3 3.5.1-58 C Ducts SSR Steel 40 Electrical Bus EN, SRE, Aluminum Air-outdoor None Structures Monitoring III.B2-7 3.5.1-50 I Ducts SSR Program 0525 41 Electrical Bus EN, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring VI.A-13 3.6.1-09 A Ducts SSR Program Aging Management Review Results Page.3.5-116 January 2010 . * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities NUREG-1 8011Tbl Aging Effect Aging Management Volume 2 Item Row Component y Intended Material Environment Requiring P Table I Notes No. Commodity Function 1 " Management Program Item 42 Electrical Bus EN, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring VI.A-13 3.6.1-09 A Ducts SSR Steel Program llI.B2-10E q u ip m e n t S N S , S R E , S tru ct u re M o i o i gA1.3 -43 Component Carbon Steel Air-indoor Loss of ma Structures Monitoring IIA.B3-7 S4Cpports SSR Program 1II.B4-10 I11.B5-7 I11.B2-5 Equipment SNS ,Glvnze 1.133-3 44 Component SNS, SRE, Galvanized Air-indoor None None 3.5.1-58 A Sopornts SSR Steel III.B4-5 Supports I11.B5-3 II1.B2-8 Equipment SNS, SRE, II1.133-5 45 Component SSR Stainless Steel Air-indoor None None 3.5.1-59 A Supports SSR 1.B4-8 I11.B5-5 ill.B2-10 Equipment SNS, SRE, Ct Structures Monitoring 1A.13-7 46 Component SSR Carbon Steel Air-outdoor Loss of materia Preora I.B3-Supports Program II1.B4-10* ' II1B5-7 Equipment SNS, SRE, Galvanized Structures Monitoring I1.B2-7 3.5.1-50 A 47 Component SSRAir-outdoor Loss of material P .B4-7 Supports Equipment SNS, SRE, Structures Monitoring I1.B2-7 1 48 Component Stainless Steel Air-outdoor None 3.5.1-50 Supports SSR Program II.B4-7 0525 Aging Management Review Results Page 3.5-117 January 2010* *
• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function' Material Environment Requiring Program Volume 2 Item Notes Management

-Item 42 Electrical 8us EN, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring VI.A-13 3.6.1-09 A Ducts SSR Steel Program 111.82-10 Equipment SNS, SRE, Structures Monitoring 111.83-7 43 Component Carbon Steel Air-indoor Loss of material 3.5.1-39 A Supports SSR Program 111.84-10 111.85-7 111.82-5 Equipment SNS, SRE, Galvanized 111.83-3 44 Component Air-indoor None None 3.5.1-58 A Supports SSR Steel 111.84-5 111.85-3 111.82-8 Equipment SNS, SRE, 111.83-5 45 Component SSR Stainless Steel Air-indoor None None 3.5.1-59 A Supports 111.84-8 111.85-5 111.82-10 Equipment SNS, SRE, Structures Monitoring 111.83-7 46 Component Carbon Steel Air-outdoor Loss of material 3.5.1-39 A Supports SSR Program 111.84-10 111.85-7 Equipment SNS, SRE, Galvanized Structures Monitoring 111.82-7 47 Component Air-outdoor Loss of material 3.5.1-50 A Supports SSR Steel Program 111.84-7 Equipment SNS, SRE, Structures Monitoring 111.82-7 I 48 Component Stainless Steel Air-outdoor None 3.5.1-50 Supports SSR Program 111.84-7 0525 Aging Management Review Results Page 3.5-117 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row ComponentAging Effect Aging Management NUREG-1801 Table I No. Commodity Functioni Material Environment Requiring Program Volume 2 Item j Management Item III.1B2-10 Structures Monitoring III.B3-7 49 Flood Curbs FLB, SNS Carbon Steel Air-indoor Loss of material Program III.14-10 3.5.1-39 C IlI.1B5-7 Flood, Pressur'e, FLB, MB, 50 and Specialty P1, SHD Carbon Steel. Air-indoor Loss of material Structures Monitoring III.B4-10 3.5.1-39 C 50 aDoospiat SNS, SRE, "Program DoorsSR SSR Flood, Pressure, FLB, MB3, 51 and Specialty PB3, SHR, Galvanized Air-indoor None None III.B4-5 3.5.1-58 C DorsSNS, SRE, Steel DoorsSR SSR Flood, Pressure, FLB, MB, Fod pes , PB, SHD, Carbon Steel Air-outdoor Loss of material StructuresMonitoring III.B4-10 3.5.1-39 C 52 and Specialty SNS, SRE, Program DoorsSR SSR Flood, Pressure, FLB, MB, PB, SHD, Galvanized Air-outdoor Loss of material r Monitoring 53 and Specialty SNS, SRE, Steel Strutr Program lll.B4-7 3.5.1-50 C Doors SSR EN, FB, FLB, 54 Hatches M1N, PR, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B4-10 3.5.1-39 C SNS, SRP , Program SSR Aging Management Review Results Page 3.5-118 January 2010 Aging Management Review Results Page 3.5-118 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging'Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item III.B2-10 , Structures Monitoring II I. B3-7 -49 Flood Curbs FLB, SNS Carbon Steel Air-indoor Loss of material 3.5.1-39 C Program III.B4-10 II I. B5-7 Flood, Pressure, FLB, MB, PB, SHD, Structures Monitoring 50 and Specialty SNS, SRE, Carbon Steel Air-indoor Loss of material Program III.B4-10 3.5.1-39 C Doors SSR Flood, Pressure, FLB, MB, 51 and Specialty PB, SHD, Galvanized Air-indoor None None III.B4-5 3.5.1-58 C SNS, SRE, Steel Doors SSR Flood, Pressure, FLB, MB, PB, SHD, Structures Monitoring , 52 and Specialty SNS, SRE, Carbon Steel Air-outdoor Loss of material Program II I. B4-1 0 3.5.1-39 C Doors SSR Flood, Pressure, FLB, MB, ", 53 and Specialty PB, SHD, Galvanized Air-outdoor Loss of material Structures Monitoring II I. B4-7 3.5.1-50 C Doors SNS, SRE, Steel Program SSR EN, FB, FLB, 54 "Hatches MB, PB, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B4-10 3.5.1-39 C -SNS, SRE, Program SSR Aging Management Review Results Page 3.5-118 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component!

Intended tAging Effect Aging Management NUREG-1801 Table I Notes No. Commodity Functiond Material Environment Requiring Program Volume 2 Item No. Comodiy FnctonIManagement Item lEN, FB, FLB, 55 Hatches MB, PB, Galvanized Air-indoor None None IlI.B4-5 3.5.1-58 C SNS, SRE, Steel SSR EN, FB, FLB, 56 Hatches MB, PB, Carbon Steel Air-outdoor Loss of material Structures Monitoring III.B4-10 3.5.1-39 C SNS, SRE, Program SSR EN, FB, FLB, 57 Hatches MB, PB, Galvanized Air-outdoor Loss of material Structures Monitoring I13.B4-7 3.5.1-50 C SNS, SRE, Steel Program SSR HELB Barriers (includes pipe restraints, whip restraints, and HELB, PW, -indoor -2 3.5.1-58 C 58 Auiu AiNoeNone lll.B5-2 3515 jet/missile SNS, SSR impingement shields/plate barriers)HELB Barriers (includes pipe restraints, whip 59 restraints, and HELB, PW, Carbon Steel Air-indoor Loss of material Structures Monitoring II1.B5-7 3.5.1-39 C jet/missile SNS, SSR Program impingement shields/plate barriers)Aging Management Review Results Page 3.5-119 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item EN, FB, FLB, 55 Hatches MB, PB, Galvanized Air-indoor None None II I. B4-5 3.5.1-58 C SNS, SRE, Steei SSR EN, FB, FLB, 56 Hatches MB, PB, Carbon Steel Air-outdoor Loss of material Structures Monitoring II I. B4-1 0 3.5.1-39 C SNS, SRE, " Program SSR EN, FB, FLB, 57 Hatches MB, PB, Galvanized Air-outdoor Loss of material Structures Monitoring III.B4-7 3.5.1-50 C SNS, SRE, Steel Program SSR HELB Barriers (includes pipe restraints, whip 58 restraints, and HELB, PW, Aluminum Air-indoor None None III.B5-2 3.5.1-58 C jeUmissile SNS,SSR impingement shields/plate barriers)

HELB Barriers (includes pipe restraints, whip . -" 59 restraints, and HELB, PW, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B5-7 3.5.1-39 C jeUmissile SNS, SSR Program impingement shields/plate . barriers) Aging Management Review Results Page 3.5-119 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component Intended Material Environment A Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Requiring Program Volume 2 Item Notes Management Item HELB Barriers (includes pipe restraints, whip 60 restraints, and HELB, PW, Galvanized Air-indoor None None III.B5-3 3.5.1-58 C jet/missile SNS, SSR Steel impingement shields/plate barriers)HELB Barriers (includes pipe restraints, whip 61 restraints, and HELB, PW, None ll.B5-5 3.5.1-59 C jet/missile SNS, SSR Stainless Steel Air-indoor None impingement shields/plate barriers)HELB Barriers (includes pipe Structures Monitoring restraints, whip Program E restraints, and HELB, PW, Stainless Steel Treated water Loss of material III.B13.1-11 3.5.1-49 62 jet/missile SNS, SSR 0534 impingement BWR Water shields/plate Chemistry Program barriers)63, HVAC Duct SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring amI.B2-10 3.5.1-39 A Supports SSR Program 64 HVAC Duct SNS, SRE, -Galvanized Air-indoor None None II1.B2-5 3.5.1-58 A Supports SSR Steel Aging Management Review Results Page 3.5-120 January 2010 0 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item HELB Barriers (includes pipe restraints, whip 60 restraints, and HELB, PW, Galvanized Air-indoor None None II I. B5-3 3.5.1-58 .C jeUmissile SNS, SSR Steel impingement shields/plate barriers) . HELB Barriers (includes pipe restraints, whip 61 restraints, and HELB, PW, Stainless Steel Air-indoor None None III.B5-5 3.5.1-59 C jeUmissile SNS, SSR i!llpingement shields/plate barriers) \ HELB Barriers (includes pipe Structures Monitoring restraints, whip Program restraints, and HELB, PW, E 62 Stainless Steel Treated water Loss of material III.B1.1-11 3.5.1-49 jeUmissile SNS, SSR. 0534 impingement BWRWater shields/plate Chemistry Program barriers) 63 HVAC Duct SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 A Supports SSR Program 64 HVAC Duct SNS, SRE, *Galvanized Air-indoor None None III.B2-5 3.5.1-58 A Supports SSR Steel Aging Management Review Results Page 3.5-120 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities mponentAging Effect Aging Management NURE Table I No. Commodit Function' Material Environment Requiring

.Program Volume2 Item No._CommodityFunction__Management Item} HVAC:Duct SNS, SRE, 65 Supports SSR Stainless Steel Air-indoor None None I11.B2-8 3.5.1-59 A 66 Instrument Line SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 A Supports SSR Program 67 Instrument Line SNS, SRE, Galvanized Air-indoor None None 111.B2-5 3.5.1-58 A Supports SSR Steel AN1-68 Instrument Line SNS, SRE, Stainless Steel Air-indoor None None 111.B2-8 3.5.1-59 A Supports SSR 69 Instrument Line SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring II.B2-10 3.5.1-39 A Supports SSR Program 70 Instrument Line SNS, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring 111.B2-7 3.5.1-50 A Supports SSR Steel Program 71 Instrument Line SNS, SRE, Stainless Steel Air-outdoor -None Structures Monitoring 111.B2-7 3.5.1-50 1 Supports SSR Program 0525 72 Instrument Racks SNS, SRE, Carbon Steel Air-indoor Lossof material Structures Monitoring 111.83-7 3.5.1-39 C and Frames SSR Program 73 Instrument Racks SNS, SRE, Galvanized Air-indoor None None 111.B3-3 3.5.1-58 C and Frames SSR Steel 74 Instrument Racks SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring 1II.B3-7 3.5.1-39 C and Frames SSR Program 75 Instrument Racks SNS, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring 111.B2-7 3.5.1-50 C and Frames SSR Steel Program Monorails, Hoists 76 and Miscellaneous SNS Carbon Steel Air-indoor Loss of material Structures Monitoring 11185-7 3.5.1-39 A Cranes Program Aging Management Review Results Page 3.5-121 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item 65 HVAC DuCt SNS, SRE, Stainless Steel Air-indoor None None II I. B2-8 3.5.1-59 A Supports SSR 66 Instrument Line SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 A Supports SSR Program 67 Instrument Line SNS, SRE, Galvanized Air-indoor . None None III.B2-5 3.5.1-58 A Supports SSR Steel 68 Instrument Line SNS, SRE, Stainless Steel Air-indoor None None III.B2-8 3.5.1-59 A Supports SSR 69 Instrument Line SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 A Supports SSR Program* 70 Instrument Line SNS, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring II I. B2-7 3.5.1-50 A Supports SSR Steel Program 71 Instrument Line SNS, SRE, Stainless Steel Air-outdoor

-None Structures Monitoring II I. B2-7 3.5.1-50 I Supports SSR Program 0525 72 Instrument Racks SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring II I. B3-7 3.5.1-39 C and Frames SSR Program 73 Instrument Racks SNS, SRE, Galvanized Air-indoor None None III.B3-3 3.5.1-58 C and Frames SSR Steel 74 Instrument Racks SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring III.B3-7 *3.5.1-39 C and Frames SSR Program 75 Instrument Racks SNS, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring III.B2-7 3.5.1-50 C and Frames SSR Steel Program Monorails, Hoists , 76 and Miscellaneous SNS Carbon Steel Air-indoor Loss of material Structures Monitoring III.B5-7 3.5.1-39 A Cranes Program Aging Management Review Results Page 3.5-121 . January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component / Intended Material Environment Requiring AgingVolume 2 Table INotes No. Commodity Function 1 M Program Volm Item Management Item Penetrations (Mechanical and EN, FB, FLB, 77 Electrical, non PB, SNS, Carbon Steel Air-indoor Loss of material Structures Monitoring 1.B2-10 3.5.1-39 C primary SRE, SSR Program containment. boundary)78. Pipe Supports SNS, SRE, arbon Steel Air-indoor Loss of material Structures Monitoring I1.B2-10 3.5.1-39 A SSR Program 1I1.B4-10 SNS, SRE, Galvanized 111.132-5 79 Pipe Supports SSR Steel Air-indoor None None III.B4-5 3.5.1-58 A 80 Pipe Supports SNS, SRE, Stainless Steel Air-indoor None None Ill.1B2-8 3.5.1-59 A SSR II1.B4-8 SNS, SRE, Structures Monitoring 111.132-10 81 Pipe Supports SSR Carbon Steel Air-outdoor Loss of material Program III.B2-10 3.5.1-39 A 81SSR Program lI1.B4-10 82 Pipe Supports SNS, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring III.B2-7 351-50 A SSR Steel Program 111.B4-7 SNS, SRE, Structures Monitoring 111.82-7 83 Pipe Supports SSR Stainless Steel Air-outdoor None Program l1l.14-7 3.5.1-50 0525 84 Pipe Supports SNS, SRE, Carbon Steel Raw water Loss of material Structures Monitoring II1.A6-11 3.5.1-47 E SSR Program 85 Pipe Supports SNS, SRE, Galvanized Raw water Loss of material Structures Monitoring III.A6-11 3.5.1-47 E'SSR Steel Program SNS, SREStructures MonitoringE 86 Pipe Supports SNS, SRE, Stainless Steel Raw water Loss of material S ronrin VII.C3-7 3.3.1-78 E SSR Program 0524 Aging Management Review Results Page 3.5-122 January 2010 0 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Penetrations (Mechanical and EN, FB, FLB, 77 Electrical, non PB, SNS, Carbon Steel Air-indoor Loss of material Structures Monitoring II I. B2-1 0 3.5.1-39 C primary SRE, SSR Program containment boundary) 78 Pipe Supports SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 A SSR Program III.B4-10 79 Pipe Supports *SNS, SRE, Galvanized Air-indoor None None r II I. B2-5 3.5.1-58 . SSR Steel III.B4-5 A 80 Pipe Supports SNS; SRE, Stainless Steel Air-indoor None None III.B2-8 3.5.1-59 SSR III.B4-8 A 81 Pipe Supports SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 A SSR Program III.B4-10 82 Pipe Supports SNS, SRE, Galvanized Air -outdoor Loss of material Structures Monitoring III.B2-7 3.5.1-50 A SSR Steel Program II I. B4-7 83 Pipe Supports SNS, SRE, Stainless Steel Air-outdoor None Structures Monitoring II I. B2-7 3.5.1-50 I SSR Program III.B4-7 0525 84 Pipe Supports SNS, SRE, Carbon Steel Raw water Loss of material Structures Monitoring III.A6-11 3.5:1-47 E; SSR Program 85 Pipe Supports SNS, SRE, Galvanized Raw water Loss of material Structures Monitoring III.A6-11 3.5.1-47 E' SSR Steel . Program 86 Pipe Supports SNS, SRE, Stainless Steel . Raw water Loss of material Structures Monitoring VII.C3-7 3.3.1-78 E SSR Program . 0524 Aging Management Review Results Page 3.5-122 . January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk CommoditiesAging Effect NUE-10 Row Component/

Intended MAging Management Effect1 Table I N FucIon Material Environment Requiring Agn aaeetVolume 2 INotes No. Commodity Suciotrogtramese Management PrgmItem Ie I Structures Monitoring SiProgram 87 Pipe Supports SSR Carbon Steel Treated water Loss of material Pr.ogr.1-1m 3.5.1-49 E BWR Water Chemistry Program Structures Monitoring Program 88 Pipe Supports SSR Stainless Steel Treated water Loss of material III.B1.1-11 3.5.1-49 E"BWR Water Chemistry Program Stair, Ladder, 89 Platform, and SNS, SRE Carbon Steel Air-indoor Loss of material Structures Monitoring I1.B5-7 3.5.1-39 A Grating Supports Program Stair, Ladder, Galvanized 90 Platform, and SNS, SRE Stee Air-indoor None None I1.B5-3 3.5.1-58 A Grating Supports Steel Stair, Ladder, Structures Monitoring 91 Platform, and SNS, SRE Carbon Steel Air-outdoor Loss of material Program1.5-7 3.5.1-39 A Grating Supports Program Stair, Ladder, Galvanized Stru 92 Platform, and SNS, SRE Steel Air-outdoor Loss of material Pcture Monitoring III.B2-7 3.5.1-50 A Grating Supports Stairs, Ladders, 93 Platforms, and SNS, SRE Aluminum Air-indoor None None 111.B5-2 3.5.1-58 C Gratings Aging Management Review Results Page 3.5-123 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information

/ Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended "\ Material Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Environment Requiring Progra.m Volume 2 Item Notes Management Item Structures Monitoring SNS, SRE, Program / 87 Pipe Supports Treated water Loss of material iii.Bl.l-l*1 3.5.1-49 r-SSR c 8WRWater Chemistry Program Structures Monitoring SNS, SRE, Program 88 Pipe Supports SSR Stainless Steel Treated water Loss of material 111.81.1-11 3.5.1-49 E 8WRWater Chemistry Program . Stair, Ladder, Structures Monitoring 89 Platform, and SNS, SRE Carbon Steel Air-indoor Loss of m.aterial 111.85-7 3.5.1-39 A Grating Supports Program ) Stair, Ladder, Galvanized 90 Platform, and SNS, SRE Steel Air-indoor None None 111.85-3 3.5.1-58 A Grating Supports Stair, Ladder, , Structures Monitoring 91 Platform, and SNS, SRE Carbon Steel Air-outdoor Loss of material 111.85-7 3.5.1-39 A Grating Supports Program Stair, Ladder, Galvanized Structures Monitoring 92 Platform, and SNS, SRE Steel Air-outdoor Loss of material Program 111.82-7 3.5.1-50 A Grating Supports Stairs, Ladders, 93 Platforms, and SNS, SRE r Aluminum Air-indoor None None 111.85-2 3.5.1-58 C Gratings Aging Management Review Results Page 3.5-123 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component! intended Aging Effect NUREG-1801 'Row~~~~~~~ ~ ~ ~ Copnn nedd Mtral EvrnetRqiig Aging Management Volume 2 Ta It Nte No. Commodity Function 1 Material Environment agRequiring Program Item Table i Notes Stairs, Ladders, Structures Monitorin 94 Platforms, and SNS, SRE Carbon Steel Air-indoor Loss of material Program III.B5-7 3.5.1-39 C GratingsStairs, Ladders, Galvanized 95 Platforms, and SNS, SRE Gal Air-indoor None None 11.B5-3 3.5.1-58 C Gratings Steel Stairs, Ladders, Structures Monitoring 3 96 Platforms, and SNS, SRE Aluminum Air-outdoor None Program 1.B4-7 3.5.1-50 525 Gratings Stairs, Ladders,97 Platforms, and SNS, SRE Carbon Steel Air-outdoor Loss of material Structures Monitoring Ill1.B5-7 3.5.1-39 C Gratings Stairs, Ladders, G laie tutrsM ntrn 98 Platforms, andd S N Galvanized Air-outdoor Loss of material Structures Monitoring 1.B2-7 3.5.1-50 C Gratings Steel Program 99 Tube Track SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring am1.B2-10 3.5.1-39 A Supports SSR Program Tube Track SNS, SRE, Galvanized 100 Supports SSR Steel Air-indoor None None 11l.12-5 3.5.1-58 A 101 Tube Track SNS, SRE, Carbon Steel Air-outdoor Loss of materialStructures Monitoring am1.12-10 3.5.1-39 A Supports SSR Program 102 Tube Track SNS, SRE, .Galvanized Air-outdoor Loss of material Structures Monitoring I1.B2-7 3.5.1-50 A Supports SSR Steel Program 103 Tube Tracks SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring I11.B2-10 3.5.1-39 C SSR Program I Aging Management Review Results Page 3.5-124 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 ,Item Notes Management Item Stairs, Ladders, Structures Monitoring 94 Platforms, and SNS, SRE Carbon Steel Air-indoor Loss of material III.B5-7 3.5.1-39 C Gratings Program Stairs, Ladders, Galvanized 95 Platforms, and SNS,SRE Steel Air-indoor None None II I. B5-3 3.5.1-58 C Gratings Stairs, Ladders, Structures Monitoring I 96 Platforms, and . SNS,SRE Aluminum Air-outdoor None II I. B4-7 3.5.1-50* Gratings Program 0525 . Stairs, Ladders, Structures Monitoring 97 Platforms, and SNS, SRE Carbon Steel Air-outdoor Loss of material III.B5-7 3.5.1-39 C Gratings Program Stairs,"Ladders, Galvanized Structures Monitoring 98 Platforms, and SNS, SRE Air-outdoor Loss of material II I. B2-7 3.5.1-50 C Gratings Steel Program 99 Tube Track SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 A Supports SSR Program 100 Tube Track SNS, SRE, Galvanized Air-indoor None None III.B2-5 3.5.1-58 A Supports SSR Steel 101 Tube Track SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring II I. B2-10 3.5.1-39 A Supports SSR Program 102 Tube Track SNS, SRE, . Galvanized Air-outdoor Loss of material Structures Monitoring III.B2-7 3.5.1-50 A Supports SSR Steel Program 103 Tube Tracks SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 C SSR Program. Aging Management Review Results Page 3.5-124 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities R omponent Intended Aging Effect Aging Management NUREG-1801 Table I F/nctiond Material Environment Requiring Volume 2 Te Notes Maaeet Program Item No. Commodity Function' Management PormItem Ie 104 Tub sSSR Carbon Stee T T Air-outdoor Loss of material Structures Monitoring IIL.B2-10 3.5.1-39 C S-R -Program 105 Vents and Louvers SNS, SRE, Aluminum Air-indoor None None I1.B2-4 3.5.1-58 C SSR 106 Vents and Louvers SNS, SRE Carbon Steel Air-indor Loss of material Structures Monitoring 1.B2-10 3.5.1-39 C SSR Program 107 Vents and Louvers SNS, SRE, Galvanized Air-indoor None None II.B21-5 3.5.1-58 C SSR Steel 108 Vents and Louvers SNS, SRE Stainless Steel Air-indoor None None II1.B2-8 3.5.1-59 C SSR 1109 Vents and Louvers CaroAluminum Air-outdoor None Structures Monitoring III.B2-7 3.5.1-50 C SSR Program 0525 110 Vents and Louvers SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 C SSR SeProgram 111 Vents and Louvers SNS, SRE, Galvanized Air-outdoor Lo ss of material Structures Monitoring 11127 3515 SSR Steel ProgramII.27 3510 C SNSStructures Monitoring 112 Vents and Louvers Stainless Steel Air-outdoor None In II.B2-7 3.5.1-50 SSR Program 0525 Threaded Fasteners Ill.B2-10 113 Anchor Bolts SNS, SRE, Carbon Steel Air-indoor Loss of materialuctures Monitoring

.3-7 3.5.1-39 A SSR Program I11.B4-10 I II.B5-7 Aging Management Review Results Page 3.5-125 January 2010*

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item 104 Tube Tracks SNS, SRE, Carbon Steel Air;-outdoor Loss of, material Structures Monitoring III.B2-10 3.5.1-39 C , SSR Program 105 Vents and Louvers SNS, SRE, Aluminum Air-indoor None None III.B2-4*

3.5.1-58 C SSR 106 Vents and Louvers SNS, SRE, Carbon Steel Air-indoor. Loss of material Structures Monitoring III.B2-10 3.5.1-39 C SSR . Program 107 Vents and Louvers SNS, SRE, Galvanized Air-indoor None None 3.5.1-58 C SSR Steel 108 Vents and Louvers SNS, SRE, Stainless Steel Air-indoor None None III.B2-8 3.5.1-59 C SSR 109 Vents and Louvers SNS, SRE, Aluminum Air-outdoor None Structures Monitoring III.B2-7 3.5.1-50 I SSR Program 0525 110 Vents and Louvers SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring III.B2-10 3.5.1-39 C SSR .. Program 111 Vents.and Louvers SNS, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring III.B2-7 3.5.1-50 C SSR Steel Program* 112 Vents and Louvers SNS, SRE, Stainless Steel None Structures Monitoring III.B2-7 3.5.1-50 I Air-outdoor SSR Program . 0525 Threaded Fasteners III.B2-10 113 Anchor Bolts SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring III.B3-7 3.5.1-39 A SSR Program III.B4-10 III.B5-7 Aging Management Review Results Page 3.5-125 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities NUREG-1801 Ta Nte Row Component / Intended Materia Managemment Tablerin No. Commodity Function' Material Environment Requiring Program Volume 2 Item N Management Item Ill.1B2-5 114 Anchor Bolts SNS, SRE, Galvanized Air-indoor None None II1.B3-3 3.5.1-58 A SSR Steel III.B4-5 I11.1B5-3 11I.B2-8 SNS, SRE, Ill.133-5 115 Anchor Bolts SSR Stainless Steel Air-indoor None None III.13-8 3.5.1-59 A SSR Ill. B4-8 Il1.1B5-5 II1.1B2-10 116 Anchor Bolts SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring I1.B3-7 3.5.1-39 A SSR Program III.B4-10 Il1.1B5-7 117 Anchor Bolts SNS, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring I1.B2-7 3.5.1-50 A SSR Steel Program II1.B4-7 118 Anchor Bolts SNS, SRE, StainIess Steel Air-outdoor None Structures Monitoring I1.B2-7 3.5.1-50 1 SSR Program 11.B4-7 0525 119 Anchor Bolts SNS, SRE, Carbon Steel Raw water Loss of material Structures Monitoring III.A6-11 3.5.1-47 E SSR Program 120 Anchor Bolts SNS, SRE, Galvanized Raw water Loss of material Structures Monitoring II1.A6-11 3.5.1-47 E SSR Steel Program SNS, SRE, Structures Monitoring VI.E 121 Anchor Bolts SS, S ,Stainless Steel Raw water Loss of material rormVII.C3-7 3.3.1-78 E SSR Program 0524 Aging Management Review Results Page 3.5-126 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item II I. B2-5 , SNS, SRE, Galvanized II I. B3-3 114 Anchor Bolts SSR Steel Air-indoor None None III.B4-5 3.5.1-58 A .. , II I. B5-3 -. II I. B2-8 Anchor Bolts SNS, SRE, Stainless Steel Air-indoor None None II I. B3-5 3.5.1-59 A 115 SSR II I. B4-8 III.B5-5 III.B2-10 Anchor Bolts SNS, SRE, Carbon Steel Air-outdoor Loss of material Structures Monitoring II I. B3-7 3.5.1-39 A 116 SSR Program II I. B4-1 0 II I. B5-7 Anchor Bolts SNS, SRE, Galvanized Air-outdoor Loss of material Structures Monitoring III.B2-7 3.5.1-50 A 117 SSR Steel Program II I. B4-7 SNS, SRE, Stainless Steel Air-outdoor Structures Monitoring III.B2.:.7 3.5.1-50 I 118 Anchor Bolts SSR None Program III.B4-7 0525 119 Anchor Bolts SNS, SRE, Carbon Steel Raw water Loss of material Structures Monitoring III.A6-11 3.5.1-47 'E SSR Program 120 Anchor Bolts SNS,SRE, Galvanized Raw water Loss of material Structures Monitoring III.A6-11 3.5.1-47 E SSR Steel Program SNS, SRE, Stainless Steel Loss of material Structures Monitoring E 121 Anchor Bolts SSR Raw water Program VII.C3-7 3.3.1-78 0524 Aging Management Review Results Page 3.5-126 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-13 Aging Management ReviewResults

-Bulk Commodities Row. Component I Intended Environment e Aging Management NUREG-1801 Table I No. Commodity Function M Management Program Volumem2 Item Anchor Bolts III.B1.1-13 !2 (ASME Class 1, 2,I Insec iIIB.-1n..15 122 a MC SRE, SSR Carbon Steel Air-indoor Loss of material Inservice Inspection3.5.1-53 A 3 and MC 0Program-lI IW-Supports Bolting) ll.B13.3-10 Anchor Bolts. II1.B1.1-7 123 (ASME Class 1, 2, SRE, SSR Galvanized Air-indoor None None I1.B1.2-5 3.5.1-58 A 3 and MC Steel Supports Bolting) I1.B13.3-5 Anchor Bolts II1.B1.1-9 124 (ASME Class 1, 2, SRE, SSR Stainless Steel Air-indoor None None II1.B1.2-7 3.5.1-59 A 3 and MC Supports Bolting) III.1B1.3-7 Anchor Bolts (ASME Class 1, 2, Inservice Inspection Ill.B1.2-10 3.5.1-53 A 125 3 and MC SRE, SSR Carbon Steel Air-outdoor Loss of material Program-IWF Supports Bolting)Anchor Bolts 126 (ASME Class 1,2, SRE, SSR Galvanized Air-outdoor Loss of material Inservice Inspection 1113B1.2-10 3.5.1-53 E 3 and MC Steel Program-IWF Supports Bolting)Anchor Bolts 127 n Class 1, 2 SRE, SSR Carbon Steel Raw water Loss of material Inservice Inspection Il.A6-11 3.5.1-47 E 3a Program-aWF Supports Bolting)Anchor Bolts (ASME.Class 1, 2, SRSR Galvanized nevc np o 128 3 and MC SRE SSR Steel Raw water Loss of material Inservice Inspection I.A6-11 3.5.1-47 E 3randaMCtS teelAPr1iram ____Supports Bolting) _____ ______________ Aging Management Review Results Page 3.5-127 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review'Results

-Bulk Commodities Row Component! Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Anchor Bolts III.B1.1-13 122 (ASME Class 1, 2, SRE, SSR Carbon Steel . Air-indoor Loss of material Inservice Inspection III.B1.2-10 3.5.1-53 A 3 andMC . PiOgiam-IVVF Supports Bolting) III.B 1.3-10 Anchor Bolts , III.B1.1-7 123 (ASME Class 1, 2, SRE, SSR Galvanized Air-indoor None None III.B1.2-5 3.5.1-58 A 3 and MC Steel Supports Bolting) III.B1.3-5 Anchor Bolts III.B1.1-9 124 (ASME Class 1, 2, SRE, SSR Stainless Steel Air-indoor None None III.B1.2-7 3.5.1-59 A 3 and MC Supports Bolting) , III.B1.3-7 Anchor Bolts 125 (ASME Class 1, 2, SRE, SSR Carbon Steel . Air-outdoor Loss of material lriservice Inspection III.B 1.2-10 3.5.1-53 A 3 and MC Program-IWF Supports Bolting). Anchor Bolts -" 126 (ASME Class 1, 2, SRE, SSR Galvanized Air-outdoor Loss of material Inservice Inspection III.B1.2-10 3.5.1-53 E 3 and MC Steel Program-IWF Supports Bolting) Anchor Bolts 127 (ASME Class 1, 2, SRE, SSR Carbon Steel Raw water Loss of material Inservice Inspection III.A6-11 3.5.1-47 E 3 and MC Program-IWF Supports ,Bolting) f Anchor Bolts 128 (ASMEClass 1, 2, SRE, SSR Galvanized Raw water Loss of material Inservice Inspection III.A6-11 3.5.1-47 E 3 and MC Steel Program-IWF Supports Bolting) Aging Management Review Results Page 3.5-127 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row T Component/I Intended Aging Effect Aging Management NUREG-1801 No. Commodity FunctionI Material Environment Requiring Program Volume 2 Table 1 Notes Management Item Anchor Bolts Inservice Inspection Program-IWF 129 (ASME Class 1, 2, SRE, SSR Carbon Steel Treated water Loss of material 1I1.B1.1-11 3.5.1-49 A 3 and MC Supports Bolting) BWR Water Chemistry Program Inservice Inspection Anchor Bolts Program-lWF 130 (ASME Class 1,2, SRE, SSR Stainless Steel Treated water Loss of material III.B1.1-11 3.5.1-49 A 3 and MC Supports Bolting) BWR Water___Chemistry Program II1.1B2-10 131 Expancion SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring 1.B3-7 3.5.1-39 A Anchors SSR Program II1.B4-10 III.1B5-7 II1.B2-5 132 Expansion SNS, SRE, Galvanized Air-indoor None None .II1.B3-3 3.5.1-58 A Anchors SSR Steel II.B4-5 III.1B5-3 II1.1B2-8133 Expansion SNS, SRE, Stainless Steel Air-indoor None None III.B3-5 3.5.1-59 A Anchors SSR II1.B418 II1.B5-5 Aging Management Review Results Page 3.5-1 28 January 2010 Aging Management Review Results Page 3.5-128 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring , Program Volume 2 Item Notes Management Item Anchor Bolts Inservice Inspection Program-IWF 129 (ASME Class 1, 2, SRE, SSR Carbon Steel Treated water Loss of material III.B1.1-11 3.5.1-49 A 3 and MC Supports Bolting) BWR Water Chemistry Program -Anchor Bolts Inservice Inspection 130 (ASME Class 1, 2, SRE, SSR Stainless Steel Treated water Loss of material III.B1.1-11 3.5.1-49 A 3 and MC Supports Bolting) BWRWater . Chemistry Program III.B2-10 Expansion SNS, SRE, Carbon Steel Air-indoor Loss of material Structures Monitoring II I. B3-7 3.5.1-39 A 131 Anchors SSR Program II I. B4-1 0 III.B5.,7 III.B2-5 132 Expansion SNS, SRE, Galvanized Air-indoor None None III.B3-3 3.5.1-58 A Anchors SSR Steel . II I. B4-5 II I. B5-3 III.B2-8 133 Expansion SNS, SRE, Stainless Steel Air-indoor None None III.B3-5 3.5.1-59 A Anchors SSR III.B4-8 II I. B5-5 Aging Management Review Results Page 3.5-128 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities 1 Aging Effect ging Management NUREG-1801 Table IN Row Component

/ Intended Mtra niomn eurn No Commodity Function Material Environment Requiring m Volume 2 Item Notes Management Program Item 11I.132-110 Exaso NSRSrcue Monitoring 11.3-K 1 l1.135-7 134 Expansion SNS. SRE. Garbonized Air-outdoor Loss of ma l Structures III.132-7 3 A Anchors SSR Program 111.B4-10 III.B5-7 135sinSSSR Structures Monitoring 111.132-7 31515 Expansion SNS, SRE, Galvanized Air-outdoor Loss of material PtutreMog itram g III.B2-7 3515 Anchors SSR Steel Program II1.B4-7 136 Expansion SNS, SRESanesSelArotor Ne Structures Monitoring II1.B2-7 3.5.1-50 052 Anchors .SSR -,SanestelArodor Ne Program lII.B4-7 02 137 Expansion SNS, SRE, Carbon Steel Raw water Loss of material Structures Monitoring Ill.A6-11 3.5.1-47 E Anchors SSR Program 138 Expansion SNS, SRE, Galvanized Raw water Loss of material Structures Monitoring IIa.A6-11 3.5.1-47 E Anchors SSR Steel Program StainionlessSIR Structures MonitoringE 139 Expansion SNS, SRE tainless Steel Raw water Loss of material VII.C3-7 3.3.1-78 Anchors SSR Program 0524 Concrete Cracking 140 Equipment Pads SNS, SRE, Concrete Air-indoor C Structures Monitoring H SSR Change in Program N/A N/A 0521 material properties SNS, SIRE, Ct AtStructures Monitoring N 141 Equipment Pads SSR Concrete Air-outdoor None ProgramN/A N/A 142 Flood Curbs FLB, SNS Concrete Air-indoor None Structures Monitoring N/A N/A I Program 0501 Aging Management Review Results Page 3.5-129 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 Material Environment .Requiring Volume 2 Notes No. Commodity Function 1 Management Program Item Item III.B2-10 134 Expansion SNS, SRE, Carbon Steel Aii -outdOOi I ____ .t. '--'" .. ;,.,,1 Structures Monitoring III.B3-7 3.5.1-39 A Anchors SSR L.U:::'

VI IIIGlLe. lal Program III.B4-10 III.B5-7 135 Expansion SNS,SRE, Galvanized Air-outdoor Loss of material Structures Monitoring III.B2-7 3.5.1-50 A Anchors SSR Steel Program III.B4-7 Expansion SNS, SRE, -Structures Monitoring II I. B2-7 I 136 Stainless Steel Air -outdoor None 3.5.1-50 Anchors 'SSR -Program III.B4-7 0525 , 137 Expansion SNS, SRE, Carbon Steel Raw water Loss of material Structures Monitoring III.A6-11 3.5.1-47 E .. Anchors SSR Program 138 Expansion SNS, SRE, Galvanized Raw water Loss of material Structures Monitoring III.A6-11 3.5.1-47 E Anchors SSR Steel . Program ) Expansion SNS, SRE, Stainless Steel Loss of material Structures Monitoring VII.C3-7 3.3.1-78 E 139 Anchors SSR Raw water Program . 0524 Concrete Cracking Equipment Pads SNS, SRE, Concrete Structures Monitoring N/A H 140 SSR Air-indoor* Change in Program N/A 0521 material properties Equipment Pads SRE, Structures* Monitoring I 141 SSR Concrete Air-outdoor None Program N/A N/A 0501 Flood Curbs FLB, SNS Concrete Structures Monitoring N/A N/A I 142 Air-indoor None Program 0501 Aging Management Review Results Page 3.5-129 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk CommoditiesAging Effect NRG10 Row Component Intended Material Environment Requiring Aging Management UREG-1801 Table I Notes No. Commodity Function 1 Management Program Item Item 143 Floor Trenches SNS, SRE Concrete Air-indoor None Structures Monitoring N/A N/A I SSR Program 0501 EN, FB, FLB, 144 Hatches MB, PB, Concrete Air-indoor None Structures Monitoring N/A N/A SHD, SNS, Program 0501 SRE, SSR EN, FB, FLB, 145 Hatches MB, PB, Concrete Air-outdoor None Structures Monitoring N/A N/A SHD, SNS, Program 0501 SRE, SSR tSNS, SRE CStructures Monitoring N 146 Support Pedestals NSR, Concrete Air-indoor None N/A N/A Peetas SSR r-norneProgram 0501 147 Support Pedestals SNS, SRE, Concrete Air-outdoor None Structures Monitoring N/A N/AI SSR -Program 0501 Loss of material SNS, SRE SrcueMoirngE 148 Support Pedestals SSR Concrete Raw water Structures Monitoring Ill.A6-5 3.5.1-35 E Cracking Program o51 Elastomeric Components Cracking Biological Shield C Wall Annulus Structures Monitoring II1.A6-12 3.5.1-44 0527 149 Compressible EXP, SSR Elastomer Air-indoor Change in Program Material material 05281 1_ 1 properties Aging Management Review Results Page 3.5-1 30 January 2010 Aging Management Review Results Page 3.5-130 January 2010 Table 3.5.2-13 Row Component! Intended No. Commodity Function 1 143 Floor Trenches SNS, SRE, SSR EN, FB, FLB, 144 Hatches MB, PB, SHD, SNS, SRE, SSR EN, FB, FLB, 145 Hatches MB, PB, SHD, SNS, SRE, SSR 146 Support Pedesta'is SNS, SRE, SSR 147 Support Pedestals SNS, SRE, SSR 148 Support Pedestals SNS, SRE, SSR Biological Shield Wall Annulus 149 Compressible EXP, SSR Material Aging Management Review Results .

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Bulk Commodities Aging Effect Aging Management NUREG-1801 Table 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Concrete Air-indoor None Structures Monitoring N/A N/A I 0501 Concrete Air-indoor None Structures Monitoring N/A N/A I Program Concrete Air-outdoor None Structures Monitoring N/A N/A I Program 0501 Concrete Air-indoor None Structures Monitoring N/A N/A I Program 0501 Concrete Air-outdoor None Structures Monitoring N/A N/A I Program 0501 Loss of material Concrete Raw water Structures Monitoring III.A6.,5 3.5.1-35 E Cracking Program 0519 Ehlstomeric ComponelJts Cracking C Structures Monitoring

Elastomer Air-indoor Change in Program 111.A6-12 3.5.1-44 0527 material v 0528 properties 3.5-130 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component Intended Aging Effect Aging Management NUREG-1801 Table I Notes No. Commodity Function' Material Environment Requiring AgigM am Volume 2 Item.._ _ Management Item Cracking Building Pressure , 1Ck Structures MonitorinC 150 Boundary Seals .N... Elastomer Air-indoor Cn ii.A6-12 3.5.1-44 0527 an elns SNS, SSR Elsoe i-nor Change in Program and Sealants material 0528 properties Cracking C 151 Compressible EXP, FLB, Elastomer Air-indoor Structures Monitoring II1.A6-12 3.5.1-44 0527 Joints and Seals SNS, SSR Change in Program material 0528 properties Cracking C 152 Structures Monitoring II1.A6-12 3.5.1-44 0527 Compressible EXP, FLB, Elastomer Air-outdoor Change inPrga Joints and Seals SNS, SSR Program material 0529 properties Cracking C 153 Expansion Boots EXP, FLB, Structures Monitoring

'111.A6-12 3.5.1-44 0527 S153 Expansion Boots SNS, SRE, Elastomer Air-outdoor Change in Program SSR material 0529 properties EXP, FLB, 154 Expansion Boots SNS, SRE, Elastomer Soil None None N/A N/A J SSR Aging Management Review Results Page 3.5-131 January 2010* Table 3.5.2-13 Row Component I Intended , No. Commodity Function 1 Building Pressure 150 Boundary Seals EXP, PS, and Sealants S!,!S, SSR 151 Compressible EXP, FLB, Joints and Seals SNS, SSR 152 Compressible EXP, FLB, Joints and Seals SNS, SSR EXP, FLB, .153 Expansion Boots SNS, SRE, SSR EXP, FLB, 154 Expansion Boots SNS, SRE, SSR Aging Management Review Results *

• Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Bulk Commodities Aging Effect Aging Management NUREG-1801 Table 1 Material Environment Requiring Program ',Volume2 Item Notes Management Item Cracking C Elastomer Air-indoor Change in Structures Monitoring iii.AS-12 3.5.1-44 0527 material Program 0528 properties Cracking C Elastomer Air-indoor Change in Structures Monitoring IILAS-12 3.5.1-44 0527 Program material 0528 properties Cracking C Elastomer Air-outdoor Change in Structures Monitoring IILAS-12 3.5.1-44 0527 Program material 0529 properties Cracking C Elastomer Air-outdoor Change in Structures Monitoring IILAS-12 3.5.1-44 0527 material Program 0529 properties Elastomer Soil None None N/A N/A J Page 3.5-131 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component/ Intended Aging Effect Aging Management Table I No. Commodity Function' Material Environment Requiring Program Volume 2 Item Notes NyManagement Item Cracking EN, FLB, Elastomer/

Structures Monitoring C 155 Roof Membrane SNS, SRE, Built-up Air-outdoor Change in Program Ill.A6-12 3.5.1-44 0527 SSR Roofing material 0529 properties 156 Waterproofing FLB, SNS, Elastomer Soil None None N/A N/A J Membrane SSR Air-indoor 157 Waterstops FLB, SNS, Elastomer (within walls, None None N/A N/A J SSR floors, or foundations) 158 Waterstops FLB, SNS, Elastomer Soil None None N/A N/A SSR Fire Barriers Fire Protection VII.G-3 3.3.1-63 B Program 0530 159 Fire Doors FB, SNS, Carbon Steel Air-indoor Loss of material SRE, SSR Structures Monitoring I11.B4-10 3.5.1-39 C Program Fire Protection N/A N/A I Program 0501 160 Fire Doors FB, SNS, Galvanized Air-indoor None SRE, SSR Steel Structures Monitoring III.B4-5 3.5.1-58 C Program Aging Management Review Results Page 3.5-132 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item Cracking EN, FLB, Elastomer/ C 155 Roof Membrane SNS, SRE, Built-up Air-outdoor Change in Structures Monitoring III.A6-12 0527 SSR Roofing material Program 0529 properties 156 Waterproofing FLB, SNS, Elastomer Soil None None N/A N/A J Membrane SSR Air-indoor 157 Waterstops FLB, SNS, Elastomer (within walls, None None N/A N/A J SSR floors, or foundations) 158 Waterstops FLB, SNS, Elastomer Soil None None N/A N/A J SSR Fire Barriers Fire Protection VII.G-3 3.3.1-63 B FB, SNS, Program 0530 159 Fire Doors SRE, SSR Carbon Steel Air-indoor Loss of material Structures Monitoring II I. B4-1 0 3.5.1-39 C Program Fire Protection N/A N/A I FB, SNS, Galvanized Program 0501 160 Fire Doors Air-indoor None I SRE, SSR Steel Structures Monitoring III.B4-5 3.5.1-58 C Program Aging Management Review Results Page 3.5-132 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function' Material Environment Requiring Program Volume 2 Item Management Item Fire Protection VII.G-4 3.3.1-63 B FB, SNS, Program 0530 161 Fire Doors FE, SS, Carbon Steel Air-outdoor Loss of material SRE, SSR Structures Monitoring I1:.B4-10 3.5.1-39 C Program Fire Protection VII.G-4 3.3.1-63 B Program 0530 162 Fire Doors FB, SNS, Galvanized SRE, SSR Steel Air-outdoor Loss of material Structures Monitoring

'111..B4-7 3.5.1-50 C Program Cracking/Delamination/ FB, FLB, PB, Separation F 163 Fire Stops SNS, SRE, Silicone Air-indoor Protection VII.G-1 3.3.1-61 B Elastomer Ai-norProgram 0528 SSR Change in material properties FB, SNS, Fire Protection N 164 Fireproofing SRE, SSR Thermolag Air-indoor None Program N/A 0501 165 Fire Wraps SNS,SRE, Ceramic fiber Air-indoor None Fire Protection N/A N/A 0501 SSR Program 03 0534 166 Fire Wraps Darmatt Air-indoor None Fire Protection N/A J SRE, SSR Program 0501 Aging Management Review Results Page 3.5-133 January 2010.' *

• Columbia Generating Station , License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2' Item Notes Management Item Fire Protection VII.G-4 3.3.1-63 B FB, SNS, Program 0530 161 Fire Doors Carbon Steel Air-outdoor Loss of material . SRE, SSR Structures Monitoring II I. B4-10 3.5.1-39 C Program Fire Protection VII.G-4 3.3.1-63 B FB, SNS, Galvanized Program 0530 162 Fire Doors SRE, SSR Steel Air-outdoor Loss of material Structures Monitoring , III.B4-7 3.5.1-50 C Program Crackingl Delaminationl FB, FLB, PB, Silicone Separation Fire Protection B 163 Fire Stops SNS, SRE, Elastomer Air-indoor Program VII.G-1 3.3.1-61 0528 SSR Change in material properties 164 Fireproofing FB, SNS, Thermolag Air-indoor None Fire Protection N/A N/A J SRE, SSR Program 0501 " J 165 Fire Wraps SNS, SRE, Ceramic fiber Air-indoor None Fire Protection N/A N/A 0501 SSR Program 0534 FB, SNS, Air-indoor Fire Protection N/A N/A J 166 Fire Wraps SRE, SSR Darmatt None Program 0501 Aging Management Review Results Page 3.5-133 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Aging Effect AigManagement VoumeG- 80 Notes Row Component/

I Intended Agn Efc Aging MaaeetNRG181Table I No. Commodity Function' Material Environment Requiring Program Volume 2 Item Management -Item FB, SNS, Thermolag Air-indoor None Fire Protection N/A N/A J SRE, SSR Program 0501 168 Fire Wraps FB, SNS, 3M Interam Air-indoor NoneFire Protection N/A N/A SRE, SSR 3MItrm Arido oeProgram 0501 Fluoropolymers and Lubrite Sliding Surfaces SNS, SRE,J 169 Cable Tie Wraps SSR Fluoropolymer Air-indoor None None N/A N/A 0 SSR 0531 J 170 Cable Tie Wraps SNS, SRE Nylon Air-indoor None None N/A N/A 0532 Inservice Inspection 1I1.B1.1-5 3.5.1-56 I Program-IWF -111.B1.2-3 0523 171 Lubrite sliding SNS, SSR Lubrite Air-indoor None Ill.1B1.3-3 supports Structures Monitoring III.B2-2 3.5.1-52. I Program 0523 Miscellaneous Materials Containment 172 Penetration SNS Fiberglass Air-indoor None None N/A N/A J Insulation Piping and 173 Mechanical SNS Aluminum Air-indoor None None N/A N/A J equipment jacketing Insulation Aging Management Review Results Page 3.5-134 January 2010 Table 3.5.2-13 Row Component I Intended No. Commodity Function 1 167 Fire Wraps FB, SNS, *SRE, SSR 168 Fire Wraps FB, SNS, SRE, SSR Columbia Generating Station License Renewal Application Technical Information Aging Management Review Results -Bulk Commodities Aging Effect Aging Management NUREG-1801 Table 1 Material Environment Requiring Program Volume 2 Item Notes Management / Item Thermolag Fire Protection N/A N/A J Air-indoor None Program 0501 3M Interam Air-indoor None Fire Protection N/A N/A J Program 0501 Fluoropolymers and Lubrite Slic;ting Surfaces 169 Cable Tie Wraps SNS, SRE, Fluoropolymer Air-indoor None None N/A N/A J SSR 0531 170 Cable Tie Wraps SNS"SRE Nylon Air-indoor None None N/A N/A J 0532 Inservice Inspection III.B1.1-5 3.5.1-56 I -Program-IWF "1II.B1.2-3 0523 .. 171 Lubrite sliding SNS, SSR Lubrite Air-indoor None III.B1.3-3 supports Structures Monitoring III.B2-2 3.5.1-52. I Program 0523 Miscellaneous Materials . Containment 172 Penetration SNS Fiberglass Air-indoo( None None N/A N/A J Insulation Piping and 173 Mechanical SNS Aluminum Air-indoor None None N/A N/A J equipment jacketing Insulation Aging Management Review Results Page 3.5-134 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results,-

Bulk Commodities Aging Effect NUREG-1801 Ta Nte Rowgintnddg Efec Aging MaaeetVolume 2 Tables Row Component FIntended Material Environment Requiring AiProgram Item No. Commodity Function' Managemen Item_____ __ _ _ _Management jItem _ _Piping and 174 Mechanical SNS Calcium Air-indoor None None N/A N/A J equipment Silicate Insulation Piping and 175 Mechanical SNS Fiberglass Air-indoor None None N/A N/A J equipment Insulation Piping and Mechnganil Stainless Steel 176 Mechanical SNS Mirror Air-indoor None None N/A N/A J equipment insulation Insulation i Piping and 177 Mechanical SNS Aluminum Air-outdoor None Structures Monitoring N/A N/A J equipment jacketing Program 0525 Insulation Piping and 178 Mechanical SNS Calcium Air-outdoor None None N/A N/A J equipment Silicate Insulation Piping and 179 Mechanical SNS Fiberglass Air-outdoor None None N/A N/A equipment Insulation Piping and Stainless Steel Structures Monitoring N 180 Mechanical SNS Mirror Air-outdoor None N/A N/A equipment insulation Program 0525 Insulation Aging Management Review Results Page 3.5-135 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results'-Bulk Commodities Row . Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring . Program Volume 2 Item Notes Management Item Piping and 174 Mechanical SNS Calcium Air-indoor None None N/A N/A J equipment Siiicate Insulation

-Piping and 175 Mechanical SNS Fiberglass Air-indoor None None N/A N/A J equipment Insulation Piping and Stainless Steel 176 Mechanical SNS Mirror Air-indoor None None N/A N/A J equipment insulation Insulation ( Piping and 17.7 Mechanical SNS Aluminum Air-outdoor None Structures Monitoring N/A N/A J equipment jacketing Program 0525 Insulation Piping and 178 Mechanical SNS Calcium Air-outdoor None None N/A N/A J equipment Silicate Insulation Piping and 179 Mechanical SNS Fiberglass Air-outdoor None None N/A N/A J equipment Insulation Piping and Stainless Steel 180 Mechanical SNS Mirror Air-outdoor None Structures Monitoring N/A N/A J equipment inSUlation Program 0525 Insulation . Aging Management Review Results Page 3.5-135 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities AgngEfec MnaemntNUREG-1 801 Tbe1Notes Row Component Intended Aging Effect Aging Management NURE 2 I No. Commodity Functioni Material Environment Requiring Program Volume 2 Item Management Item1 -Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-1 36 January 2010 Aging Management Review Results Page 3.5-136 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.5.2-13 Aging Management Review Results -Bulk Commodities Row Component I Intended Aging Effect Aging Management NUREG-1801 Table 1 No. Commodity Function 1 Material Environment Requiring Program Volume 2 Item Notes Management Item 1 -Refer to Table 2.0-1 for intended function descriptions. Aging Management Review Results Page 3.5-136 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Generic Notes: A Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1 801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1 801 AMP.E Consistent with NUREG-1801 item for material, environment, and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1 801 for this component.

G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1801 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-1801. Aging Management Review Results Page 3.5-137 January 2010* (' *

• Columbia Generating Station License Renewal Application Technical Information Generic Notes: -A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP. S Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP. C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP. 0 Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP. E Consistent with NUREG-1801 item for material, environment, and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program. F Material not in NUREG-1801 for this component.

G Environment.not in NUREG-1801 for this component and material. H Aging effect not in NUREG-1801 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-1801. Aging Management Review Results Page 3.5-137 January 2010 Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes: 0501 No applicable aging effects have been identified for the component type. However, the identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0502 NUREG-1801 item lI.B2.1-1 indicates the moisture barrier, at the junction where the shell or liner becomes embedded, is subject to aging management activities in accordance with ASME Section Xl, Subsection IWE requirements. Columbia drywell floor peripheral seal is made of stainless steel and is welded to the primary containment vessel and to the underside of the circular closure girder embedded in the drywell floor. There are no concrete to metal moisture barriers; therefore, the NUREG-1 801 textregarding moisture barrier is not applicable. 0503 The refueling stainless steel bellows perform their functions during refueling preventing water from entering the drywell. The bellows are not subjected to cyclic loading during refueling. The normal environment experienced by the refueling bellows is warm, dry air, with short periods of demineralized water contact during refueling. 0504 Due to possibility of containment shell degradation from corrosion induced by a moist environment in sand pocket region, Columbia has committed to monitor humidity levels in this region. Columbia has implemented a procedure to survey the relative humidity of air drawn from within containment annulus sand pocket region. k 0505 The process line penetrations are of welded steel construction without expansion bellows, gaskets, or sealing compounds. Electrical penetration assembly internal o-rings are sub-component of the electrical penetration and are included in this commodity group. Insulation for hot penetrations is addressed in bulk commodities. 0506 Elastomeric seals, gaskets, or o-rings are sub-part of the host component and their leak tightness is monitored by the Appendix JProgram. Plant Technical Specification ensures that access airlocks and hatches maintain leak tightness in the closed position.0507 In addition to Inservice Inspection Program-IWE and Appendix J Program as AMP, the BWR Water Chemistry Program is credited with the elimination of excessive chlorides and sulfates from the.water. 0508 In addition to Structures Monitoring Program as AMP, the BWR Water Chemistry Program is credited with the elimination of excessive chlorides and sulfates from the water. 0509 Note C is used since NUREG-1801 only has an ASME Class 1 item for component in treated water. Component is ASME Class 2;the NUREG-1801 item is the closest match.Aging Management Review Results Page 3.5-138 January 2010 0\. Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes: 0501 No applicat;>le aging effects have been identified for the component type. However, the identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0502 NUREG-1801 item II.B2.1-1 indicates the moisture barrier, at the junction where the shell or liner becomes embedded, is subject to aging management activities in accordance with ASME Section XI, Subsection IWE requirements. Columbia drywell floor peripheral seal is made of stainless steel and is welded to the primary containment vessel and to the underside of the circular closure girder embedded in the drywell floor. There are no concrete to metal moisture barriers; therefore, the NUREG-1801 text regarding moisture barrier is not applicable. 0503 The refueling stainless steel bellows perform their functions during refueling preventing water from entering the drywell. The bellows are not subjected to cyclic loading during refueling. The normal environment experienced by the refueling bellows is warm, dry air, with short periods of demineralized water contact during refueling. 0504 Due to possibility of containment shell degradation from corrosion induced by a moist environment in sand pocket region, Columbia has committed to monitor humidity levels in this region. Columbia has implemented a procedure to survey the relative humidity of air drawn from within containment annulus sand pocket region. \ 0505 The process line penetrations are of welded steel construction without expansion bellows, gaskets, or sealing compounds. Electrical penetration assembly internal o-rings are SUb-component of the electrical penetration and are included in this commodity group. Insul<;ltion for hot penetrations is addressed in bulk commodities. 0506 Elastomeric seals, gaskets, or o-rings are sub-part of the host component and their leak tightness is monitored by the Appendix J Program. Plant Technical Specification ensures that access airlocks and hatches maintain leak tightness in the closed position. 0507 In addition to Inservice Inspection Program-IWE and Appendix J Program as AMP, the BWR Water Chemistry Program is credited with the elimination of excessive chlorides and sulfates from thewater. 0508 In addition to Structures Monitoring Program as AMP, the BWR Water Chemistry Program is credited with the elimination of excessive chlorides and sulfates from the water. 0509 Note C is used since NUREG-1801 only has an ASME Class 1 item for component in treated water. Component is ASME Class 2; the NUREG-1801 item is the closest match. Aging Management Review Results Page 3.5-138 JanuarY 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes: 0510 Aging management for loss of material of the neutron absorber stainless steel sheathing is required by the listed AMP. Columbia plant-specific AMR concluded boron carbide plates (B4C) do not require aging management for the period of extended operation for their neutron absorbing function based on plant-specific examination and industry operating experience.

However; Columbia has already committed in the CLB to perform boron carbide coupon sample testing and this current commitment will continue to verify the specific design values of the B4C neutron absorbing parameters and demonstrate that the effects of aging are not significant. FSAR Section 9.1.2.3.2 states the CLB commitment, "To ensure the integrity of the spent fuel storage racks in the event that water has leaked into the racks, specially designed control samples, consisting of B4C plates in vented (to pool water) canisters, are placed in a readily accessible position in the spent fuel pool. These samples are subjected to periodic examinations to check for possible deterioration and they are also analyzed to ensure that the boron has not leached from the plates." The current CLB -commitment along with continued monitoring of industry operating experience will provide adequate assurance that any age related degradation of the B4C will be detected.0511 The new fuel storage racks are located in a dry mild environment inside the new fuel storage vault. The new fuel storage racks are made from aluminum with stainless steel fasteners. The use of stainless steel fasteners in aluminum to avoid detrimental galvanic corrosion in a predominantly air environment, is a recommended practice and has been used successfully for many years by the aluminum industry.0512 The AMP manages loss of material due to crevice and pitting corrosion. Cracking due to SCC is not applicable. Spent fuel pool water level monitoring is per Technical Specifications. Leak chase channel monitoring is via operator rounds.0513 The gates experience the same environment as the spent fuel pool liner. The BWR Water Chemistry Program manages Loss of material due to crevice and pitting corrosion. Cracking due to SCC is not applicable. Since the gates are part of the fuel pool water containment boundary, monitoring of fuel pool level and leak chase channels activities also indirectly manage this component. 0514 This NUREG&1801 item specifies the AMP is to be augmented by a "One-Time Inspection." Augmented One-time inspection is not applicable to the spent fuel pool since it is not a low flow or stagnant flow area. Also, NUREG-1801 Chapter VII.A2 Spent Fuel Storage does not require Water Chemistry to be augmented by a "One-Time Inspection." Augmented inspection applies to piping, piping components, and piping elements, not the spent fuel racks or gates.0515 Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. Chapter II or Chapter III of NUREG-1 801 does not list exposed to raw water environment for stainless steel components. The identified AMP is used to manage aging effects for the period of extended operation. 0516 The lead panels are encapsulated within stainless steel casing.0517 The shield walls at Columbia are made up of free-standing or stacked solid bricks (blocks) sandwiched between metal (siding)panels. The panel sections (and blocks) are held in place under all load conditions by angle sections anchored to the concrete wing walls at the-pipe chases. Concrete block shield walls do not function like a typical block wall within a structure and are not subjected to degradations found from industry experience (i.e., aging effects cited in IEB 80-11.)Aging Management Review Results Page 3.5-139 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes: 0510 Aging management for loss of material of the neutron absorber stainless steel sheathing is required by the listed AMP. Columbia plant-specific AMR concluded boron carbide plates (B4C) do not require aging management for the period of extended operation for their neutron absorbing function based on plant-specific examination and industry operating experience.

However; Columbia has already committed in the CLB to perform boron carbide coupon sample testing and this current commitment will continue to verify the specific design values of the B4C neutron absorbing parameters and demonstrate that the effects of aging are not significant FSAR Section 9.1.2.3.2 states the CLB commitment, "To ensure the integrity of the spent fuel storage racks in the event that water has leaked into the racks, speciaily designed control samples, consisting of B4C plates in vented (to pool water) canisters, are placed in a readily accessible position in the spent fuel pool. These samples are subjected to periodic examinations to check for possible deterioration and they are also analyzed to ensure that the boron has not leached from the plates: The current CLB commitment along with continued monitoring of industry operating experience will provide adequate assurance that any age related degradation of the B4C will be detected. 0511 The new fuel storage racks are located in a dry mild environment inside the new fuel storage vault. The new fuel storage racks are made from aluminum with stainless steel fasteners. The use of stainless steel fasteners in aluminum to avoid detrimental galvanic corrosion in a predominantly air environment, is a recommended practice and has been used successfully for many years by the aluminum industry. 0512 The AMP manages loss of material due,to crevice and pitting corrosion. Cracking due to SCC is not applicable. Spent fuel pool water level monitoring is per Technical SpeGifications. Leak chase channel monitoring is via operator rounds. -0513 The gates experience the same environment as the spent fuel pool liner. The BWR Water Chemistry Program manages Loss of material due to crevice and pitting corrosion. Cracking due to SCC is not applicable. Since the gates are part of the fuel pool water containment boundary, monitoring offuel pool level and leak chase channels activities also indirectly manage this component. 0514 This item specifies the AMP is to be augmented by a "One-Time Inspection." Augmented One-time inspection is not applicable to the spent fuel pool since it is not a low flow or stagnant flow area. Also, NUREG-1801 Chapter VII.A2 Spent Fuel Storage does not require Water Chemistry to be augmented by a "One-Time Inspection: Augmented inspection applies to piping, piping components, and piping elements, not the spent fuel racks or gates. 0515 Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. Chapter II or Chapter III of NUREG-1801 does not list exposed to raw water environment for stainless steel components. The identified AMP is used to manage aging' effects for the period of extended operation. 0516 The lead panels are encapsulated within stainless steel casing. " 0517 The shield walls at Columbia are made up offree-standing or stacked solid bricks (blocks) sandwiched between metal (siding) panels. The panel sections (and blocks) are held in place under all load conditions by angle sections anchored to the concrete wing walls at the. pipe chases. Concrete block shield walls do not function like a typical block wall within a structure and are not subjected to degradations found from industry experience (i.e., aging effects cited in IEB 80-11.) Aging Management Review Results Page 3.5-139 January 2010 ) Columbia Generating StationLicense Renewal Application Technical Information Plant-Specific Notes: 0518 Columbia is not committed to RG 1.127 Inspection of Water Control Structures Associated with Nuclear Power Plants, Revision 1.However, the Structures Monitoring Program will be enhanced to include the inspection elements delineated in RG 1.127, Revision 1 per NUREG-1801 Chapter XI.S7.0519 The NUREG-1 801 item for freeze-thaw does not list exposed to raw water environment for water-control structures. Freeze-thaw can be possible near the water line. This environment is both exposed to weather and exposed to raw water; therefore, the environment is a match. The identified AMP is used to manage aging effects for the period of extended operation. 0520 Concrete component submerged in raw water is not susceptible to freeze-thaw. No applicable aging effects have been identified for the component type. However, the identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0521 The indicated aging effects (cracking and change in material properties due to irradiation) requiring management are only applicable to component types within the Radwaste Control Building charcoal absorber zones (i.e., Zone E at el. 437'-0" and Zone K at elevation 467'-0"). Radiation values are the worst case surface (contact) doses for the indicated zones. The identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0522 Loss of material due to crevice corrosion and pitting corrosion is not an aging effect requiring management for aluminum exposed to air-outdoor since Columbia is located in an in-land rural environment and not exposed to aggressive environmental conditions. However, the identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0523 Lubrite material resists deformation, has a low coefficient of friction, resists softening at elevated temperatures, absorbs grit and abrasive particles, is not susceptible to corrosion, withstands high intensities of radiation, and will not score or mar. The Lubrite lubricants used in nuclear applications are designed for the environments to which they are exposed. There are no known aging effects that would lead to a loss of intended function. However, the identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0524 Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. NUREG-1801 does not list exposed to raw water environment for support components. The identified AMP is used to manage aging effects for the period of extended operation. 0525 The NUREG-1801 item lists Loss of material as an aging effect. This aging effect was determined not applicable since Columbia is located in an in-land rural environment and is not exposed to aggressive environmental conditions. Component external surfaces are not continuously wetted or exposed to an. aggressive ambient environment (such as a saltwater atmosphere, sulfur dioxide, etc.)or industrial locations. However, the identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0526 The roof is insulated or has built-up roofing. Therefore, environment for this concrete roof slab is "air-indoor" for underside of slab.Roof membrane is evaluated and addressed in bulk commodities. Aging Management Review Results Page 3.5-140 January 2010 Columbia Generating Station License Renewal Application Technical Information plant-Specific Notes: 0518 Columbia is not committed to RG 1.127 Inspection of Water Control Structures Associated with Nuclear Power Plants, _ Revision 1. However, the Structures Monitoring Program will be enhanced to include the inspection elements delineated in RG 1.127, Revision 1 per NUREG-1801 Chapter XI.S7. 0519 The NUREG-1801 item for freeze-thaw does not list exposed to raw water environment for water-control structures. Freeze-thaw can be possible near the water line. This environment is both exposed to weather and exposed to raw water; therefore, the environment is a match. The identified AMP is used to manage aging effects for the period of extended operation. 0520 Concrete component submerged in raw water is not susceptible to freeze-thaw. No applicable aging effects have been identified for the component type. However; the identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0521 The indicated aging effects (cracking and change in material properties due to irradiation) requiring management are only applicable to component types within the Radwaste Control Building charcoal absorber zones (i.e., Zone E at el. 43T-0" and Zone K at elevation 467'-0"). Radiation values are the worst case surface (contact) doses for the indicated zones. The identifiedAMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0522 Loss of material due to crevice corrosion and pitting corrosion is not an aging effect requiring management for aluminum exposed to air-outdoor since Columbia is located in an in-land rural environment and not exposed to aggressive environmental conditions. However, the identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0523 Lubrite material resists deformation, has a low coefficient of friction, resists softening at elevated temperatures, absorbs grit and abrasive particles, is not susceptible to corrosion, withstands high intensities of radiation, and will not score or mar. The Lubrite lubricants used in nuclear applications are designed for the environments to which they are exposed. There are no known aging effects that would lead to a loss of intended function. However, the identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0524 Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. NUREG-1801 does not list exposed to raw water environment for support components. The identified AMP is used to manage aging effects for the period of extended operation. 0525 The NUREG-1801 item lists Loss of material as an aging effect. This aging effect was determined not applicable since Columbia is located in an in-land rural environment and is not exposed to aggressive environmental conditions. Component external surfaces are not continuously wetted or exposed to an. aggressive ambient environment (such as a saltWater atmosphere, sulfur dioxide, etc.) or industrial locations. However, the identified AMP will be used to confirm the absence of significant aging effects for the period of extended operation. 0526 The roof is insulated or has built-up roofing. Therefore, environment for this concrete roof slab is "air-indoor" for underside of slab. Roof membrane is evaluated and addressed in bulk commodities. Aging Management Review Results Page 3.5-140 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes: 0527 NUREG-1801 lists loss of sealing aging effect for elastomer.

Loss of sealing is not an aging effect, but rather a consequence of elastomer degradation. This effect can be caused by cracking or change in material properties for elastomeric material. Note C is used since the NUREG-1 801 item is intended for Group 6 -water-control structures' components; the line item covers all in-scope structures. 0528 Ionizing radiation is an applicable aging mechanism for elastomers located in areas where the radiation exceeds threshold. Ionizing radiation mechanism does not apply to elastomers located in mild radiation areas.0529 Cracking and Change in material properties due to ultraviolet radiation and ozone are applicable aging effects for rubber only.0530 The aging mechanism Loss of material due to wear is not an aging effect for fire doors based on EPRI Report 1015078 "Aging Effects for Structures and Structural Components (Structural Tools)." The aging mechanism Loss of material due to general corrosion was not specified in the corresponding NUREG-1 801 item as an aging effect requiring management. Generic Note "A" was used to align to the NUREG-1801 item since the material, environment, aging effect, and program matches. The identified AMP will be used to manage Loss of material due to general corrosion and will confirm the absence of significant wear of fire doors for the period of extended operation. The Fire Protection Program inspects for excessive wear of latches, strike plates, hinges, sills, and closing devices, and proper clearances (gaps) between the door, frame, and threshold. 0531 -Plant-specific Tefzel tie wraps test report and engineering evaluation concluded Tefzel (fluorpolymer) tie wraps met environmental qualification requirements. Tefzel product performance was demonstrated by meeting the tensile strength requirements specified in the test report where it was subjected to normal life, accident and post accident conditions. Both the temperature and radiation capabilities exceed the maximum temperature and 60 years total integrated dose values, therefore based on plant-specific environmental qualification test results and plant engineering evaluation there are no aging effects. requiring management for Tefzel cable tie wraps.0532 Per plant procedure, nylon tie wraps may be used for applications outside the Radiologically Controlled Area (RCA) where they will not be exposed to environmental stresses such as extreme temperatures, ultraviolet radiation, or harsh chemicals. The temperature capability of nylon tie wraps exceeds the maximum temperature values for non-RCA areas, therefore there are no aging effects requiring management for nylon cable tie wraps.0533 Components are the stainless steel missile deflectors for the spent fuel rack vents which are not within the scope of ISI-IWF. The identified AMPs will be used to manage the aging effects for the period of extended operation. 0534 The Thermo-Lag fire wraps at Columbia are abandoned in place. There are a few tray nodes where Thermo-lag is credited as electrical separation barrier, but not for Post-Fire Safe Shutdown. Siltemp tapes and Flame-Safe blankets are also used as electrical separation barriers.Aging Management Review Results Page 3.5-141 January 2010* * /'

• Co.lumbia Generating Station License Renewal Application , Technical Information Plant-Specific Notes: 0527 NUREG-1801 lists loss of sealing aging effect for elastomer.

Loss of sealing is not an aging effect, but rather a consequence of elastomer degradation. This effect can be caused by cracking or change in material properties for elastomeric material. Note C is used since the NUREG-1801 item is intended for Group 6 -water-control structures' compqnents; the line item covers all structures. -0528 Ionizing radiation is an applicable ag'ing mechanism for elastomers located in areas where the radiation exceeds threshold. Ionizing radiation mechanism does not apply to elastomers located in mild radiation areas. 0529 Cracking and Change in material properties due to ultraviolet radiation and ozone are applicable aging effects for rubber only. 0530 The aging mechanism Loss of material due to wear is not an aging effect for fire doors based on EPRI Report 1015078 "Aging Effects for Structures and Structural Components (Structural Tools)." The aging mechanism Loss of material due to general corrosion was not specified in the corresponding NUREG-1801 item as an aging effect requiring management. Generic Note "A" was used to align to the NUREG-1801 item since the material, environment, aging effect, and program matches. The identified AMP will be used to manage Loss of material due to general corrosion and will confirm the absence of significant wear of fire doors for the period of extended operation. The Fire Protection Program inspects for excessive wear of latches, strike plates, hinges; sills, and closing devices, and proper clearances (gaps) between the door, frame, and threshold. 0531-Plant-specific Tefzel tie wraps test report and engineering evaluation concluded Tefzel(fluorpolymer) tie wraps met environmental qualification requirements. Tefzel product performance was demonstrated by meeting the tensile strength requirements specified in the test report where it was subjected to normal life, accident and post accident conditions. Both the temperature and radiation capabilities exceed the maximum temperature and 60 years total integrated dose values, therefore based on plant-specific environmental qualification test results and plant engineering evaluation there are no aging effects requiring management for Tefzel ' cable tie wraps. 0532 Per plant procedure, nylon tie wraps may be used for applications outside the Radiologically Controlled Area (RCA) where they will not be exposed to environmental stresses such as extreme temperatures, ultraviolet radiation, or harsh chemicals. The , temperature capability of nylon tie wraps exceeds the maximum temperature values for non-RCA areas, therefore there are no aging effects requiring management for nylon cable tie wraps. 0533 Components are the stainless steel missile deflectors for the spent fuel rack vents which are not within the scope of ISI-IWF. The identified AMPs will be used to manage the aging effects for the period of extended operation. 0534 The Thermo-Lag fire wraps at Columbia are abandoned in place. There are a few tray nodes where Thermo-lag is credited as electrical separation barrier, but not for Pos,t-Fire Safe Shutdown. Siltemp tapes and Flame-Safe blankets are also used as electrical separation barriers. Aging Management Review Results Page 3.5-141 , January 2010 Columbia Generating Station License RenewalrApplication Technical Information [This page intentionally blank] Aging Management Review Results Page 3.5-142 January 2010[This page intentionally blank] \ Aging Management Review Results Page 3.5-142 *

• Columbia Generating Station License RenewalrApplication Technical Information January 2010 .,

Columbia Generating Station License Renewal Application Technical Information

3.6 AGING

MANAGEMENT OF ELECTRICAL AND INSTRUMENTATION AND CONTROL SYSTEMS 3.6.1 Introduction Section 3.6 provides the results of the aging management reviews (AMRs) for those components and commodities identified in Section 2.5, Scoping and Screening Results-Electrical and Instrumentation and Control Systems, subject to AMR. The components and commodity groups subject to AMR are:* Non-Environmentally Qualified Insulated Cables and Connections (Section 2.5.5.1)0 Metal-Enclosed Bus (Section 2.5.5.2)* Switchyard Bus and Connections (Section 2.5.5.3)* Transmission Conductors and Connections (Section 2.5.5.4)* Uninsulated Ground Conductors and Connections (Section 2.5.5.5)0 High-Voltage Insulators (Section 2.5.5.6)Table 3.6.1, Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI .of NUREG-1801, provides the summary of the programs evaluated in NUREG-1801 that are applicable to component and commodity groups in this section. Text addressing summary items requiring further evaluation is provided in Section 3.6.2.2.3.6.2 Results The following table summarizes the results of the AMR for the components and commodity groups in the Electrical and Instrumentation and Control Systems area: Table 3.6.2-1 Aging Management Review Results -Electrical ComponentCommodity Groups 3.6.2.1 Materials, Environments, Aging Effects Requiring Management, and Aging Management. Programs The materials from which specific components and commodity groups are fabricated,the environments to which they are exposed, the potential aging effects requiring management, and the aging management programs used to manage these aging effects are provided for each component and commodity group in the following sections.Aging Management Review Results Page 3.6-1 January 2010 Aging Management Review Results Page 3..6-1 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information

3.6 AGING

MANAGEMENT OF ELECTRICAL AND INSTRUMENTATION AND CONTROL SYSTEMS 3.6.1 Introduction Section 3.6 provides the results of the aging management reviews (AMRs) for those components and commodities identified in Section 2.5, Scoping and Screening Results -Electrical and Instrumentation and Control Systems, subject to AMR. The components and commodity groups subject to AMR are:

• Non-Environmentally Qualified Insulated Cables and Connections (Section 2.5.5.1)
• Metal-Enclosed Bus (Section 2.5.5.2)
• Switchyard Bus and Connections (Section 2.5.5.3)
• Transmission Conductors and Connections (Section 2.5.5.4)
• Uninsulated Ground Conductors and Connections (Section 2.5.5.5)
• High-Voltage.

Insulators (Section 2.5.5.6) Table 3.6.1, Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI*of NUREG-1801, provides the summary of the programs evaluated in NUREG-1801 that are applicable to component and commodity groups in this section. Text addressing summary items requiring further evaluation is provided in Section 3.6.2:2. 3;6.2 Results The following table slJmmarizes the results of the AMR for the components and commodity groups in the Electrical and Instrumentation and Control Systems area: Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups 3.6.2.1 Materials, Environments, Aging Effects Requiring Management, and Aging Management Programs The materials from which specific components' and commodity groups are fabricated, the environments to which they are exposed, the potential aging effects requiring management, and the aging management programs used to manage these aging effects are provided for each component and commodity group in the following sections . Aging Management Review Results Page 3.6-1 January 2010 Columbia Generating Station License Renewal Application Technical Information 3.6.2.1.1 Non-Environmentally Qualified Insulated Cables and Connections The Non-Environmentally Qualified Insulated Cables and Connections commodity group is subdivided for AMR into the following categories:

• Non-Environmentally Qualified Insulated Cables and Connections
• Non-Environmentally Qualified Sensitive, High-Voltage, Low-Level Signal Instrument Cables and Connections 0 Non-Environmentally Qualified Medium-Voltage Power Cables
• Cable Connections (Metallic Parts)0 Fuse Holders (Insulation)
• Fuse Holders (Metallic Clamp)Materials The materials of construction for the Non-Environmentally Qualified Insulated Cables and Connections are:* Various Organic Polymers* Various Metals* Silicon Dioxide* Copper Alloy (fuse holder metallic clamp)Environments The Non-Environmentally Qualified Insulated Cables and Connections are exposed to the following environments:
• Adverse localized environments
• Air- indoor uncontrolled
• Air- outdoor Aging Effects Requiring Management Theaging effects requiring management for the Non-Environmentally Qualified Cables and Connections exposed to adverse localized environments are the following:
• Electrical Failure* Localized Damage and Breakdown of Insulation
• Loosening of Bolted Connections Aging Management Review Results Page 3.6-2 January 2010 Columbia Generating Station License Renewal Application Technical Information 3.6:2.1.1 Non-Environmentally Qualified Insulated Cables and Con'lections The Non-Environmentally Qualified Insulated Cables and Connections commodity group is subdivided for AMR into the following categories:
• Non-Envirqnmentally Qualified Insulated Cables and Connections
• Non-Environmentally Qualified Sensitive, High-Voltage, Low-Level Signal Instrument Cables and Connections
• Non-Environmentally Qualified Medium-Voltage Power Cables
• Cable Connections (Metallic Parts)
• Fuse Holders (Insulation)
• Fuse Holders (Metallic Clamp) Materials The materials of construction for the Non-Environmentally Qualified Insulated Cables and Connections are:
• Various Organic Polymers
• Various Metals
• Silicon Dioxide
• Copper Alloy (fuse holder metallic clamp) Environments The Non-Environmentally Qualified Insulated Cables and Connections are exposed to the following environments: .
• Adverse localized environments
• Air -indoor uncontrolled
• Air -outdoor Aging Effects Requiring Management The .aging effects requiring management for the Non-Environmentally Qualified Cables and Connections exposed to adverse localized environments are the following:

/

• Electrical Failure
• Localized Damage and Breakdown of Insulation
• Loosening of Bolted Connections Aging Management Review Results Page 3.6-2 January 2010 * * ** /

Columbia Generating StationLicense Renewal Application Technical Information

• Reduced Insulation Resistance Aging Management Programs The following aging management programs manage -the aging effects for the Non-Environmentally Qualified Cables and Connections components:
• Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements
• Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program* Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection
• Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program 3.6.2.1.2 Metal-Enclosed Bus The Metal-Enclosed Bus commodity group is subdivided for AMR into the following categories:
• Metal-Enclosed Bus, Non-Segregated (Bus and Connections)" Metal Enclosed Bus, Non-Segregated (Enclosure Assemblies)
• Metal-Enclosed Bus, Non-Segregated (Insulation and Insulators)

Materials The materials of construction for the Metal-Enclosed Bus components are:

• Aluminum* Copper* Silver Plate* Elastomers
• Fiberglass" Galvanized Steel* Porcelain" Steel" Stainless Steel Aging Management Review Results Page 3.6-3 January 2010* *
• Columbia Generating Station License Renewal Application Technical Information
• Reduced Insulation Resistance Aging Management Programs The following aging management programs manage -the aging effects for the Non-Environmentally Qualified Cables and Connections components:
• Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements
• Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Used in Instrumentation Circuits Program
• Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection .
• Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EO Requirements Program 3.6.2.1.2 Metal-Enclosed Bus The Metal-Enclosed Bus commodity group is subdivided for AMR into the following categories:
• Metal-Enclosed Bus, Non-Segregated (Bus and Connections)
• Metal Enclosed Bus, Non-Segregated (Enclosure Assemblies)
• Metal-Enclosed Bus, Non-Segregated (Insulation and Insulators)

Materials The materials of construction for the Metal-Enclosed Bus components are:

• Aluminum
• Copper
• Silver Plate
• Elastomers
• Fiberglass
• Gplvanized Steel
• Porcelain
• Steel \
• Stainless Steel Aging Management Review Results Page 3.6-3 January 2010 Columbia Generating Station License Renewal Application Technical Information
• Various Organic.Polymers (EPR and PVC tape)EnvironmentsThe Metal-Enclosed Bus components are exposed to the following environments:.
• Air -indoor uncontrolled
• Air- outdoor Aging Effects Requiring Management The following aging effects require management for the Metal-Enclosed Bus components:
• Electrical Failure* Hardening and Loss of Strength* Loosening of Bolted Connections" Loss of Material* Reduced Insulation Resistance Aging Management Programs The following aging management programs manage the aging effects for the Metal-Enclosed Bus components:
• Metal-Enclosed Bus Program* Structures Monitoring Program 3.6.2.1.3 Switchyard Bus and Connections The Switchyard Bus and Connections commodity group is evaluated for aging management as follows: Materials The materials of construction for the Switchyard Bus and Connections are:* Aluminum* Galvanized steel Aging Management Review Results Page 3.6-4 January 2010 Columbia Generating Station License Renewal Application
• Technical Information
• Various Organic Polymers (EPR and PVC tape) Environments The Metal-Enclosed Bus components are exposed to the following environments:*
• Air -indoor uncontrolled
• Air -outdoor Aging Effects Requiring Management The following aging effects require management for the Metal-Enclosed Bus components:
• Electrical Failure
• Hardening and Loss of Strength
• Loosening of Bolted Connections
• Loss of Material
• Reduced Insulation Resistance Aging Management Programs The following aging management programs manage the aging effects for the Enclosed Bus components:
• Metal-Enclosed Bus Program
• Structures Monitoring Program 3.6.2.1.3 Switchyard Bus and Connections The SWitchyard Bus and Connections commodity group is evaluated for aging management as follows: Materials The materials

'of construction for the Switchyard Bus and Connections are:

• Aluminum
• Galvanized steel Aging Management Review Results Page 3.6-4 January 2010 *
• Columbia Generating Station License Renewal Application Technical Information Environments The Switchyard Bus and Connections are exposed to the following environment:

0 Air- outdoor Aging Effects Requiring Management There are no aging effects identified as requiring management for the Switchyard Bus and Connections components (See Section 3.6.2.2.3). Aging Management ProgramsThere are no aging effects identified as requiring management; therefore, no aging management programs are required for the Switchyard Bus and Connections components. 3.6.2.1.4 Transmission Conductors and Connections The Transmission Conductors and Connections commodity group is evaluated for aging management as follows: Materials Transmission conductors are Type ACSR (aluminum conductor steel reinforced). The materials of construction for the Transmission Conductor and Connection components are:* Aluminum" Galvanized Steel" Stainless Steel Environments The Transmission Conductor and Connection components are exposed to the following environment:

• Air -.outdoor Aging Effects Requiring Management There are no aging effects identified as requiring management for the TransmissionConductor and Connection components (See Section 3.6.2.2.3).

Aging Management Review Results Page 3.6-5 January 2010.Aging Management Review Results Page 3.6-5 January 2010* *

• Environments Columbia Generating Station License Renewal Application Technical Information The Switchyard Bus and Connect!ons are exposed to the following environment:

o Air -outdoor Aging Effects Requiring Management There are no aging effects identified as requiring management for theSwitchyard Bus and Connections componel'1ts (See Section 3.6.2.2.3). Aging Management Programs There are no aging effects identified as requIring management; therefore, no aging management .programs are required for the Switchyard Bus and Connections components. 3.6.2.1.4 Transmission Conductors and Connections The Transmission Conductors and Connections commodity group is evaluated for aging management as follows: . Materials Transmission conductors are Type ACSR (aluminum conductor steel reinforced). The . materials of construction for the Transmission Conductor and Connection components are:

• Aluminum
• Galvanized Steel
• Stainless Steel Environments The Transmission Conductor and Connection components are exposed to the following environment:
• Air -outdoor Aging Effects Requiring Management There are no aging effects identified as requiring management for the Transmission Conductor and Connection components (See Section 3.6.2.2.3).

Aging Management Review Results Page 3.6-5 January 20.10. Columbia Generating Station License Renewal Application Technical Information Aging Management Programs There are no aging effects identified as requiring management; therefore, no aging management programs are required for the Transmission Conductors and Connections components. 3.6.2.1.5 Uninsulated Ground Conductors and Connections The Uninsulated Ground Conductors and Connections commodity group is evaluated for aging management as follows: Materials The material of construction for the Uninsulated Ground Conductors and Connections is:* Copper EnvironmentsThe Uninsulated Ground Conductors and Connections are exposed to the following environments: " Air- outdoor" Soil, Aging Effects Requiring Management There are no aging effects identified as requiring management for the Uninsulated Ground Conductors and Connections components. Aging Management Programs There are no aging effects identified as requiring management; therefore, no aging management programs are required for the Uninsulated Ground Conductors and Connections components. 3.6.2.1.6 High-Voltage Insulators The High-Voltage Insulators commodity group is evaluated for aging management as follows: Materials The materials of construction for the High-Voltage Insulators are:* Cement* Galvanized Metal Aging Management Review Results Page 3.6-6 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Aging Management Programs There are no aging effects identified as requiring management; therefore, no aging management programs are required for the Transmission Conductors and Connections components.

3.6.2.1.5 Uninsulated Ground Conductors and Connections The Uninsulated Ground Conductors and Connections commodity group is evaluated for aging management as follows: ' . Materials The material of construction for the Uninsulated Ground Conductors and Connections is:

• Copper Environments The Uninsulated Ground Conductors and Connections are exposed to the following environments:
• Air -outdoor
• SoiL Aging Effects Requiring Management There are no aging effects identified as reqUiring management for the Uninsulated Ground Conductors and Connections components.

Aging Management Programs There are no aging effects' identified as requlnng management; therefore, no aging management programs are required for the Uninsulated Ground Conductors and Connections components. 3.6.2.1.6 High-Voltage Insulators The High-Voltage Insulators commodity group is evaluated for aging management as follows: Materials The materials of construction for the High-Voltage Insulators are:

• Cement
• Galvanized Metal Aging Management Review Results Page 3.6-6 January 2010 *
• Columbia Generating Station License Renewal Application Technical Information
• Porcelain* Stainless Steel Environments The High-Voltage Insulators are exposed to the following environment:
• Air- outdoor Aging Effects Requiring Management The following aging effect requires management for the High-Voltage Insulator components:
• Degradation of Insulator Quality Aging Management Programs The following aging management program manages the aging. effects for the High-Voltage Insulator components:
• High-Voltage Porcelain Insulators Aging Management Program3.6.2.2 Further Evaluation of Aging Management as Recommended by NUREG-1801 For theý electrical and instrumentation and control (I&C) components, the items thatrequire further evaluation are addressed in the following sections.3.6.2.2.1 Electrical Equipment Subject to Environmental Qualification Analyses for environmental qualification of components with qualified lives of 40 years or greater are time-limited aging analyses, as defined in 10 CFR 54.3. The time-limited aging analyses are required to be evaluated in accordance with 10 CFR 54.21(c).

The evaluation of this time-limited aging analysis is addressed in Section 4.4, Environmental Qualification of Electrical Equipment. 3;6.2.2.2 Degradation of Insulator Quality due to Presence of Any Salt Deposits and Surface Contamination, and Loss of Material due to Mechanical Wear For Columbia, the deposition of contaminants on the high voltage insulators (in the 500-kV system) in the plant transformer yard has caused plant trips in the past. The root cause evaluations concluded-that the specific meteorological conditions (i.e., the wind and. temperature) at the time, along with the associated plume from the cooling towers (which slumped over the power block into the transformer yard), allowed a coating of ice to form, which also trapped liquid water containing minerals on the surface of the insulators, thereby allowing electrical tracking to occur. The corrective action was to implement a program to clean the insulators every two years. The event re-occurred on Aging Management Review Results Page 3.6-7 January 2010*

• Porcelain
• Stainless Steel Environments Columbia Generating Station License Renewal Application Technical Information The High-Voltage Insulators are exposed to the following environment:
• Air -outdoor Aging Effects Requiring Management The following aging requires management for the High-Voltage Insulator components:
• Degradation of Insulator Quality Aging Management Programs The following aging management program manages the aging. effects for the Voltage Insulator components: * . High-Voltage Porcelain Insulators Aging Management Program
• 3.6.2.2 Further Evaluation of Aging Management as Recommended by NUREG-1801 For the* electrical and instrumentation and control (I&C) components, the items that require further evaluation are addressed in the following sections.

3.6.2.2.1 Electrical Equipment Subject to Environmental Qualification Analyses for environmental qualification of components with qualified lives of 40 years or greater are time-limited aging analyses, as <;Iefined in1 0 CFR 54.3. The time-limited aging analyses are required to be evaluated in accordance with 10 CFR 54.21(c). The evaluation of this time-:-limited aging analysis is addressed in Section 4.4, Environmental Qualification of Electrical Equipment. . 3.6.2.2.2 Degradation of Insulator Quality due to Presence of Any Salt Deposits and Surface Contamination, and Loss of Material due to Mechanical Wear For Columbia, the deposition of contaminants on the high voltage insulators (in the 500-kV system) in the plant yard has caused plant trips in the past. The root cause evaluations the specific meteorological conditions (Le., the wind and. temperature) at the time, along with the associated plume from the cooling towers (which slumped over the power block into the transformer yard), allowed a coating of ice to form, which also trapped liquid water containing minerals on the surface of the' insulators, thereby allowing electrical tracking to occur. The corrective action was to

• implement a program to clean the insulators every two years. The event re-occurred on Aging Management Review Results Page 3.6-7 January 2010 Columbia Generating Station License Renewal Application Technical Information the 500-kV system. Additional testing was performed, which resulted in developing a coating system that has proven effective in mitigating the flashover when reapplied at least every 10 years.Due to the operating experience with the 500-kV system, Columbia instituted a program to clean the high voltage insulators on the 115-kV system, identified for license renewal as the plant-specific High-Voltage Porcelain Insulators Aging Management Program, in order to manage the build-up of hard water residue from the cooling tower plume, and thereby mitigate potential degradation of the insulation function.

This program allows for the option to either hand clean the in-scope high voltage insulators every two years or to coat the insulators every 10 years and inspect the coating for damage every two years between coatings. The operating experience indicates that this is only an issue with station post insulators. There are no station post insulators associated with the 230-kV system in the Columbia transformer yard, therefore the 230-kV system is.excluded. Loss of material due to mechanical wear is an aging effect for certain strain insulators if they are subject to significant movement. Such movement of the insulators can be caused by wind blowing the supported transmission conductor, causing it to sway from side to side. If this swinging motion occurs frequently enough, it could cause wear on the metallic contact points of the insulator string and between an insulator and the supporting hardware. Although this aging mechanism is possible, industry experience has shown that transmission conductors do not normally swing unless subjected to a substantial wind, and they stop swinging shortly after the wind subsides. Wind loading that can result in conductor sway is considered in the transmission system design. For insulators that are associated with switchyard bus, movement is precluded by the rigid design of the switchyard bus (i.e., the bus is of short length, is rigid itself, and is connected to rigid components). Review of operating experience has identified no concerns related to the occurrence of loss of material due to mechanical wear as a result of wind blowing on transmission conductors and the switchyard high voltageinsulators. Therefore, loss of material due to mechanical wear is not an aging effect requiring management for the high voltage insulators at Columbia.3.6.2.2.3 Loss of Material due toWind Induced Abrasion and Fatigue, Loss ofConductor Strength due to Corrosion, and Increased Resistance of Connection due to Oxidation or Loss of Pre-LoadThe switchyard bus which connects Back-up Transformer E-TR-B to circuit breaker E-CB-TRB and the bus between the 230 kV overhead line and circuit breaker A809 is within the scope of license renewal at Columbia. These are aluminum tube. The switchyard bus is connected to flexible connectors that do not normally vibrate and are supported by insulators and ultimately by structural components such as concrete footings and structural steel. With no connection to moving or vibrating equipment, vibration is therefore not an applicable aging mechanism. The aluminum bus will form a Aging Management Review Results Page 3.6-8 January 2010 Columbia Generating Station License Renewal Application

• Technical Information the SOO-kV system. Additional testing was performed, which resulted in developing a coating system that has proven effective in mitigating the flashover when reapplied at . least every 10 years. Due to the operating experience with the SOO-kV system, Columbia instituted a program to clean the high voltage insulators on the 11S-kV system, identified for license renewal as the plant-specific High-Voltage Porcelain Insulators Aging Management Progra'm, in order to manage the build-up of hard water residue from the cooling tower plume, and thereby mitigate potential degradation of the insulation function.

This program allows for the option to either hand clean the in-scope high voltage insulators every two years or to coat the insulators every 10 years and inspect the coating for damage every two years between coatings. The operating experience indicates that this is only an issue with station post insulators. There are no station post insulators associated with the 230-kV system in the Columbia transformer yard, therefore the 230-kV system is excluded. Loss of material due to mechanical wear is an aging effect for certain strain insulators if they are subject to significant movement. Such movement of the insulators can be caused by wind blowing the supported transmission conductor, causing it to sway from side to side. If this swinging motion occurs frequently enough, it could cause wear on the metallic contact pOints of the insulator string and between an insulator and the supporting hardware. Although this aging mechanism is pOSSible, industry experience

• has shown that transmission conductors do not normally swing unless subjected to a substantial wind, and they stop swinging shortly after the wind subsides.

Wind loading that can result in conductor sway is considered in the transmission system design. For insulators that are associated with switchyard bus, movement is precluded by the rigid design of the switchyard bus (Le., the bus is of short length, is rigid itself, and is connected to rigid components). Review of operating experience has identified no concerns related to the occurrence of loss of material due to mechanical wear as a result of wind blowing on transmission .conductors and the switchyard high voltage insulators. Therefore, . loss of material due to mechanical wear is not an aging effect management for the high voltage insulators at Columbia. 3.6.2.2.3 Loss of Material due to.Wind Induced Abrasion and Fatigue, Loss of Conductor Strength due to Corrosion, and Increased Resistance of Connection due to Oxidation or Loss of Pre-Load The switchyard bus which connects Back-up Transformer E-TR-B to circuit breaker CB-TRB and the bus between the 230 kV overhead line and circuit breaker A809 is within the scope of license renewal at Columbia. These are aluminum tube. The switchyard bus is connected to flexible connectors that do not normally vibrate and are supported by insulators and ultimately by structural components such as concrete footings and structural steel. With no connection. to moving or vibrating equipment, vibration is therefore not an applicable aging mechanism. The aluminum bus will form a Aging Management Review Results Page 3.6-8 . January 2010

• Columbia Generating StationLicense Renewal Application Technical Information very thin surface layer of oxidation, but the tube itself does not oxidize and theconductor properties are not degraded by a thin surface oxidation layer. The Columbia applications incorporate the use of galvanized or stainless steel "Belleville" washers on bolted electrical connections using galvanized or stainless steel bolts, nuts, and washers to compensate for temperature changes and to maintain the proper tightness.

The bolted connections are exposed to the ambient service conditions in the switchyard bus locations at Columbia (in the plant transformer yard and in the Ashe substation), and do not experience any aging effects that require management. From EPRI. TR-104213 ("Bolted Joint Maintenance & Applications Guide"), Section 15.7.5.3, ANSI B18.21.1 ("Lock Washers") has not changed since 1972. Prior to that.year, it was designated ASA B27.1 (1965). The specification was changed in 1972regarding embrittlement. Prior to 1972, there was no statement made to prevent possible hydrogen embrittlement if the washers were plated. Because construction of the Columbia transformer yard post-dates 1972, there is strong assurance that the washers used at Columbia are not subject to hydrogen embrittlement. Wind-induced abrasion and fatigue are not aging effects applicable to the in-scopetransmission conductors. Industry experience has shown that transmission conductors do not normally swing unless subjected to substantial winds, and they stop swinging after a short period once the wind subsides. Because the transmission conductors are not normally moving, the loss of material due to wind-induced abrasion and fatigue is not an aging effect requiring management. Loss of conductor strength due to corrosion of the transmission conductor is not identified as an aging effect due to ample design margin and a minimal corrosion process at the rural location of Columbia. Connection resistance is not identified as a stressor based on use of good bolting practices and review of site operating experience. EPRI Report 1013475, the License Renewal Electrical Handbook, concludes that the most prevalent aging mechanism contributing to loss of conductor strength of ACSR (aluminum conductor steel reinforced) transmission conductors is corrosion. For ACSRconductors, degradation begins as a loss of zinc from the galvanized steel core wires.Corrosion rates depend largely on air quality, which involves suspended particles in the air, sulfur dioxide (SO 2) concentration, rain, fog chemistry, and other weather conditions. Corrosion of ACSR conductors is a very slow process that is even slower in rural areas with less air pollution. Columbia is located in a rural area in east-central Washington state, where airborne particle concentrations are low.Tests performed by Ontario Hydroelectric showed a 30 percent composite loss of conductor strength for an 80 year-old sample of an ACSR conductor (due to corrosion). The Ontario Hydroelectric Test Report is available from the Institute of Electrical and Electronics Engineers (IEEE). The report is documented in two parts in the IEEE Transactions on Power Delivery, Volume 7, Number 2, April 1992©. The papers present the test methods and results of both field and laboratory tests on samples of ACSR Aging Management Review Results Page 3.6-9 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information very thin surface layer of oxidation, but. the tube itself 90es not oxidize and the conductor properties are not degraded by a thin oxidation layer. The Columbia applications incorporate the use of galvanized or stainless steel "Belleville" washers on bolted* electrical connections using galvanized or stainless steel bolts, nuts, and washers to compensate for temperature changes and to maintain the proper tightness.

The bolted connections are exposed to the ambient service conditions in the switchyard bus locations at Columbia (in the plant transformer yard and in the Ashe substation), and do not experience any aging effects that require management. From EPRI. TR-1 0421 ("Bolted Joint Maintenance & Applications Guide"), Section 15.7.5.3, ANSI B18.21.1 ("Lock Washers") has not changed since 1972. Prior to that year, it was designated ASA B27.1 (1965). The specification was changed in 1972 regarding embrittlement. Prior to 1972, there was no statement made to prevent possible hydrogen embrittlement if the washers were plated. Because construction of the Columbia transformer yard post-dates 1972, there is strong assurance that the washers used at Columbia are not subject to hydrogen embrittlement. Wind-induced abrasion and fatigue are not aging effects applicable to the in-scope transmission cooductors. Industry experience has shown that transmission conductors do not normally swing unless subjected to substantial winds, and they stop swinging after a short period once the wind subsides. Because the transmission conductors are not normally moving, the loss of material due to wind-induced abrasion and fatigue is not an aging effect requiring management. Loss of conductor strength due to corrosion of the transmission conductor is not identified as an aging effect due to ample design margin and a minimal corrosion process at the rural location of Columbia. Connection resistance is not identified as a stressor based on use of good bolting practices and review of site operating experience. EPRI Report 1013475, the License Renewal Electrical Handbook,concludes that the* most prevalent aging mechanism contributing to loss of conductor strength of ACSR (aluminum conductor steel reinforced) transmission is corrosion. For ACSR conductors, degradation begins as a loss of zinc from the galvanized steel core wires. Corrosion rates depend largely on air quality, which involves suspended particles in the air, sulfur dioxide (502) concentration, rain, fog chemistry, and other weather conditions. Corrosion of ACSR conductors is a very slow process that is even slower in rural areas with less air pollution. Columbia is located in a rural area in east-central Washington state, where airborne particle concentrations are low . . Tests performed by Ontario Hydroelectric showed a 30 percent composite loss of conductor strength for an 80 year-old sample of an ACSR conductor (due to corrosion). The Ontario Hydroelectric Test Report is available from the Institute of Electrical and Eiectroqics Engineers (IEEE). The report is documented in two parts in the IEEE Transactions on Power Delivery, Volume 7, Number 2, April 1992©. The papers present the test methods and results of both field and laboratory tests on samples of ACSR Aging Management Review Results Page 3.6-9 January 2010 Columbia Generating Station License Renewal Application Technical Information (aluminum conductor, steel reinforced) conductors from Ontario Hydroelectric's older transmission lines. The field testing involved detection of steel core galvanizing loss via the use of an overhead line conductor corrosion detector. Laboratory tests (using a dynamometer) were performed for fatigue, tensile strength, torsional ductility, and electrical performance. The report also addressed metallurgical data and analysis of potential environmental contributors. With respect to the Ontario Hydroelectric study, the National Electrical Safety Code (NESC) requires that tension on installed conductors be a maximum of 60 percent of the ultimate conductor strength and that consideration for ice, wind, and temperature be included in the design. The discussion in EPRI 1013475 demonstrates that with a 30 percent loss of conductor strength, there is still margin between the NESC requirements and the actual 'conductor strength. Because the Columbia transmission conductor design and installation meets the NESC requirements, the Ontario Hydroelectric study bounds the Columbia configuration. The specific comparisons are addressed below.The transmission conductors within the scope of license renewal are "Drake" ACSR 795 MCM (thousand circular mils) with a 26/7 stranding (for the 230-kV system). The Ontario Hydro testing included ACSR with the same stranding configuration as the Columbia transmission conductors. The Columbia transmission conductors have an ultimate strength of 31,200 pounds for the "Drake" configuration. The "Drake" conductor has a maximum design working tension of 8,000 pounds. Because the Ontario Hydro study demonstrated a 30 percent loss of ultimate strength in an 80 year-old conductor, the Columbia transmission conductors are shown to demonstrate the following: Normal margin (ultimate versus maximum design tension): "Drake" -(31,200 -8,000) / (31,200) = 0.74 x 100 = 74 percentAged margin (assuming a 30 percent loss of ultimate strength): ".Drake" -[(0.7)*(31,200) -8,000] [(31,200)*(0.7)] = 0.63 x 100 = 63 percent This demonstrates that (using the Ontario Hydroelectric test data) the Columbiatransmission conductors will have greater than 63 percent ultimate strength margin remaining after 80 years.Therefore, based on the expected low corrosion rates due to plant location and the margins included in the design, corrosion of the transmission conductors is not an aging effect requiring management for the period of extended operation. Increased connection resistance is not identified as an aging effect requiring management. Bolted connections associated with the transmission conductors employ the use of good bolting practices consistent with the recommendations of EPRI 1003471, "Electrical Connector Application Guidelines." The preferred hardware for the connections is stainless steel. The Columbia applications incorporate the use of Aging Management Review Results Aging Management Review Results Page 3.6-10 January 2010 Page 3.6-10 January 2010 Columbia Generating Station License Renewal Application Technical Information (aluminum conductor* steel reinforced) conductors from Ontario Hydroelectric's older transmission lines. The field testing involved detection of steel core galvanizing loss via the use of an overhead line conductor corrosion detector. Laboratory tests (using a dynamometer) were performed for fatigue, tensile strength, torsional ductility, and electrical performance. The report also addressed metallurgical data and analysis of potential environmental contributors. With respect to the Ontario Hydroelectric study, the National Electrical Safety Code (NESC) requires that tension on installed conductors be a maximum of 60 percent of the ultimate conductor strength and that consideration for ice, wind, and temperature be included in the design. The discussion in EPRI 1013475 demonstrates that with a 30 percent loss of conductor strength, there is still margin between the NESC requirements and the actual 'conductor strength. Because the Columbia transmission conductor design and installation meets the NESC requirements, the Ontario Hydroelectric study bounds the Columbia configuration. The specific comparisons are addressed below. The transmission conductors within the scope of license renewal are "Drake" ACSR 795 MCM (thousand circular mils) with a 26/7 stranding (for the 230,.kV system). The Ontario Hydro testing included ACSR with the same stranding configuration as the Columbia transmission conductors. The Columbia transmission conductors have an ultimate strength of 31 ,200 pounds for the "Drake" configuration. The "Drake" has a maximum design working tension of 8,000 pounds. Because the Ontario Hydro study, demonstrated a 30 percent loss of ultimate strength in an 80 year-old conductor, the Columbia transmission conductors are shown to demonstrate the following: Normal margin (ultimate versus maximum design tension): "Drake" -(31,200 -8,000) / (31,200) = 0.74 x 100= 74 percent Aged margin (assuming a 30 percent loss of ultimate strength): "Drake" -[(0.7)*(31,200) -8,000] / [(31,200)*(0.7)] = 0.63 x 100 = 63 percent This demonstrates that (using the Ontario Hydroelectric test data) the Columbia transmission conductors will have greater than 63 percent ultimate strength margin remaining after 80 years. . Therefore, based on the expected low corrosion rates due to plant location and the margins included in the design, corrosion of the transmission conductors is not an aging effect requiring management for the period of extended operation. Increased connection resistance is not identified as an aging effect requiring management. Bolted connections associated with the transmission conductors employ the use of good bolting practices consistent with the recommendations of EPRI. 1003471, "Electrical Connector Application Guidelines." The preferred hardware for the connections is stainless steel. The Columbia applications incorporate the use of Aging Management Review Results Page 3.6-10 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information stainless steel "Belleville" washers on bolted electrical connections using stainless steel bolts, nuts, and washers to compensate for temperature changes and to maintain the proper tightness.

Aluminum hardware is also used for aluminum to aluminum bus connections, but stainless steel is preferred. Use of aluminum fasteners with aluminum bus minimizes any differences in thermal expansion that could lead to loss of pre-load.In addition, design installation drawings provide guidance on bolted joints (copper to aluminum, aluminum to aluminum, and aluminum to copper). Design documents also require the use of an electrical joint compound, to be used in accordance with the manufacturer's recommendations. These methods of assembly (particularly the use of the "Belleville" washers) are consistent with EPRI 1003471. The review of site operating experience revealed no bolted connection failures associated withtransmission conductors. 3.6.2.2.4 Quality Assurance for Aging Management of Non-safety Related Components Quality Assurance provisions applicable to license renewal are discussed in Appendix B, Section B.1.3.3.6.2.3 Time-Limited Aging Analyses The time-limited aging analyses identified below are associated with the electrical and I&C components. The section of the application that contains the time-limited aging analysis review results is indicated in parentheses. Analyses for Environmental Qualification of components with a qualified life of 40 years or greater (Section 4.4, Environmental Qualification of Electrical Equipment)

3.6.3 ConclusionsThe

electrical and I&C components and commodities subject to aging management review have been identified in accordance with 10 CFR 54.21. The aging management programs selected to manage the effects of aging for the electrical components and commodities are identified in the following tables and Section 3.6.2.1. A description of the aging management programs is provided in Appendix B of this application, along with the demonstration that the identified aging effects will be managed for the period of extended operation. Therefore, based on the demonstrations provided in Appendix B, the effects of aging associated with the electrical and I&C components and commodities will be managed so that there is reasonable assurance' that the intended functions will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Review Results Aging Management Review Results Page 3.6-11 January 2010 Page 3.6-11 January 2010* * * . Columbia Generating Station License Renewal Application Technical Information stainless steel washers on bolted electrical connections using stainless steel bolts, nuts, and washers to compensate for temperature changes and to maintain the proper tightness. Aluminum hardware is also used for aluminum to aluminum bus connections, but stainless steel is preferred. Use of aluminum with aluminum bus minimizes any differences in thermal expansion that could lead to loss of pre-load. In addition, design installation drawings provide guidance on bolted joints (co'pper to aluminum, aluminum to aluminum, and aluminum to copper). Design documents also require the use of an electrical joint compound, to be used in accordance with the manufacturer's recommendations. These methods of assembly (particularly the use of the "Belleville" washers) are consistent with EPRI 1003471. The review of site operating experience revealed no bolted. connection failures associated with transmission conductors. 3.6.2.2.4 Quality Assurance for Aging Management of Non-safety Related. Components Quality Assurance provisions applicable to license renewal are discussed in Appendix B, Section B.1.3. . 3.6.2.3 Time-Limited Aging Analyses Th,e* time-limited aging analyses identified below are associated with the electrical and , I&C components. The! section of the application that contains the time-limited aging analysis review results is indicated in parentheses.

• Analyses for Environmental Qualification of components with a qualified life of 40 years or greater (Section 4.4, Environmental Qualification of Electrical Equipment)

3.6.3 Conclusions

The electrical and I&C components and commodities subject to aging management review have been identified in accordance with 10 CFR 54.21. The aging management . programs selected to manage the effects of aging for the electrical components and commodities are identified in the following tables and Section 3,6.2.1. A description of the aging management programs is provided in Appendix B of this application, along with the demonstration that the identified aging effects will be managed for the period of extended operation. . Therefore, based on the demonstrations provided in Appendix B, the effects of aging associated with the and I&C components and commodities will be managed so that there is reasonable assurance'that the intended functiqns will be maintained consistent with the current licensing basis during the period of extended operation . Aging Management Review Results Page 3.6-11 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1801 Further Item dity Aging Effect! ýAging Management Evaluation Discussion Number Component/CommodityMechanism Programs Recommended D 3.6.1-01 Electrical equipment subject to Degradation due to Environmental Yes, TLAA This TLAA is evaluated in 10 CFR 50.49 environmental various aging Qualification of Electrical Section 4.4.qualification (EQ) requirements mechanisms Components Refer to Section 3.6.2.2.1 for further information. 3.6.1-02 Electrical cables, connections, Reduced insulation Electrical Cables and No Consistent with NUREG-1801. and fuse holders (insulation) not resistance and Connections Not Subject subject to 10 CFR 50.49 EQ electrical failure due to 10 CFR 50.49 EQ requirements to various physical, Requirements thermal, radiolytic, photolytic, and chemical mechanisms3.6.1-03 Conductor insulation for Reduced insulation Electrical Cables and No Consistent with NUREG-1801_ electrical cables and connections resistance and Connections Used in used in instrumentation circuits electrical failure due Instrumentation Circuits not subject to 10 CFR 50.49 EQ to various physical, Not Subject to 10 CFR requirements that are sensitive thermal, radiolytic, 50.49 EQ Requirements to reduction in conductor photolytic, and insulation resistance (IR) chemical mechanisms 3.6.1-04 Conductor insulation for Localized damage Inaccessible Medium- No Consistent with NUREG-1 801. inaccessible medium voltage (2- and breakdown of Voltage Cables Not kV to 35-kV) cables (e.g., insulation leading to Subject to 10 CFR 50.49 installed in conduit or direct electrical failure due EQ Requirements buried) not subject to to moisture intrusion, 10 CFR 50.49 EQ requirements water trees Aging Management Review Results Page 3.6-12 January 2010 Aging Management Review Results Page 3.6-12 January 2010 Columbia Generating Station' License Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1801 Item Aging Effect!

• Aging Management Further Component!Commodity Evaluation Discussion Number Mechanism Programs Recommended 3.6.1-01 Electrical equipment subject to Degradation due to Environmental Yes, TLAA This TLAA is evaluated in 10 CFR 50.49 environmental various aging Qualification of Electrical Section 4.4. qualification (EQ) requirements mechanisms Components Refer to Section 3.6.2.2.1 for further information.

3.6.1-02 Electrical cables, connections, Reduced insulation Electrical Cables and No Consistent with NUREG-1801. and fuse holders (insulation) not resistance and Connections Not Subject -' . subject to 10 CFR 50.49 EQ electrical failure due to 10 CFR 50.49 EQ " requirements to various physical, Requirements thermal, radiolytic, photolytic, and chemical mechanisms 3.6.1-03 Conductor insulation for Reduced insulation Electrical Cables and No Consistent with NUREG-1801:- electrical cables and connections resistance and Connections Used in used in instrumentation circuits electrical failure due Instrumentation Circuits not subject to 10 CFR 50.49 EQ to various physical, Not Subject to 10 CFR requirements that are sensitive thermal, radiolytic, 50.49 EQ Requirements to reduction in conductor photolytic, and insulation resistance (IR) chemical mechanisms 3.6.1-04 Conductor insulation for Localized damage Inaccessible Medium-No Consistent with NUREG-1801. inaccessible medium voltage (2-and breakdown of Voltage Cables Not kV to 35-kV) cables (e.g., insulation leading to Subject to 10 CFR 50.49 installed in conduit or direct electrical failure due EQ Requirements buried) not subject to to moisture intrusion, 10 CFR 50.49 EQ requirements water trees Aging Management Review Results. Page 3.6-12 January 2010 * *

• 0 Columbia Generating StationLicense Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1 801 Further Item o n Aging Effect/ Aging Management Euatis s CmoetCmoiyEvaluation Discussion Number Mechanism Programs Recommended 3.6.1-05 Connector contacts for electrical Corrosion of Boric Acid Corrosion No Not applicable for Columbia..

connectors exposed to. borated ......ector contact I,, .,I water leakage surfaces due to Columbia is a BWR and does intrusion of borated not use boric acid in any water systems. The Standby Liquid Control System uses a sodium pentaborate solution (a mixture of boric acid and borax) that is not aggressive to metals.Aging Management Review Results Page 3.6-13 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1801 Item/ Aging Effectl Aging Management Further ComponentiCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.6.1-05 Connector contacts for electrical Corrosion of Boric Acid Corrosion No Not applicable for Columbia .. connectors exposed to borated ______ , ............................

_f. l"UIIIIC\"lUI \"VII La", .. water leakage surfaces due to Columbia is a BWR and does intrusion of borated \ not use boric acid in any water systems. The Standby Liquid Control System uses a sodium pentaborate solution (a mixture -of boric acid and borax) that is not aggressive to metals. Aging Management Review Results Page 3.6-13 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1801 I Further Item Component/Commodi Aging Effect/ Aging Management Evaluation Discussion Number ty Mechanism I Programs Recommended 3.6.1-06 Fuse Holders (Not Part of a Fatigue due to Fuse Holders No Not applicable for Columbia.Larger Assembly): ohmic heating, thermal cycling, The aging effects detailed in Fuse Holders -metallic clamp electrical transients, NUREG-1 801 are not applicable frequent for this item. None of the fuse manipulation, holders that are within the scope vibration, chemical of license renewal contain fuses contamination, that are frequently manipulated. corrosion, and Inspection of a sample of the oxidation passive fuse boxes found the condition to be clean and dry, with no signs of contamination orcorrosion or moisture intrusion. Similarly, ohmic heating, thermal cycling, electrical transients, and vibration do not apply to the passive fuse boxes at Columbia because the fuses are not heavily loaded (in their installed applications) and do not experience frequent electrical and thermal cycling. Power fuses are bolted to maintain electrical contact. Vibration is an induced aging mechanism, and is not applicable because the electrical boxes are securely mounted on walls.Aging Management Review Results Page 3.6-14 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1801 . Item Aging Effectl Aging Management Further ComponentlCommodity Evaluation Discussion Number Mechanism Programs Recommended 3.6.1-06 Fuse Holders (Not Part of a Fatigue due to Fuse Holders No Not applicable for Columbia. Larger Assembly): ohmic heating, thermal cycling, The aging effects detailed in Fuse Holders -metallic clamp electrical transients, NUREG-1801 are not applicable frequent for this item. None of the fuse manipulation, holders that are within the scope vibratfon, chemical of license renewal contain fuses contamination, that are frequently manipulated. corrosion, and Inspection of a sample of the oxidation passive fuse boxes found the condition to be clean and dry, with no signs of contamination or corrosion or moisture intrusion. Similarly, ohmic heating, thermal cycling, electrical transients, and vibration do not apply to the passive fuse boxes at Columbia because the fuses are not heavily loaded (in their installed applications) and do not experience frequent electrical and thermal cycling. Power fuses are bolted to maintain electrical contact. Vibration is an , induced aging mechanism, and is not applicable because the electrical boxes are securely mounted on walls. Aging Management Review Results Page 3.6-14 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1 801 Item Aging Effect/ Aging Management Further Component/Commodity Evaluation Discussion Number Mechanism ProgramsReomnd

__ _____ ___ ____ ______Recommended _ _ _ _ _3.6.1-071 Metal-enclosed bus -Loosening of bolted Metal-Enclosed Bus No Consistent with NUREG-1 801,*connections due to with exceptions The Metal-Bus/connections thermal cycling and Enclosed Bus Program is ohmic heating credited.3.6.1-08 Metal-enclosed bus -Reduced insulation Metal-Enclosed Bus No Consistent with NUREG-1 801, resistance and with exceptions. The Metal-Insulation/insulators electrical failure due Enclosed Bus Program is to various physical, credited.. thermal, radiolytic, photolytic, and chemical mechanisms3.6.1-09 Metal-enclosed bus -Loss of material due Structures Monitoring No Consistent with NUREG-1 801.to general corrosion Program Enclosure assemblies3.6.1-10 Metal-enclosed bus -Hardening and loss Structures Monitoring No Consistent with NUREG-1 801 of strength due to Program item for material, environment, Enclosure Assemblies elastomer and aging effect, but a different degradation aging management program is credited. The Metal-EnclosedBus Program is credited.Aging Management Review Results Page 3.6-15 January 2010*

• Columbia Generating Station License Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1801 Item Aging Effectl Aging Management Further ComponentiCommod ity -Evaluation Discussion Number Mechanism Programs Recommended 3.6.1-07 Metal-enclosed bus -Loosening of bolted Metal-Enclosed Bus No Consistent with NUREG-1801, connections due to with exceptions.

The Metal-Bus/connections thermal cycling and Enclosed Bus Program is f ohmic heating credited. Metal-enclosed bus -Reduced insulation Metal-Enclosed Bus No Consistent with NUREG-1801, resistance and with exceptions. The Metal-Insulation/insulators electrical failure due Enclosed Bus Program is to various physical, credited ..

• thermal, radiolytic, photolytic, and .-chemical mechanisms 3.6.1-09 Metal-enclosed bus -Loss of material due Structures Monitoring No Consistent with NUREG-1801.

to general corrosion Program Enclosure assemblies 3.6.1-10 bus -Hardening and loss Structures Monitoring No Consistent with NUREG-1801 of strength due to Program item for material, environment, Enclosure Assemblies elastome*r and aging effect, but a different degradation aging management program is credited. The Metal-Enclosed -Bus Program is credited. Aging Management Review Results Page 3.6-15 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1 801 Item Aging Effect/ Aging Management Further Number Component/Commodity Mechanism Programs Evaluation Discussion Recommended 3.6.1-11 High-Voltage Insulators Degradation of A plant-specific aging Yes, plant- The High-Voltage Porcelain insulation quality management program is specific Insulators Aging Management due to the presence to be evaluated Program is credited.of any salt deposits and surface Loss of material due to wear is contamination; not an applicable aging effect for Loss of material the in-scope high-voltage caused by insulators at Columbia. Refer to mechanical wear Section 3.6.2.2.2 for further due to wind blowing information. on transmission conductors 3.6.1-12 Transmission conductors and Loss of material due A plant-specificaging Yes, plant- No aging effects are identified as connections; to wind-induced management program is specific requiring aging management. abrasion and to be evaluated Switchyard bus and connections fatigue; Refer to Section 3.6.2.2.3 for Loss of conductor further information. strength due to corrosion, increased resistance of connection due to oxidation or loss of pre-load Aging Management Review Results Page 3.6-16 January 2010 Aging Management Review Results Page 3.6-16.January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.1 Summary of Agjng Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1801 Item Aging Effect! Aging Management Further Component!Commod ity Evaluation Discussion Number Mechanism Programs Recommended 3.6.1-11 High-Voltage Insulators Degradation of A plant-specific aging Yes, plant-The High-Voltage Porcelain insulation quality management program is specific Insulators Aging Management due to the presence to be evaluated Program is credited. of any salt deposits and surface Loss of material due to wear is contamination; not an applicable aging effect for Loss of material the in-scope high-voltage caused by insulators at Columbia. Refer to mechanical wear Section 3.6.2.2.2 for further due to wind blowing information. on transmission conductors , 3.6.1-12 Transmission conductors and Loss of material due A plant-specific/aging Yes, plant-No aging effects are identified as connections; to wind-induced management program is specific requiring aging management. abrasion and to be evaluated Switchyard bus and connections fatigue; Refer to Section 3.6.2.2.3 for Loss of conductor further information. strength due to , corrosion, increased resistance of -connection due to oxidation or loss of pre-load Aging Management Review Results Page 3.6-16 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1801 I Further Item Aging Effect/ Aging Management Euatis s Number ComponentCommodity Mechanism Programs Recommended 3.6.1-13 Cable connections

-{ Loosening of bolted J Electrical Cable No, Consistent with NUREG-1801,.LA.. I L -t I... .,-necton f , with exceptions. Metallic parts thermal cycling, to 10 CFR 50.49 ohmic heating, Environmental See Appendix B Section B.2.21.electrical transients, Qualification vibration, chemical Requirements contamination, corrosion, and oxidation 3.6.1-14 Fuse Holders (Not Part of a None None N/A- Consistent with NUREG-1801. Larger Assembly) -NoAEM or AMP Insulation Material Aging Management Review Results Page 3.6-17 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.6.1 Summary of Aging Management Programs for Electrical and I&C Components Evaluated in Chapter VI of NUREG-1801 Item Aging Effectl Aging Management Further ComponentlCommod ity Evaluation Discussion Number Mechanism Programs Recommended 3.6.1-13 Cable connections

-.. Loosening of bolted Electrical Cable No Consistent with NUREG-1801, connections due to Connections f'Jot with exceptions. Metallic parts . thermal cycling, to 10 CFR 50.49 ohmic heating, Environmental See Appendix 8 Section 8.2.21. electrical transients, Qualification vibration, chemical Requirements contamination, corrosion, and oxidation 3.6.1-14 Fuse Holders (Not Part of a None None N/A-Consistent with NUREG-1801. -Larger Assembly) -NoAEM orAMP Insulation Material Aging Management Review Results Page 3.6-17 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups Aging ýEffect INUREG-Row Component Intended Aging Management 1801 Table No. Type Function(s) Material Environment Requiring Program Volume I Item Notes Management I2 Item Loosening of bolted connections Various due to thermal Electrical Cable Cable Metals Air -indoor cycling, ohmic Connections Not heating, Connections Conduct uncontrolled electrical Subject to 10 CFR VI.A-1 3.6.1- B (Metallic Electricity (used for and 50.49 EQ 13 Parts) electrical Air -outdoor transients Requirements contact) vibration, Iseto chemical Inspection contamination, corrosion, and oxidation Aging Management Review Results Page 3.6-18 January 2010 Aging Management Review.Results Page 3.6-18 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups Aging Effect NUREG-Row Component Intended Aging Management 1801 Table No. Type Function(s) Material Environment . Requiring Program Volume 1 Item Notes Management 2 Item Loosening of 1 bolted connections Various due to thermal Electrical Cable Cable Metals Air-indoor cycling, ohmic Connections Not Connections Conduct uncontrolled heating, Subject to 10 CFR 3.6.1-1 electrical VI.A-1 8 (Metallic Electricity (used for and transients, 50.49 EO 13 Parts) electrical Air -outdoor vibration, Requirements contact) chemical Inspection contamination, corrosion, and oxidation Aging Management ReviewResults Page 3.6-18 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information*

Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups NUREG-Row Component Intended Aging Effect Aging Management 1801 Table No. Type Function(s) Material Environment Requiring Program Volume I Item Notes Management 2 Item Embrittlement, cracking, melting, discoloration, swelling, or loss of dielectric strength leading to Adverse reduced localized insulation Non- Various environment resistance (IR); Electrical Cables and Environment-electrical Connections Not allyrConduct Organic caused by failure/ Subject to 10 CFR 3.6.1-2 ally Qualified Conduct Polymers heat, VLA-2 A Insulated Electricity or degradation of 50.49 EQ 02 Cables and DSilicon radiation, organics Requirements Connections Dioxide moisture in (thermal/ Program the presence thermoxidative) of oxygen radiolysis and photolysis (UV-sensitive materials only)of organics;radiation-induced oxidation, and moisture intrusion Aging Management Review Results Page 3.6-19 January 2010 Aging Management Review Results Page 3.6-19 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information . Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups Aging Effect NUREG-Row Component Intended Aging Management 1801 Table No. Type Function(s)

Material Environment Requiring Program Volume 1.1tem Notes Management 2 Item -Embrittlement, -cracking, melting, discoloration, swelling, or loss of dielectric -, strength leading to Adverse reduced localized insulation Non-Various environment resistance (IR); Electrical Cables and Environment-Organic caused by electrical Connections Not 2 ally Qualified Conduct Polymers heat, failure/ Subject to 10 CFR VI.A-2 3.6.1-A Insulated ElectricitY radiation, or degradation of 50.49 EQ 02 Cables and Silicon organics Requirements Connections Dioxide moisture in (thermal! Program the presence of oxygen thermoxidative) radiolysis and photolysis (UV-sensitive materials only) of organics; radiation-induced oxidation, and moisture intrusion Aging Management Review Results Page 3.6-19 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups Aging ffectNUREG-Row Component Intended Aging Effect Aging Management 1801 Table No. Type Function(s) Material Environment Requiring Program Volume I Item Notes Management 2 Item Embrittlement, cracking, melting, discoloration, swelling, or loss of dielectric strength leading to Non- Adverse reduced Environment-localized insulation Electrical Cables and ally Qualified environment resistance (IR); Connections Not Sensitive, electrical Connect Not High-Voltage, Conduct Various -caused by failure/ 50.49 EQ R3.6.1- A Organic heat, ofe50.49tEQn of 03 Low-Level Electricity Polymers radiation, or degradation Requirements Used 03 Signal moisture in organics in Instrumentation Instrument the presence thermoxidative) Circuits Program Cables and of oxygen hroiave Connections radiolysis and photolysis (UV-sensitive materials only)of organics;radiation-induced oxidation, and moisture intrusion Aging Management Review Results Page 3.6-20 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups Aging Effect NUREG-. Row Component Intended Aging Management 1801 Table No. Type Function(s) Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Embrittlement, cracking, melting, discoloration, swelling, or loss of dielectric strength -leading to Non-Adverse reduced Environment- -localized insulation Electrical Cables and ally Qualified environment resistance (lR); Connections Not Sensitive, Various caused by electrical Subject to 10 CFR High-Voltage, Conduct failurel 3.6.1-3 Low-Level Electricity Organic heat, degradation of 50.49 EQ ,VI.A-3 03 A Signal* Polymers radiation, or organics Requirements Used moisture in in Instrumentation Instrument the presence (thermal/ Circuits Program Cables and thermoxidative) Connections of oxygen radiolysis and photolysis (UV-sensitive materials only) -of organics; radiation-induced oxidation, and moisture intrusion Aging Management Review Results Page 3.6-20 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results.-

Electrical Component Commodity Groups Aging Effect NUREG-Row Type Fntinds) Material Environment Requiring Aging Management 1801 Table No. Type Function(s) Management Program Volume I Item Management_ _2 Item No Aee Localized ' FT Non- Adverse damage and Inaccessible Medium-"Environment-localized breakdown Of Voltage Cables Not ally Qualified Conduct Various environment insulation Subject to 10 CFR 3.6.1-4 Medium- Electricity Organic caused by leading to S 0 CF VLA-4 04 Voltage Polymers exposure to electrical failure 5eq Power moisture and / moisture Requirements Cables voltage intrusion, -water Program___trees Aging Management Review Results Page 3.6-21 January 2010 Aging, Management Review Results Page 3.6-21 January 2010* * --* Columbia Generating Station Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical, Component Commodity Groups Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management Program Volume 1 Item 2 Item Localized Non-Adverse damage and Inaccessible Medium-. localized breakdown of. Voltage Cables Not -. ally Qualified Conduct Various environment insulation Subject to 10 CFR . 3.6.1-4 Medium-Electricity Organic caused by leading to 50.49 EQ VI.A-4 04 A Voltage Polymers exposure to electrical failure Requirements Power moisture and I moisture Cables voltage intrusion, water Program trees Aging.Management Review Results Page 3.6-21 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups Aging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) Management 'Program Volume_ Item 2 Itemhrl__n lo~rna~m nt IIColumbia Generating StationLicense Renewal ApplicationTechnical Information 5 Fuse Holders: Insulation Conduct Electricity Various Organic Polymers Adverse localized environment caused by heat, radiation, or moisture in the presence of oxygen or> 60-year service limiting temperature cracking, melting, discoloration, swelling, or loss of dielectric strength leading to reduced insulation resistance (IR);electrical failure/degradation (thermal/thermoxidative) of organics/thermoplastics; radiation-induced oxidation, moisture intrusion, and ohmic heating None Identified Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program VI.A-6 3.6.1-02 A Fuse Conduct Various flr raana Air -indoor uncontrolled None Required VI.A-7 3.6.1-14 A 6 Holoers: Electricity Insulation Polymers Aging Management Review Results Page 3.6-22 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups Aging Effect NUREG-Row Component Intended Aging Management 1801 Table No. Type Function(s) Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Embrittlement, -cracking, -melting, , discoloration, swelling, or loss of ' Adverse dielectric localized strength environment leading to caused by reduced Electrical Cables and heat, insulation Connections Not Fuse Conduct Various radiation, or resistance (IR); Subject to 1,0 CFR 3.S.1-5 Holders: Organic moisture in electrical VI.A-6 A Insulation Electricity Polymers the presence failurel 50.49 EQ 02 of oxygen or degradation Requirements > SO-year (thermal! Program service thermoxidative) limiting of organicsl temperature . thermoplastics; radiation-induced oxidation, moisture intrusion, and -ohmic heating Fuse Conduct Various Air-indoor 3.S.1-6 Holders: Electricity Organic uncontrolled None IdentifiE;!d None Required VI.A-? 14 A Insulation Polymers' -Aging Management Review Results Page3.S-22 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups IAging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s)

Management Program Volume I Item Fus2 Item Fuse I Holders: Conduct Copper Air -Indoor None Identified None Required VI.A-8 3.6.1- 0603 Metallic Electricity Alloy uncontrolled 06 0607 Clamp Porcelain, Degradation of Galvanized insulator quality High-Voltage High-Voltage Insulation Metal, / presence of Porcelain Insulators VI.A-9 3.6.1- E 8 Insulators (and support) Stainless Air -Outdoor any salt Aging Management 11 0608 I a ( s o Steenlss deposits or Program Steel, surface Cement contamination Porcelain, Galvanized 9 High-Voltage Insulation Metal, Air -Outdoor None Identified None Required VI.A-10 3.6.1-Insulators (and support) Stainless 11 0601 Steel, Cement.Aluminum /Silver Metal- Plated Loosening of Enclosed Bus Aluminum, Air -Indoor bolted 10 (bus and Conduct Copper/ uncontrolled connections I Metal-Enclosed Bus VI.A-1 1 3.6.1- B connections) Electricity Silver and thermal cycling Program 07 (non- Plated Air -Outdoor and ohmic segregated) Copper, heating Stainless Steel, Steel Aging Management Review Results Page 3.6-23 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups Aging Effect NUREG-Row Component Intended Aging Management 1801 Table No. Type Function(s) . Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Fuse I 7 Hoiders: . Conduct Copper Air -Indoor None Identified None Required VI.A-8 3.6.1-0603 .' Metallic "Electricity' Alloy uncontrolled 06 0607 Clamp Porcelain, Degradation of Galvanized insulator quality High-Voltage I presence of . 8 High-Voltage Insulation Metal, Air -Outdoor any salt Porcelain Insulators VI.A-9 3.6.1-E Insulators (and support) Stainless deposits or Aging Management 11 0608 Steel, surface Program Cement contamination Porcelain, Galvanized 9

Insulation Metal, Air -Outdoor None Identified None Required VI.A-10 3.6.1-I Insulators (and support) Stainless 11 0601 Steel, Cement" Aluminum I Silver , Metal-Plated Loosening of Enclosed Bus Aluminum, Air -Indoor bolted 10 (bus and Conduct Copper I uncontrolled* connections I Metal-Enclosed Bus VI.A-11 3.6.1-B connections) Electricity Silver and thermal cycling Program 07 (non-Plated Air -Outdoor and ohmic segregated) Copper, heating Stainless Steel, Steel Aging Management Review Results Page 3.6-23 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups dAging Effect NUREG-Row Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s) M eProgram Volume 1 Item Managementm Metal-Enclosed Bus Air -Indoor Hardening and 1 (Enclosure Elt uncontrolled loss of strength Metal-Enclosed Bus VI.A-12 3.6.1- E Assemblies) upport asomers and / elastomer Program 10 0605 (non- Air -Outdoor degradation segregated) Metal-Enclosed Bus Aluminum, Air -Indoor Loss of A (enclosure Steel, uncontrolled material / Structures Monitoring VI.A-13 03.6.1-assemblies) Support Galvanized and general 'Program 09 (non- Steel Air -Outdoor corrosion 0606 segregated) I I II Aging Management Review Results Page 3.6-24 January 2010 Aging Management Review Results Page 3.6-24 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3:6.2-1 Aging Management Review Results -Electrical Component Commodity Groups Aging Effect NUREG-Row Component Intended Aging Management 1801 Table No. Type Function(s) Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Metal-Enclosed Bus -Air -Indoor Hardening and 11 (Enclosure Support Elastomers uncontrolled loss of strength Metal-Enclosed Bus VI.A-12 3.6.1-E Assemblies) and I elastomer Program 10 0605 (non-Air-Outdoor degradation segregated) Metal-Enclosed Bus Aluminum, Air -Indoor Loss of A 12 (enclosure Support Steel, uncontrolled material I Structures Monitoring VI.A-13 3.6.1-0605 assemblies) Galvanized and general Program 09 (non-Steel Air -Outdoor corrosion

0606 segregated)

-Aging Management Review Results Page 3.6-24 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Aging Management Review Results Page 3.6-25 January 2010 Aging Management Review Results Page 3.6-25 January 2010* *
• Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Commodity Groups Aging Effect NUREG-Row ,Component Intended Material Environment Requiring Aging Management 1801 Table Notes No. Type Function(s)

Management Program Volume 1 Item 2 Item -Embrittlement, cracking, meiting, discoloration, swelling, or Joss of {, dielectric strength leading to Metal-Porcelain, reduced Enclosed Bus Fiberglass, Air -Indoor insulation (insulation Various uncontrolled resistance (IR); Metal-Enclosed Bus 3.6.1-13 and Insulation Organic and electrical Program VI.A-14 08 B insulators) Polymers Air -Outdoor failure! thermal! (non-(EPR and thermoxidative segregated) PVC tape) degradation of organics! thermoplastics; radiation-induced oxidation; moisture! debris intrusion, and ohmic heating SWitchyard Conduct Aluminum, 3.6.1-I 14 Bus and Electricity Galvanized Air -Outdoor None Identified None Required VI.A-15 12 0602 Connections Steel Aging Management Review Results Page 3.6-25 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups gEffect NUREG-Row Component Intended i Aging Management 1801 Table No. Type Function(s) Material Environment Requiring Program Volume I Item Notes Management 2 Item Transmission Aluminum, Conductors Conduct Galvanized 15 and Electricity Steel, Air -Outdoor None Identified None Required VI.A-16 12 0604 Connections Stainless Steel Uninsulated 1 Ground Conduct Air -Outdoor 16 Conductors Elect Copper and None Identified None Required N/A N/A 0609 and Electricity Soil Connections Adverse localized Electrical Vario environment organicVarious Equipment polymers caused by degradations / 3.6.1-17 Subject to 10 Various and heat, various 01 A FR 50.49 EQ ,metallic radiation, mechanisms Requirements materials oxygen, moisture, or voltage Aging Management Review Results Page 3.6-26 January 2010 Aging Management Review Results Page 3.6-26 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 3.6.2-1 Aging Management Review Results -Electrical Component Commodity Groups Aging Effect NUREG-Row Component Intended Aging Management 1801 Table No. Type Function(s) Material Environment Requiring Program Volume 1 Item Notes Management 2 Item Transmission Aluminum, Conductors Conduct Galvanized 3.6.1-I 15 and Electricity Steel, Air -Outdoor None Identified None Required VI.A-16 12 0604 Connections Stainless Steel Uninsulated Ground Conduct Air -Outdoor J 16 Conductors Electricity Copper and None Identified .. None Required N/A N/A 0609 and Soil Connections Adverse -localized Electrical Various environment Equipment organic caused by Various 17 Subject to 10 Various polymers heat, degradations I TLAA VI.B-1 3.6.1-A and various 01 CFR 50.49 EO metallic mechanisms Requirements materials oxygen, moisture, or voltage Aging Management Review Results Page 3.6-26 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Generic Notes: Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.B Consistent with NUREG-1 801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP.C Component is different, but consistent with NUREG-1 801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP.,D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1 801 AMP.E Consistent with NUREG-1 801 item for material, environment, and aging effect, but a different aging management program is credited or NUREG-1801 identifies a plant-specific aging management program.F Material not in NUREG-1801 for this component.

G Environment not in NUREG-1 801 for this component and material.H Aging effect not in NUREG-1 801 for this component, material and environment combination. I Aging effect in NUREG-1 801 for this component, material and environment combination is not applicable. J Neither the component nor the material and environment combination is evaluated in NUREG-1 801.Aging Management Review Results Page 3.6-27 January 2010 Aging Management Review Results Page 3.6-27 January 2010* *

• Columbia Generating Station*

License Renewal Application Technical Information Generic Notes: 0 e A Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP. 8 Consistent with NUREG-1801 item for component, material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP. C Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP is consistent with NUREG-1801 AMP. D Component is different, but consistent with NUREG-1801 item for material, environment, and aging effect. AMP takes some exceptions to NUREG-1801 AMP. E Consistent with NUREG-1801 item for material, environment, and aging effect, but different aging management program is credited or NUREG-1801 identifies a plant-.specific aging management program. F Material not in NUREG-1801 for this component. , G Environment not in NUREG-1801 for this component and material. H Aging effect not in NUREG-1801 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-1801. Aging Management Review Results Page 3.6,.27 January 2010 Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes: Loss of material due to wear is not an applicable aging effect for the in-scope high-voltage insulators at Columbia - see Section 3.6.2.2.2 for evaluation. 0602 For the switchyard bus and connections, no aging effects are identified that require aging management -refer to Section 3.6.2.2.3 for evaluation. A review of the Columbia fuse list and other engineering documents showed that there are no in-scope passive fuses that are pulled on a routine basis such that deformation (fatigue) would cause loosening of the fuse holder.The in-scope fuse holders at Columbia are located in metallic electrical boxes (terminal boxes) which have covers to protect the interior of the box from the ambient environment. The boxes are not exposed to weather conditions (they are located indoors); they are not exposed to chemical contamination or spills; they are not exposed to mechanical stress inside the box; and, due to the 0603 Columbia location in rural central Washington, they are not located in an evironment with industrial pollution or salt deposition. Therefore, chemical contamination, corrosion, and oxidation are not applicable aging mechanisms for the fuse holders within the license renewal scope at Columbia.With respect to electrical transients and ohmic heating, these fuses are not heavily loaded and do not experience frequent electrical and thermal cycling. With respect to vibration, it is an induced aging mechanism, and the fuse boxes are securely mounted on walls, so vibration itself is not an applicable stressor.The transmission conductors within the license renewal scope are those that connect start-up transformer E-TR-S to circuit breaker A 809 in the Ashe substation switchyard. This circuit breaker constitutes part of the station blackout license renewal boundary.0604 This segment of transmission conductor does not exhibit significant aging mechanisms or effects. An aging management program is not required for the segment of transmission conductor that is within the scope of license renewal. See Section 3.6.2.2.3 for details.The inspection of the metal-enclosed bus enclosure assembly elastomers (joints, seals, gaskets) will be performed as part of the Metal-Enclosed Bus Program. The elastomers will be inspected when the covers of the various bus enclosure sections are 0605 removed. The Structures Monitoring Program will address the metallic portion of the enclosure assembly and the external structural supports for the various bus assemblies (along with the building penetrations and seals where the bus ducts enter the Reactor Building). In addition to steel and galvanized steel, Columbia uses aluminum enclosures (a material not mentioned in NUREG-1801, Item 0606 VI.A-1 3). Note A is used, because the Structures Monitoring Program includes consideration of aluminum and is consistent with NUREG-1801. 0607 Inspection of a sample of the passive fuse boxes within the scope of license renewal (performed in September 2007) showed that conditions are clean and dry, with no corrosion or moisture intrusion found.Aging Management Review Results Page 3.6-28 January 2010 Columbia Generating Station License Renewal Application Technical Information Notes: 0601 Loss of material due to wear is not an applicable aging effect for the in-scope high-voltage insulators at Columbia -see Section 3.6.2.2.2 for evaluation. 0602 For the switchyard bus and connections, no aging effects are identified that require aging management -refer to Section 3.6.2.2.3 for evaluation. A review of the Columbia fuse list and other engineering documents showed that there are no in-scope passive fuses that are pulled on a routine basis such that deformation (fatigue) would cause loosening of the fuse holder. . The in-scope fuse holders at Columbia are located in metallic electrical boxes (terminal boxes) which have covers to protect the interior of the box from the ambient environment. The boxes are not exposed to weather conditions (they are located indoors); they are not exposed to chemical contamination or spills; they are not exposed to mechanical stress inside the box; and, due to the 0603 Columbia location in rural central Washington, they are not located in an evironment with industrial pollution or salt deposition. Therefore, chemical contamination, corrosion, and oxidation are not applicable aging mechanisms forthe fuse holders within the license renewal scope at Columbia. With respect to electrical transients and ohmic heating, these fuses are not heavily loaded and do not experience frequent electrical and thermal cycling. With respect to vibration, it is an induced aging mechanism, and the fuse boxes are securely mounted on* , walls, so vibration itself is not an applicable stressor. The transmission conductors within the license renewal scope are those that connect start-up transformer E-TR-S to circuit breaker A 809 in the Ashe substation switchyard. This circuit breaker constitutes part cif the station blackout license renewal boundary. 0604 This segment of transmission conductor does not exhibit significant aging mechanisms or effects. An aging management program is not required for the segment of transmission conductor that is within the scope of license renewal. See Section 3.6.2.2.3 for details. .. The inspection of the metal-enclosed bus enclosure assembly elastomers Ooints, seals, gaskets) will be performed as part of the Metal-Enclosed Bus Program. The elastomers will be inspected when the covers of the various bus enclosure sections are 0605 removed. The Structures Monitoring Program will address the metallic portion of the enclosure assembly and the external structural supports for the various bus assemblies (along with the building penetrations and seals where the bus ducts enter the Reactor Building).* . In addition to steel and galvanized steel, Columbia uses aluminum enclosures (a material not mentioned in NUREG-1801, Item 0606 VI.A-13). Note A is used, because the Structures Monitoring Program includes consideration of aluminum and is consistent with NUREG-1801. 0607 Inspection of a sample of the passive fuse boxes within the scope of license renewal (performed in September 2007) showed that conditions are clean and dry, with no corrosion or moisture intrusion found. Aging Management Review Results Page 3.6-28 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes: 0608 See Section 3.6.2.2.2 for a description of the surface contamination item affecting the high-voltage insulators in the Columbia.transformer yard.The uninsulated ground conductors and connections are included in the license renewal scope because they are required for fire 0609 protection (from lightning-induced fires) on certain structures and for facilitating the operation of ground fault detection devices in the event of ground fault or insulation failure on any electrical load or current (see Section 2.5.5.5).

There are no aging effects requiring management for the metallic components of thile uninsulated ground conductors and connections. Aging Man .agement Review Results Page 3.6-29 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Plant-Specific Notes: 0608 See Section 3.6.2.2.2 for a description of the surface contamination item affecting the high-voltage insulators in the Columbia . transformer yard. The uninsulated ground conductors and connections are included in the license renewal scope because they are required for fire 0609 protection (from lightning-induced fires) on certain structures and for facilitating the operation of ground fault detection devices in the event of ground fault or insulation failure on any electrical load or current (see Section 2.5.5.5).

There are no aging effects re uirin q g mana ement for the metallic com onents of the uninsulated "'round cond"c+o g p .... rs a nd t""'nnectj ns. .0 Aging Management Review Results Page 3.6-29 January 2010 Columbia Generating Station License Renewal Application Technical Information [This page intentionally blank]Aging Management Review Results Page 3.6-30 January 2010 0[This page intentionally blank] Aging Management Review Results Page 3.6-30

• Columbia Generating Station License Renewal Application Technical Information January 2010
• Columbia Generating Station License Renewal Application Technical Information 4.0 TIME-LIMITED AGING ANALYSES 10 CFR 54 governs the issuance of renewed operating licenses for nuclear powerplants and includes requirements for the performance of an integrated plant assessment (IPA) and the review of time-limited aging analyses.

The results of the IPA and time-limited aging analysis (TLAA) evaluations form the technical bases upon which the Columbia Generating Station (Columbia) license renewal application is built.This section provides the results of reviews of potential TLAAsand exemptions specific to Columbia for license renewal and documents evaluations of each identified item for the period of extended operation. This section dispositions each identified TLAA in accordance with 10 CFR 54.21 (c).Time-Limited Aging Analyses Page 4.0-1 January 2010 Time-Limited Aging Analyses Page 4.0-1 January 2010* * -* 4.0 TIME-LIMITED AGING ANALYSES Columbia Generating Station License Renewal Application Technical Information 10 CFR 54 governs issuance of renewed operating licenses for nuclear power plants and includes requirements for the performance of an integrated plant assessment (IPA) and the review of time-limited aging analyses. The results of the IPA and limited aging analysis (TLAA) evaluations form the technical bases upon which the Columbia Generating Station (Columbia) license renewal application is built. , This section provides the results of reviews of potential TLAAs _and exemptions specific to Columbia for license renewal and documents evaluations of each identified item for the period of extended operation. This section dispositions each identified TLAA in accordance with 10 CFR 54.21(c) . / Aging Analyses Page 4.0-1 January 2010 Columbia Generating Station License Renewal Application Technical Information [This page intentionally blank]Time-Limited Aging Analyses Page 4.0-2 January 2010 Time-Limited Aging Analyses Page 4.0-2 January 2010 Columbia Generating Station License Renewal Application

• Technical Information

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• Time-Limited Aging Analyses Page 4.0-2 January 2010 Columbia Generating Station License Renewal Application Technical Information

4.1 IDENTIFICATION

OF TIME-LIMITED AGING ANALYSES Time-limited aging analyses are defined in 10 CFR 54.3 as those licensee calculations and analyses that:.(1) Involve systems, structures, and components within the scope of license renewal, as delineated in 10 CFR 54.4(a);(2) Consider the effects of aging;(3) Involve time-limited assumptions defined by the current operating term, for example, 40 years;(4) Were determined to be relevant by the licensee in making a safety determination; (5) Involve conclusions or provide the basis for conclusions related to the capability of the system, structure, and component to perform its intended functions, as delineated in 10 CFR 54.4(b); and (6) Are contained or incorporated by reference in the CLB.4.1.1 Time-Limited Aging Analyses Identification ProcessThe major emphasis in the License Renewal Rule (10 CFR 54) is that the CLB must be maintained during the period of extended operation. Time-limited aging analyses that are contained or incorporated by reference in the CLB at Columbia are identified, as, required by 10 CFR 54. The CLB documentation that was searched to identify potential TLAAs includes the following:

• Final Safety Analysis Report (FSAR)* Fire Protection Evaluation
• Assurance Program* In-Service Inspection Program* Docketed Licensing Correspondence
• Operating License (including Technical Specifications)
• Code Exemptions and Relief Requests* Design Calculations and Design Reports Industry documents that list generic time-limited aging analyses were reviewed toprovide additional assurance

'of the completeness of the plant-specific list. These documents include NUREG-1800, "Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants," Revision 1, NEI 95-10, "Industry Guideline for Implementing the Requirements of 10 CFR Part 54- The License Renewal Rule," Revision 6, Boiling Water Reactor Vessel and Internals Project Time-Limited Aging Analyses.Page 4. 1-1 January 2010* ** ,

• 4.1 Columbia Generating Station License Renewal Application Technical Information IDENTIFICATION OF TIME-LIMITED AGING ANALYSES " Time-limited aging analyses are defined in 10 CFR 54.3 as those licensee calculations and analyses that . (1) Involve systems, structures, and components within the scope of license renewal, as delineated in 10 CFR 54.4(a); (2) Consider the effects of aging; (3) Involve time-limited assumptions defined by the current operating term, for example, 40 years; (4) Were determined to be relevant by the licensee in making a safety determination; (5) Involve conclusions or provide the basis for conclusions related to the capability of the system, structure, and component to perform its intended functions, as delineated in 10 CFR 54.4(b); and (6) Are contained or incorporated by reference in the CLB. 4.1.1 Time-Limited Analyses Identification Process The major emphasis in the License Renewal Rule (10 CFR 54) is that the CLB must be maintained during the period of extended operation.

Time-limited aging analyses that are contained or incorporated by reference in the CLB at Columbia are identified, as, required by 10 CFR 54. The CLB documentation that was searched to identify potential TLAAs includes the following:

• Final Safety Analysis Report (FSAR)
• Fire Protection Evaluation
• Quality Assurance Program .
• In-Service Inspection Program
• Docketed Licensing Correspondence
• Operating License (including Technical Specifications)
• Code Exemptions and Relief Requests
• Design Calculations and Design Reports Industry documents that list generic time-limited aging analyses were reviewed to provide additional assurance:of the completeness of th'e plant-specific list. These documents include NUREG-1800, "Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants," Revision 1, NEI 95-10, "Industry Guideline for Implementing the Requirements of 10 CFR Part 54 .-The License Renewal Rule," Revision 6, Boiling Water Reactor Vessel and Internals Project Time-Limited Aging Analyses . Page 4.1-1 January 2010 Columbia Generating StationLicense Renewal Application Technical Information (BWRVIP) reports and recent license renewal applications for boiling water reactor designs.Each potential TLAA identified is reviewed to determine if it meets the definition of a TLAA in accordance with 10 CFR 54.3. Columbia analyses and calculations that meet the TLAA definition are evaluated in accordance with the options provided in 10 CFR 54.21 (c)(1).4.1.2 Evaluation of Time-Limited Aging Analyses As required by 10 CFR 54.21 (c)(1), an evaluation of Columbia-specific TLAAs must be performed to demonstrate that: (i) The analyses remain valid for the period of extended operation;(ii) The analyseshave been projected to the end of the period of extended operation; or (iii) The effects of aging on the intended function(s) will be adequately managed for the period of extended operation.

The results of these evaluations are summarized in Table 4.1-1 and Table 4.1-2 and discussed in Sections 4.2 through 4.7.4.1.3 Identification of Exemptions Pursuant to 10 CFR 54.21(c)(2), an applicant for license renewal must provide: (1) a listing of plant-specific exemptions granted pursuant to 10 CFR 50.12 that are in effect and based on a TLAA, and (2) an evaluation of these exemptions to justify their continuation for the period of extended operation. Columbia current licensing basis documentation, identified in Section 4.1.1, was reviewed for exemptions. As a result of the review, there were no exemptions identified that are based on a TLAA.Time-Limited Aging Analyses Page.4.1-2 January 2010 Columbia Generating Station License Renewal Application Technical Information (BWRVIP) reports and recent license renewal applications for boiling water reactor designs. Each potential TLAA identified is reviewed to determine if it meets the definition of a TLAA in accordance with 10 CFR 54.3. Columbia analyses and calculations that meet the TLAA definition are evaluated in accordance with the options provided in 10 CFR 54.21 (c)(1). 4.1.2 Evaluation of Time-Lim ited Aging Analyses As required by 10 CFR 54.21 (c)(1), an evaluation of Columbia-specific TLAAs must be performed to demonstrate that: (i) The analyses remain valid for the period of extended operation; (ii) The analyses have been projected to the end of the period of extended operation; or (iii) The effects of aging on the intended function(s) will be adequately managed for the period of extended operation. The results of these evaluations are summarized in Table 4.1-1 and Table 4.1-2 and discussed in Sections 4.2 through 4.7. 4.1.3 Identification of Exemptions Pursuant to 10 CFR 54.21 (c)(2), an applicant for license renewal must provide: (1) a listing of plant-specific exemptions granted pursuant to 10 CFR 50.12 that are in effect and based on a, TLAA, and (2) an evaluation of these exemptions to justify their continuation for the period of extended operation. Columbia current licensing basis documentation, identified in Section 4.1.1, was reviewed for exemptions. As a result of the review, there were no exemptions identified that are based on a TLAA. Time-Limited Aging Analyses Page4.1-2 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table 4.1-1 Time-Limited Aging Analyses Results of TLAA Evaluation by Category 10 CFR 54.21(c)(1)

LRA Paragraph Section R~eactr Vessel Neuron Embrittlernent 4.Neutron Fluence Not a TLAA 4.2.1 Upper Shelf Energy (USE) (ii) 4.2.2 Adjusted Reference Temperature (ART) (ii) 4.2.3 Pressure-Temperature (P-T) Limits (iii) 4.2.4 Reactor Vessel Circumferential Weld Examination (ii) 4.2.5 Relief Reactor Vessel Axial Weld Failure Probability (ii) 4.2.6 Metal, Fatigue 4.Reactor Pressure Vessel Fatigue Analyses (iii) 4 3.1 Reactor Vessel Internals Fatigue Analyses (iii) 4.3.2 Reactor Coolant Pressure Boundary Piping and (iii) 4.3.3 Component Fatigue Analyses Non-Class 1 Component Fatigue Analyses (i) 4.3.4 Effects of Reactor Coolant Environment on Fatigue (iii) 4.3.5 Life of Components and Piping SEnvironmental Qualification of El~ectrica[ Equipmenet .~ (iii)~ , J4.4 CocrteCotanmntTe-o Prestres~s NtaTA Cotimn ~e lte ea otimns and Penetrations Fatigue 4.ASME Class MC Components (i) 4.6.1 Downcomers (i) 4.6.2 Safety Relief Valve Discharge Piping (i) 4.6.3 Diaphragm Floor Seal (i) 4.6.4ECCS Suction Strainers (i) 4.6.5 Other Plnt-Specific Time-Limiited Aging Analyses4. Reactor Vessel Shell Indications (iii)Sacrificial Shield Wall (ii)_4_7.2 Main Steam Line Flow Restrictor Erosion Analysis (ii)_4_7_3 Time-Limited Aging Analyses Page 4.1-3 January 2010 Time-Limited Aging Analyses Page 4.1-3 January 2010* *

• Table 4.1-1 Time-Limited Aging Analyses Results of TLAA Evaluation by Category NeutronFluence Upper Shelf Ene Effects of Reactor Coolant Environment on Fatigue Life of Com nents and Pipin Downcomers S Relief Valve D'C""I',,,,,rn m Floor Seal ECCS Suction Strainers Reactor Vessel Shell Indications Sacrificial Shield Wall Main Steam Line Flow Restrictor Erosion is Time-Limited Aging Analyses Page 4.1-3 Columbia Generating Station License Renewal Application Technical Information 10 CFR 54.21(c)(1)

LRA Paragraph Section Not a TLAA 4.2.1 4.2.2 4.2.3 4.2.4 4.2.5 ii) (iii) 4.3.3 (i) 4.3.4 (iii) 4.3.5 4.6.2 4.6.3 4.6.4 (i) 4.6.5 (ii) 4.7.3 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 4.1-2 Review of Generic TLAAs Listed in Tables 4.1-2 and 4.1-3 of NUREG-1800 LRA NUREG-1800 Generic TLAAs Example Applicability to Columbia Sci Section Reactor Vessel Neutron Embrittlement Yes 4.2 Concrete Containment Tendon Prestress No -Columbia does not have 4.5containment tendons Metal Fatigue Yes 4.3 Environmental Qualification of Electrical Yes 4.4 Equipment Metal Corrosion Allowance No -!No explicit 40-year basis applies.Inservice Flaw Growth Analyses that Yes 4.7.1 Demonstrate Structure Stability for 40 Years Inservice Local Metal Containment Corrosion No -No explicit 40-year basis Analyses applies. ,High-Energy Line-Break Postulation Based on Yes 4.3.3 Fatigue Cumulative Usage Factor Intergranular Separation in the Heat-Affected No -No HAZ analysis was -Zone (HAZ) of Reactor Vessel Low-Alloy Steel identified within the CLB.Under Austenitic Stainless Steel Cladding Low-Temperature Overpressure Protection No -No LTOP analysis was (LTOP) Analyses identified within the CLB.Fatigue Analysis for the Main Steam Supply No -Columbia is a BWR andLines to the Turbine-Driven Auxiliary does not have an AuxiliaryFeedwater Pumps Feedwater System.Fatigue Analysis of the Reactor Coolant Pump No -Recirculation System Flywheel pumps do not have flywheels. Fatigue Analysis of Polar Crane No -No explicit 40-year basis applies.Time-Limited Aging Analyses Page 4.1-4 January 2010 Time-Limited Aging Analyses Page 4.1-4 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 4.1-2 Review of Generic TLAAs Listed in Tables 4.1-2 and 4.1-3 of NUREG-1800 NUREG-1800 Generic TLAAs Example Reactor Vessel Neutron Embrittlement -Concrete Containment Tendon Prestress Metal Fatigue Environmental Qualification of Electrical Equipment Metal Corrosion Allowance Inservice Flaw Growth Analyses that Demonstrate Structure Stability for 40 Years Inservice Local Metal Containment Corrosion Analyses High-Energy Line-Break Postulation Based on Fatigue Cumulative Usage Factor Intergranular Separation in the Heat-Affected Zone (HAZ) of Reactor Vessel Low-Alloy Steel Under Austenitic Stainless Steel Cladding Low-Temperature Overpressure Protection (L TOP) Analyses . Fatigue Analysis for the Main Steam Supply Lines to the Turbine-Driven Auxiliary Feedwater Pumps Fatigue Analysis of the Reactor Coolant Pump Flywheel Fatigue Analysis of Polar Crane Applicability to Columbia Yes No -Columbia does not have containment tendons Yes Yes No -'No explicit 40-year basis applies. Yes No -No explicit 40-year basis applies. Yes No -No HAZ analysis was identified within the CLB. No -No L TOP analysis was identified within the CLB. No -Columbia is a BWR and does not have an Auxiliary Feedwater System. No -Recirculation System pumps do not have flywheels. No -No explicit 40-year basis applies. Time-Limited Aging Analyses Page 4.1-4 LRA 4.2 4.5 4.3 4.4 4.7.1 4.3.3 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 4.1-2 (continued)

Review of Generic TLAAs Listed in Tables 4.1-2 and 4.1-3 of NUREG-1800 LRA NUREG-1800 Generic TLAAs Example Applicability to Columbia Sci Section NUREG-1 800, Table 4.1-3 (cont..)Flow-Induced Vibration Endurance Limit forthe No -No analyses were Reactor Vessel Internals identified within the CLB forthe reactor vessel internals related to this topic.Transient Cycle Count Assumptions for the Yes 4.312 Reactor Vessel Internals Ductility Reduction of Fracture Toughness for No -No analyses were --the Reactor Vessel Internals identified within the CLB forthe reactor vessel internals related to this topic.Leak Before Break No -Columbia does not credit Leak Before Break. Fatigue Analysis for the Containment Liner Plate No -Columbia does not have 4.6.1 a liner plate, but the metal shell is analyzed for fatigue.Containment Penetration Pressurization Cycles Yes 4.6.1 Reactor Vessel Circumferential Weld Inspection Yes 4.2.5 Relief (BWR)Time-Limited Aging Analyses Page 4.1-5 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information . Table 4.1-2 (continued)

Review of Generic: TLAAs Listed in Tables 4.1-2 and 4.1-3 of NUREG-1800 NUREG-1800 Generic TLAAs Example Applicability to Columbia Flow-Induced Vibration Endurance Limit forthe No -No analyses were Reactor Vessel Internals identified within the CLB for the reactor vessel internals related to this topic. Transient Cycle Count Assumptions for the Yes Reactor Vessel Internals Ductility Reduction of Fracture Toughness for No -No analyses were the Reactor Vessel Internals identified within the CLB for the reactor vessel internals related to this topic. Leak Before Break No -Columbia does not credit Leak Before Break . I Fatigue Analysis for the Containment Liner Plate No -Columbia does not have a liner plate, but the metal shell is analyzed for fatigue. Containment Penetration Pressurization Cycles Yes Reactor Vessel CircumfElrential Weld Inspection Yes Relief (BWR) Time-Limited Aging AnalysEls Page 4.1-5 LRA Section 4.3.2 4.6.1 4.6.1 4.2.5 January 2010 Columbia Generating Station License Renewal Application Technical Information [This page intentionally blank]Time-Limited Aging Analyses Page 4.1-6 January 2010[This page intentionally blank] Time-Limited Aging Analyses Page 4.1-6 , .' Columbia Generating Station License Renewal Application Technical Information January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information

4.2 REACTOR

VESSEL NEUTRON EMBRITTLEMENT Neutron embrittlement is the term used to describe changes-in mechanical properties of reactor vessel materials that result from exposure to fast neutron flux (E>1.0 MeV)within the beltline region. The most pronounced material change is a reduction in fracture toughness. As fracture toughness decreases, with cumulative fast neutron exposure, the material's resistance to crack propagation decreases. Fracture toughness is also dependent on temperature. The reference temperature for nil-ductility transition (RTNDT) is the temperature above which the material behaves in a ductile manner and below which the material behaves in a brittle manner. As fluence increases, RTNDT increases. This means higher temperatures are required for the material to continue to act in a ductile manner.The regulations governing reactor vessel integrity are in 10 CFR Part 50. Section 50.60 requires that all light-water reactors meet the fracture toughness, pressure-temperature limits, and material surveillance program requirements for the reactor coolant pressure boundary as set forth in Appendices G and H of 10 CFR 50.The analyses associated with evaluation of the effect of neutron embrittlement on the Columbia reactor pressure vessel for 40 years are TLAAs. Neutron fluence, Upper shelf energy (USE), adjusted reference temperature (ART), and vessel pressure-temperature (P-T) limits are time dependent parameters that must be investigated with respect to fracture toughness (embrittlement) of reactor vessel materials. The following sections address fluence, USE, ART, P-T limits, circumferential welds, and axial welds for the reactor pressure vessel (RPV) beltline materials for the period of extended operation. This discussion uses the latest data, as submitted to the NRC on June 9, 2004 (Reference 4.8-1) and approved by the NRC in license amendment'number 193 on May 12, 2005 (Reference 4.8-2). The latest data supersedes the information currently in the NRC's Reactor Vessel Integrity Database (RVID2).4.2.1 Neutron Fluence EFPY Projection To evaluate the effects of radiation on RPV material embrittlement, the results of analyses were projected to determine neutron fluence out to 54 effective full power years (EFPY). Using actual reactor core power histories to-date and conservative estimates of future core designs, extended operation to 60 years will be bounded by 54 EFPY. (Reaching 54 EFPY would require a plant capacity factor in excess of 95 percent from now until the end of the period of extended operation.) Time-Limited Aging Analyses Page 4.2-1 January 2010* * *** 4.2 REACTOR VESSEL NEUTRON EMBRITTLEMENT Columbia Generating Station License Renewal Application Technical Information Neutron embrittlement is the used to describe changes in mechanical properties of reactor vessel materials that result from exposure to fast neutron flux (E>1.0 MeV) within the beltline region. The most pronounced material change is a reduction in fracture toughness. As fracture toughness decreases with cumulative' fast neutron exposure, the matericll's resistance to crack propagation decreases. Fracture toughness is also dependent on temperature. The reference temperature for nil-ductility transition (RT NOT) is the temperature above which the material behaves in a ductile manner and below which the material behaves in a brittle manner. As fluence increases, RT NOT increases. This means higher temperatures are required for the material to continue to clct in a ductile manner. . The regulations governing reactor vessel integrity are in 10 CFR Part 50. Section 50.60 requires that all light-water reactors meet the fracture toughness, pressure-temperature limits, and material surveillance program requirements for the reactor coolant pressure boundary as set forth in Appendices G and H of 10 CFR 50. The analyses with evaluation of the effect of neutron embrittlement on the Columbia reactor pressure vessel for 40 years are TLAAs. Neutron fluence, upper shelf energy (USE), adjusted reference temperature (ART), and vessel pressure-temperature (P-T) limits are time dependent parameters that must be investigated with respect to fracture toughness (embrittlement) o.f reactor vessel materials. The following sections address fluence, USE, ART, P-T limits, circumferential welds, and axial welds for the reactor pressure vessel (RPV) beltline materials for the period of extended operation. This discussion uses the latest data, as submitted to the NRC on June 9, 2004 (Reference 4.8-1) and approved by the NRC in license amendment Inumber 193 on May 12, 2005 (Reference 4.8-2). The latest data supersedes the information currently in the NRC's Reactor Vessel Integrity Database (RVID2). 4.2.1 Neutron Fluence EFPY Projection To evaluate the effects of radiation on RPV material embrittlement, the results of analyses were projech3d to determine neutron fluence out to 54 effective full power years (EFPY). Using actual reactor core power histories to-date and conservative estimates of future con3 designs, extended operation to 60 years will be bounded by 54 EFPY. (Reaching 54 EFPY would require a plant capacity factor in excess of 95 percent from now until the end of the period of extended operation.) Time-Limited Aging Page 4.2-1 January 2010 Columbia Generating Station License Renewal Application Technical Information Fluence Projection Fluence values at 51.6 EFPY of reactor operation (analyzed by General Electric (GE) in Reference 4.8-3) are addressed in FSAR Section 4.3.2.8 and FSAR Table 4.3-1. These fluence analyses are based on the original licensed thermal power of 3323 megawatt-thermal (MWt) through fuel cycle 10, and the currently licensed thermal power uprated to 3486 MWt from cycle 11 through the end of operation. These fluence analyses are based on the methodology -of NEDC-32983P, "General Electric Methodology for Reactor Pressure Vessel Fast Neutron Flux Evaluation." NEDC-32983P was approved by NRC letter (Reference 4.8-4) with acceptability based :on the fact that the methodology followed the guidance in Regulatory Guide (RG) 1.190, "Calculational and Dosimetry Methods for Determining Pressure Vessel Neutron Fluence." Subsequently, GE incorporated the fluence analyses into a personal computer worksheet to allow production of fluence estimates at other EFPY. For purposes of license renewal, the reported fluence was linearly extrapolated from 33.1 EFPY (the original 40-year end of life estimate) through 51.6 EFPY to 54 EFPY. Those projections match the fluence values obtained from the automated worksheet for 54 EFPY.A summary of the highest estimated values offluence for the RPV beltline shells and welds is shown in Table 4.2-1. Fluence is calculated at the inner surface (OT) of the vessel and at Y4 thickness (1/4T) depth into the vessel.Beitline Evaluation NUREG-1801 indicates that ferritic materials for RPV beltline shells, welds, and assembly components are to be evaluated for neutron irradiation embrittlement if high energy neutron fluence is greater than a threshold value of 1E+17 n/cm 2 (E >1 MeV) at the end of the license renewal term. The only RPV assembly items, other than the shells and welds in Table 4.2-1, that would experience neutron fluence greater than 1E+17 n/cm 2 during the period of extended operation are instrumentation nozzle N12 and residual heat removal/low-pressure coolant injection (RHR/LPCI) nozzle N6.Instrumentation nozzle N12 has a thickness less than 2.5 inches and therefore requires no fracture toughness evaluation per ASME Code Appendix G, Section G2223, and thus is not evaluated. Nozzle N6 is evaluated for ART in Section 4.2.3 and Table 4.2-5 below. As shown in Table 4.2-5, the ART for these nozzles is only 22.2 OF, versus 53.8 OF for the highest weld and 73.6 OF for the highest plate. Consequently, nozzle N6 is not the limiting material for the vessel. However, as nozzle N6 was evaluated for ART it meets thedefinition of a beltline component per 10 CFR 50, Appendix G.Time-Limited Aging Analyses Time-Limited Aging Analyses Page 4.2-2 January 2010 Page 4.2-2.January 2010 Columbia Generating Station License Renewal Application

• Technical Information Fluence Projection Fluence values at 51.6 EFPY of reactor operation (analyzed by General Electric (GE) in Reference 4.8-3) are addressed in FSAR Section 4.3.2.8 and FSAR Table 4.3-1. These fluence analyses are based on the original licensed thermal power of 3323 thermal (MWt) through fuel cycle 10, and the currently licensed -thermal power uprated to 3486 MWt from cycle 11 through the end of operation.

These fluence analyses are based on the methodology

• of NEDC-32983P, "General Electric Methodology for Reactor Pressure Vessel Fast Neutron Flux Evaluation." NEDC-32983P was approved by NRC letter (Reference 4.8-4) with acceptability based* on the fact that the methodology followed the guidance in Regulatory Guide (RG) 1.190, "Calculational and Dosimetry Methods for Determining Pressure Vessel Neutron Fluence." Subsequently, GE incorporated the fluence analyses into a personal computer worksheet to allow production of fluence estimates at other EFPY. For purposes of license renewal, the reported fluence was linearly extrapolated from 33.1 EFPY (the original 40-year end of life estimate) through 51.6 EFPY to 54 EFPY. Those projections match the fluence values obtained from the* automated worksheet for 54 EFPY. A summary of the highest estimated values of f1uence for the RPV beltline shells and welds is shown in Table 4.2-1. Fluence is calculated at the inner surface (OT) of the
• vessel and at % thickness (1/4T) depth into the vessel. Beltline Evaluation NUREG-1801 indicates that ferritic materials for RPY beltline shells, welds, and assembly components are to be evaluated for neutron irradiation embrittlementif high energy neutron fluence is greater than a threshold value of 1 E+17 n/cm 2 (E >1 MeV) at the end of the license renewal term. The only RPV assembly items, other than the shells, and welds in Table 4.2-1, that would experience neutron fluence greater than 1 E+17 n/cm 2 during the perjod of extended operation are instrumentation nozzle N12 and residual heat removal/low-pressure coolant injection (RHR/LPCI) nozzle N6. Instrumentation nozzle N12 has a thickness less than 2.5 inches and therefore requires no fracture toughness evaluation per ASME Code Appendix G, Section G2223, and thus is not evaluated.

Nozzle N6 is evaluated for ART in Section 4.2.3 and Table 4.2-5 below. As shown in Table 4.2-5, the ART for these nozzles is only 22.2 of, versus 53.8 of for the highest weld and 73.6 of for the highest plate. Consequently, nozzle N6 is not the limiting material for the vessel. However, as nozzle N6 was evaluated for ART it meets the* definition of a beltline component per 10 CFR 50, Appendix G. Time-Limited Aging Analyses Page 4.2-2 'January 2010 .' Columbia Generating StationLicense Renewal Application Technical Information As such, the beltline definition for the period of extended operation includes the lower shell, lower-intermediate shell, associated vertical (longitudinal) welds, the girth (circumferential) weld that connects the lower and lower-intermediate shells, and nozzle N6.Disposition: Neutron fluence is not a TLAA. It is a time-limited assumption used in various neutron embrittlement TLAAs.Table 4.2-1 RPV Beltline Fluence Values at 54 EFPY Lower bnlell Mk 21-1-1, Mk 21-1-2, Mk 21-1-3, Mk 21-1-4 4.78E+17 Lower-I ntermediate Shell Mk 22-1-1, 1.17E+18 8.10E+17 Mk 22-1-2, Mk 22-1-3, Mk 22-1-4 NOZZLES N6 (RHR / LPCI) Mk 64-1 6.49E+17 4.48E+17 (3 nozzles)Lower Vertical BA, BB, 4.78E+17 2.71 E+17 (Axial / Longitudinal) BC, BD Lower-Intermediate Vertical BE, BF, 1.17E+18 8.10E+17 (Axial / Longitudinal) BG, BH Lower to Lower-Intermediate Girth AB 4.78E+17 3.3E+17 (Circumferential) Time-Limited Aging Analyses Page 4.2-3 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information . As such, the beltline definition for the period of extended operation inCludes the lower shell, lower-intermediate shell, associated vertical (longitudinal) welds, the girth (circumferential) weld that connects the lower 'and'iower-intermediate shells, and nozzle N6. Disposition:

Neutron fluence is not a TLAA. It is a time-limited assumption used in variolJs neutron embrittlement TLAAs. ' Table 4.2-1 RPV 8eltline Fluence Values at 54 EFPY Lower Shell Mk 21-1-1, 4.78E+17 2.71E+17 Mk 21-1-2, Mk 21-1-3, Mk 21-1-4 Lower-Intermediate Shell Mk 22-1-1, 1.17E+18 8.10E+17 Mk 22-1-2, Mk 22-1-3, Mk 22-1-4 Lower Vertical BA, BB, 4.78E+17 2.71E+17 (Axial! Longitudinal) BC, BO Lower-Intermediate Vertical BE, BF, 1.17E+18 8.10E+17 (Axial! Longitudinal) BG, BH Lower to Lower-Intermediate Girth AB 4.78E+17 3.3E+17 (Circumferential) Time-Limited Aging Analyses Page 4.2-3 January 2010 Columbia Generating StationLicense Renewal Application Technical Information

4.2.2 Upper

Shelf Energy Evaluation 10 CFR .50 Appendix G requires the USE of the RPV beltline materials to remain above 50 ft-lb at all times during plant operation, including the effects of neutron radiation. If USE cannot be shown to remain above this limit, then an equivalent margin, analysis (EMA) must be performed to show that the margins of safety against fracture are equivalent to those required by Appendix G of Section Xl of the ASME Code.The USE calculation of record for the existing licensed period (33.1 EFPY) is Appendix F of GE NEDO-33144 (Reference 4.8-5). The initial (unirraditated) USE is not known for all the Columbia vessel plates and welds. For those plates and welds for which the initial USE is known, USE was projected using Regulatory Guide 1.99, Revision 2 methods. For the vessel plates and welds for which the initial USE is not known, USE EMAs were performed using the Boiling Water Reactor Owners Group EMA methodology. Results from the testing and analysis of surveillance materials were used in the EMA analyses.The values of USE projected to 54 EFPY are listed in Table 4.2-2. All of the projected USE values from Table 4.2-2 remain above 50 ft-lbs through the end of the period of extended operation (54 EFPY).The projected EMAs are listed in Table 4.2-3 and Table 4.2-4. The projected EMAs in Table 4.2-3, and Table 4.2-4 used the projected 54 EFPY fluence listed in Table 4.2-1, and the curves provided in RG 1.99 Figure 2. The predicted values were compared to the minimum 54 EFPY USE limits in BWRVIP-74-A. For the vessel beltline plates, the maximum decrease in USE was found to be 13.2 percent (see Table 4.2-3). This is less than the assumed decrease of 23.5 percent in the beltline plate equivalent margin analysis. Therefore, the maximum predicted decreases in USE for 54 EFPY for the beltline plates are bounded by the generic 54 EFPY equivalent margin analysis documented in BWRVIP-74-A. The projected USE for the vessel beltline plates is acceptable for the period of extended operation. For the welds associated with the vessel beltline plates, the maximum decrease in USE was found to be 21.6 percent (see Table 4.2-4). This is less than the assumed decrease of 39 percent in the equivalent margin analysis. Therefore, the maximum predicted decreases in USE for the welds in the vessel beltline region are bounded by the generic 54 EFPY equivalent margin analysis documented in BWRVIP-74-A. The projected USE for the beltline welds is acceptable for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(ii) -Reactor vessel upper shelf energy TLAAs have been projected to the endiof the period of extended operation. Time-Limited Aging Analyses Time-Limited Aging Analyses Page 4.2-4 January 2010 Page 4.2-4, January 2010 Columbia Generating Station License Renewal Application

• Technical Information

4.2.2 Upper

Shelf Energy Evaluation 10 CFR ,50 Appendix G requires the USE of the RPV beltline materials to remain above 50 ft-Ib at all times during plant operation, including the effects of neutron radiation. If USE; cannot be shown to remain above this limit, then' an equivalent margin, analysis (EMA) must be performed to show that the margins of safety against fracture are equivalent to those required by G of Section XI of the ASME Code. ' The USE calculation of record for the existing licensed period (33.1 EFPY) is Appendix F of GE NEDO-33144 (Reference 4.8-5). The initial (unirraditated) USE is not known for all the Columbia vessel plates and welds. For those plates and welds for which the initia'i USE is known, USE was projected using Regulatory Guide 1.99, Revision 2 methods. For the vessel plates and welds for which the initial USE is not known, USE EMAs were performed using the Boiling Water Reactor Owners Group EMA methodology. Results from the testing and analysis of surveillance materials were used in the EMA analyses. The values of USE projected to 54 EFPY are listed in Table 4,2-2. All of the projected USE values from Table 4.2'-2 remain above 50 ft-Ibs through the end of the period of extended operation (54 EFPY). The projected EMAs, are listed in Table 4.2-3 and Table 4.2-4. The projected EMAs in

• Table 4.2-3, and Table 4.2-4 used the projected 54 EFPY fluence listed in Table 4.2-1, and the curves provided in RG 1.99 Figure 2. The predicted values were compared to the minimum 54 EFPY USE limits in BWRVIP-74-A. . For the vessel beltline plates, the maximum decrease in USE was found to be 13.2 percent (see Table 4.2-3). This is less than the assumed decrease of 23.5 percent in the beltline plate equivalent margin' analysis.

Therefore, the maximum predicted decreases in USE for 54 EFPY for the beltline plates are bounded by the generic 54 EFPY equivalent margin analysis documented in BWRVIP-74-A. The projected USE for the vessel beltline plates is acceptable for the period of extended operation. For the welds associated with the vessel beltline plates, the maximum decrease in USE was found to be 21.6 percent (see Table 4.2-4). This is less 'than the assumed decrease of 39 percent in the equivalent margil") analysis. Therefore, the maximum predicted decreases in USE for the welds in the vessel beltline region are bounded by the generic 54 EFPY equivalent margin analysis docume'nted in BWRVIP-74-A. The projected USE for the beltline welds is acceptable for the period of extended operation. Disposition: 10 CFR 54.21 (c)(1)(ii) -Reactor vessel upper shelf energy TLAAs have been projected to the endiof the period of extended operation . Time-Limited Aging Analyses Page 4,2-4, January 2010

• Columbia Generating Station License Renewal Application Technical Information Table 4.2-2 USE Projections for 54 EFPY 1/4 T' Drop 1.T I.D. Heat Initial Fluence in USE Sub-Componentd')

No. (Single/Tandem wire) % Cu USE n/cm 2 USE (ft-lb)P)LATES-:___- Lower-Intermediate Mk 22- B5301-1 0.13 98 8.10E+17 12.1% 86.1 Shell (Course #2) 1-1 Lower Vertical Longitical BA- 3P4966 (S) 0.025 98 2.71E+17 7.0% 91.1 (Axial/Longitudinal) 3P4966 (T) 0.025 98 2.71E+/-17 7.0% 91.1 Lower-Intermediate Vertical BE- 3P4966 (S) 0.025 98 8.10E+17 9.1% 89.1 (Axial/Longitudinal) BH 3P4966(T) 0.025 98 8.10E+17 9.1% 89.1 Lower to Lower-Intermediate Girth 5P6756(S) 0.080 91 3.30E+17 9.8% 82.1 (Circumferential) AB 5P6756 (T) 0.080 97 3.30E+17 9.8% 87.5 AB 3P4955 (S) 0.027 90 3.30E+17 7.4% 83.3 3P4955 (T) 0.027 95 3.30E+17 7.4% 87.9" The sub-components not on this table have no projection due to the initial USEbeing unknown. See TableA4.2-3 and Table 4.2-4 for the equivalent margin analyses for the limiting plate and weld.Time-Limited Aging Analyses.Page 4.2-5 January 2010* *

• Lower-Intermediate Vertical (Axial/Longitudinal)

Lower to Intermediate Girth (Circumferential) BO BH AS AS Table 4.2-2 USE Projections for 54 EFPY Heat Columbia Generating Station License Renewal Application Technical Information Drop %T USE (1) The sub-compone!nts not on this table have no projection due to the initial USE being unknown. See Table \4.2-3 and Table 4:2-4 for the equivalent margin analyses for the limiting plate and weld . Time-Limited Aging Analyses Page 4.2-5 . January 2010 Columbia Generating Station License Renewal Application Technical Information Table 4.2-3 RPV Beltline Plate USE Equivalent Margin Analysis for 54 EFPY Surveillance Plate USE (Heat: B5301-1)%Cu = 0.13 Unirradiated USE = 98.0 ft-lb 1 st Capsule Measured USE = 99.6 ft-lb 1st Capsule Fluence = 1.55E+17 n/cm 2 1 st Capsule Measured Decrease = -1.6 %1 st Capsule RG 1.99 Predicted Decrease = 8.0%Limiting Beltline Plate USE (Heat: C1337-1 and C1337-2)%Cu = 0.15 54 EFPY %1/4T Fluence = 8.10E+17 n/cm 2 RG 1.99 Predicted Decrease = 13.2 %Adjusted Decrease = N/A 13.2 % 5 23.5 % (bounding value from SER for BWRVIP-74-A) Therefore, the vessel plates are bounded by Equivalent Margin Analysis in BWRVIP-74-A. Time-Limited Aging Analyses Page 4.2-6 January 2010 Time-Limited Aging Analyses Page 4.2-6 January 20.10 Columbia Generating Station License Renewal Application Technical Information Table 4.2-3 RPV 8eltline Plate USE Equivalent Margin Analysis for 54 EFPY Surveillance Plate USE (Heat: B5301-1) %Cu = 0.13 Unirradiated USE = 98.0 ft-Ib 1 sl Capsule Measured USE = 99.6 ft-Ib 1 sl Capsule Fluence = 1.55E+17 n/cm 2 1 sl Capsule Measured Decrease = -1.6 % 1 sl Capsule RG 1.99 Predicted Decrease = 8.0 % Limiting Beltline Plate USE (Heat: C1337-1 and C1337-2) % Cu = 0.15 54 EFPY %T Fluence = 8.1 OE+17 n/cm 2 RG 1.99 Predicted Decrease = 13.2 % Adjusted Decrease = N/A , 13.2 % s 23.5 % (bounding value from SER for BWRVIP-74-A) Therefore, the vessel plates are bounded by Equivalent Margin Analysis in BWRVIP-74-A. Time-Limited Aging Analyses Page 4.2-6 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table 4.2-4 RPV Beltline Weld USE Equivalent Margin Analysis for 54 EFPY Surveillance Weld USE (Heat 3P4966):% Cu.= 0.03 Unirradiated USE = 98.0 ft-lb 1 st Capsule Measured USE = 108.0 ft-lb 1 st Capsule Fluence = 1.55E+17 n/cm 2 1 st Capsule Measured Decrease = -10.2 %1 t Capsule RG 1.99 Predicted Decrease = 6.0 %ISP Surveillance Weld USE (Heat 5P6756):%Cu = 0.06 Unirradiated USE = 104.4 ft-lb River Bend 1830 Capsule Measured USE = 84.4 ft-lb River Bend 1830 Capsule Fluence = 1.16E+18 n/cm 2 SSP Capsule F Measured USE = 79.3 ft-lb SSP Capsule F Fluence = 1.94E+18 n/cm 2 SSP Capsule H Measured USE = 84.6 ft-lb SSP Capsule H Fluence = 1.36E+18 n/cm 2 River Bend 1830 Capsule Measured Decrease = 19.2 %River Bend 1830 Capsule RG 1.99 Predicted Decrease = 12.5 %SSP Capsule F Measured Decrease = 24.0 %SSP Capsule F RG 1.99 Predicted Decrease = 14.0 %SSP Capsule H Measured Decrease = 19.0 %SSP Capsule H RG 1.99 Predicted Decrease = 13.0 %Limiting Beltilne Weld USE (Heat 624039/D205A27A):

%Cu = 0.10 54 EFPY 1/4T Fluence = 8.10E+17 n/cm 2 RG 1.99 Predicted Decrease = 13.2 %Adjusted Decrease = 21.6 % (1)21.6 % (54 EFPY) < 39.0 % (bounding value from SER for BWRVIP-74-A) Therefore, the vessel welds are bounded by this Equivalent Margin Analysis.(1) The 54 EFPY adjusted decrease was evaluated for license renewal using the formulas for the curves in Figures 1 and 2 of RG 1.99, rather than by reading values off the curves. This resulted in a larger adjustment based on surveillance data than was used for the 33.1 EFPY projections. Time-Limited Aging Analyses Page 4.2-7 January 2010* *

• Table 4.2-4 Columbia Generating Station License Renewal Application Technical Information RPV Beltlin'e Weld USE Equivalent Margin Analysis for 54 EFPY Surveillance Weld USE (Heat 3P4966): %Cu.= 0.03 Unirradiated USE = 98.0 ft-Ib 1 sl Capsule Measured USE = 108.0ft-lb

/ 1 sl CapsuleFluence = 1.55E+17 n/cm 2 1 sl Capsule Measured Decrease = -10.2 % 1 sl Capsule HG 1.99 Predicted Decrease = 6.0 % ISP Surveillance Weld USE (Heat 5P6756): ' %Cu = 0.06 Unirradiated USE = 104.4 ft-Ib River Bend 183 0 Capsule Measured USE = 84.4 ft-Ib River Bend 183 0 Capsule Fluence = 1.16E+18 n/cm 2 SSP Capsule F Measured USE = 79.3 ft-Ib SSP Capsule F Fluence = 1.94E+18 n/cm 2 SSP Capsule H Measured USE = 84.6 ft-Ib SSP Capsule H Fluence = 1.36E+18 n/cm 2 River.Bend 183 0 Capsule Measured Decrease = 19.2 % River Bend 183 0 Capsule HG 1.99 Predicted Decrease = 12.5 % SSP Capsule i= Measured Decrease = 24.0 % SSP Capsule F HG 1.99 Predicted Decrease = 14.0 % SSP Capsule H Measured Decrease = 19.0 % SSP Capsule H HG 1.99 Predicted Decrease = 13.0 % Limiting Beltline Weld USE (Heat 624039/D205A27A): % Cu = 0.10 54 EFPY %T Fluence = 8.1 OE+17 n/cm 2 RG 1.99 Predicted Decrease = 13.2 % 21.6 % (1) f Adjusted Decrease = 21.6 % (54 EFPY) S 39.0 % (bounding value from SER for BWRVIP-74-A) Therefore, the vessel welds are bounded by this Equivalent Margin Analysis. (1) The 54 EFPY adjusted decrease was evaluated for license renewal using the formulas for the curves in Figures 1 and 20f RG 1.99, rather than by reading values off the curves. This resulted in a larger adjustment based on surveillance data than was used for the 33.1 EFPY projections . Time-Limited Aging Analyses Page 4.2-7 January 2010 \ Columbia Generating Station License Renewal Application Technical Information

4.2.3 Adjusted

Reference Temperature Analysis In addition to USE, the other key parameter that characterizes the fracture toughness of a material is the RTNDT. This reference temperature changes as a function of exposure to neutron radiation resulting in an adjusted reference temperature, ART.The initial RTNDT is the reference temperature for the unirradiated material as defined in Paragraph NB-2331 of Section III of the ASME Boiler and Pressure Vessel Code. The change due to neutron radiation is referred to as ARTNDT.The ART is calculated by adding the initial RTNDT, the ARTNDT, and a margin to account for uncertainties as prescribed in Regulatory Guide 1.99, Revision 2.The ART evaluations of record for the vessel beltline plates and welds for the currently licensed period (33.1 EFPY), including power uprate conditions, are provided in NEDO-33144 (Reference 4.8-5). NEDO-33144 lists the initial RTNDT and chemistry values for the Columbia reactor vessel materials obtained from the Columbia vessel Certified Material Test Reports. Some chemistry factors were adjusted when Surveillance Capsule Data and Integrated Surveillance Program (ISP) best estimates were available, as described in NEDO-33144. The results and methodology in NEDO-33144, Revision 2 of Regulatory Guide 1.99 (Reference 4.8-6), and the projected fluence values listed in Table 4.2-1 were Used to project the ART for 54 EFPY. The results of this projection are summarized in Table 4.2-5 for vessel beltline plates and welds. The ART values projected to 54 EFPY are used to develop P-T limit curves, as discussed in Section 4.2.4. Projected ART values are well below the 200°F end of life ART suggested in Section 3 of Regulatory Guide 1.99 and are, thus, acceptable for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(ii) -Reactor vessel adjusted reference temperature TLAAs have been projected to the end of the period of extended operation. Time-Limited Aging Analyses Time-Limited Aging Analyses Page 4.2-8 January 2010 Page 4.2-8 January 2010 4.2.3 Adjusted Reference Temperature Analysis Columbia Generating Station License Renewal Application Technical Information In addition to USE, the other key parameter that characterizes the fracture toughness of a material is theRT NOT. This reference temperature changes as a function of exposure to neutron radiation resulting in an adjusted reference temperature, ART. The initial RT NOT is the reference' temperature for the unirradiated material as defined in Paragraph NB-2331 of Section III of the ASME Boiler and Pressure Vessel Code. The change due to neutron radiation is referred to as NOT. The ART is calculated by pdding the initial RT NOT, the NOT, and a margin to account for uncertainties as prescribed in Regulatory Guide 1.99, Revision 2. The ART evaluations of record for the vessel beltline plates and welds for the currently licensed period (33.1 EFPY), including power uprate conditions, are provided in NEDO-33144 (Reference 4.8-5). NEDO-33144 lists the initial RT NOT and chemistry values for the Columbia reactor vessel materials obtained from the Columbia vessel Certified Material Test Reports. Some chemistry factors were adjusted when Surveillance Capsule Data and Integrated Surveillance Program (ISP) best estimates were available, as described in NEDO-33144. . ,

• The results and methodology in NEDO-33144, Revision 2 of Regulatory Guide 1.99 * (Reference 4.8-6), and the projected fluence values listed in Table 4.2-1 were used to project the ART for 54 EFPY. The results of this projection are summarized in Table 4.2-5 for vessel beltline plates and welds. The ART values projected to 54 EFPY are used to develop P-T limit curves, as discussed in Section 4.2.4. Projected ART values are well below the 200°F end of life ART suggested in Section 3 of Regulatory Guide 1.99 and are, thus, acceptable for the period of extended operation.

Disposition: 10CFR 54.21 (c)(1)(ii) Reactor . vessel adjusted reference temperature TLAAs have been projected to the end of the period of extended operation. Time-Limited Aging Analyses Page 4.2-8 January 2010

• Columbia Generating Station License Renewal Application Technical Information Table 4.2-5 ART Values for 54 EFPY Initial Chemistry RTNDT/4T Fluence ARTNDT a.Margin ART Sub-Component(1)

Heat or Heat/Lot°' % Cu % Ni Factor R n/cm 2 OF O oA 0 F OF OF PLATES-. hmsr il TFuneATD Lower Shell C1272-1 0.15 0.60 110 28 2.71E+17 22.8 0 11.4 22.8 73.6 (Course #1) C1273-1 0.14 0.60 100 20 2.71E+17 20.7 0 10.4 20.7 61.4 C1273-2 0.14 0.60 100 4 2.71E+17 20.7 0 10.4 20.7 45.4 C1272-2 0.15 0.60 110 0 2.71E+17 22.8 0 11.4 22.8 45.6 Lower-Intermediate B5301-1(21 0.13 0.50 88 -20 8.1OE+17 33.1 0 16.5 33.1 46.2 Shell (Course #2) C1336-1 0.13 0.50 88 -8 8.10E+17 33.1 0 16.5 33.1 58.2 C1337-1 0.15 0.51 105 -20 8.10E+17 39.5 0 17.0 34.0 53.5 C1 337-2 0.15 0.51 105 -20 8.10E+17 39.5 0 17.0 34.0 53.5 NOZZLES: L51.7 .415 21.1 22.2 N6 (RHR /LPCI) Q2055W 790S 0.11 0.76 76.4 -20 4.48E+17 -21.1 11.4 10.5 21.1 :22.2 Time-Limited Aging Analyses Page 4.2-9 January 2010 Time-Limited Aging Analyses Page 4.2-9 January 201,0 A* Sub-Component (1) Heat or Heat/Lot (1) C1273-1 C1273-2 C1272-2 Lower-I ntermediate 85301-1 Shell (Course #2) C1336-1 C1337-1 .. Time-Limited Aging

• Table 4.2-5 ARTValues for 54 EFPY %Cu %Ni Initial Chemistry

%T Fluence llRT NOT Factor NOT n/cm 2 . OF of 0.1 0.60 100 20 2.71E+17 20.7 0.14 0.60 100 4 2.71E+17 20.7 0.15 0.60 110 0 2.71E+17 22.8 0.13 0.50 88 -20 8.10E+17 33.1 0.13 0.50 88 -8 33.1 0.15 0.51 105 39.5 Page 4.2-9,

• Columbia Generating Station License Renewal Application Technical Information Margin ART of of 10.4 20.7 10.4 20.7 0 11.4 22.8 0 16.5 33.1 46.2 0 33.1 58.2 34.0 53.5 January 201.0 Columbia Generating StationLicense Renewal Application Technical Information Table 4.2-5 (continued)

ART Values for 54 EFPY Tm IInitial 1/4T Sub-Component Heat or Heat/Lot 1 00 % Cu % Ni Chemistry RTNDT Fliuence ARTNDT Margin ART Factor OF n/cm 2 OF __ OF OF SWELDS Lower Vertical 04P046 / D217A27A 0.06 0.9 82 -48 2.71E+17 17.0 0 8.5 17.0 -14.0 (Axial/Longitudinal) 07L669 / K004A27A 0.03 1.02 41 -50 2.71 E+17 8.5 0 4.2 8.5 -33.0 3P4966/ 1214-3482 (S) 0.025 0.913 34 -30 2.71E+17 7.0 0 3.5 7.0 -15.9 3P4966 / 1214-3482 (T) -48 233.9 C3L46C J020A27A 0.02 0.87 27 -20 2.71E+17 5.6 0 2.8 5.6 -8.8 08M365 /G128A27A 0.02 1.10 27 -48 2.71E+17 5.6 0 2.8 5.6 -36.8 09L853 /A111A27A 0.03 0.86 41 -50 2.71E+17 8.5 0 4.2 8.5 -33.0 Lower-Intermediate 3P4966 /1214-3481 (S) 0.025 0.913 34 -20 8.10E÷17' 12.8 0 6.4 12.8 5.6 Vertical 3P4966 /1214-3481 (T) -6 19.7 (Axial/Longitudinal) 04P046 / D217A27A 0.06 0.90 82 -48 8.10E+17 30.8 0 15.4 30.8 13.7 05P018 / D211A27A 0.09 0.90 .122 -38 8.10E+17 45.9 0 22.9 45.9 53.8 624063 / C228A27A 0.03 1.00 41 -50 8.10E+17 15.4 0 7.7 15.4 -19.2 624039 / D224A27A 0.07 1.01 95 -36 8.10E+17 35.7 0 17.9 35.7 35.5 624039 / D205A27A 0.10 0.92 134 -50 8.10E+17 50.4 0 25.2 50.4 50.8 Lower to Lower- 492L4871 /A422B27AF 0.03 0.98 41 -50 3.30E+17 9.5 0 4.8 9.5 -31.0 Intermediate 04T931 /A423B27AG 0.03 1.00 41 -50 3.30E+17 9.5 0 4.8 9.5 -31.0 Girth 5P6756 / 0342-3477 0.08 0.936 153.97121 -50 3.30E+17 35.7 0 17.9 35.7 21.4 3P4955 / 0342-3443 (S) -16 1.2 (Circumferential) / 0342-3443 (T) 0.027 0.921 37 -20 3.30E+17 8.6 0 4.3 8.6 -2.8 ( For weld materials, (S) = Single Wire, (T) = Tandem Wire..(2) Adjusted chemistry factor determined per NEDO-33144, Section 4.2.1.1 (Reference 4.8-5), which was approved by the NRC in an SER (Reference 4.8-2), and updated per Columbia specific Integrated Surveillance Program (ISP) data.Time-Limited Aging Analyses Page 4.2-10 January 2010 o Sub-Component (1) Lower-Intermediate Vertical (Axial/Longitudinal) Lower to Lower-. Intermediate Girth (Circumferential) Heat or Heat/Lot (1) Table 4.2-5 (continued) ART Values for 54 EFPY %Cu %Ni Initial Chemistry RT NOT Factor OF (1) For weld materials, (S) = Single Wire; (T) = Tandem Wire. %T Fluence n/cm 2 L\RT NOT OF Columbia Generating Statiqn . License Renewal Application Technical Information Margin ART OF OF (2) Adjusted chemistry factor determined per NEDO-33144, Section 4.2.1.1 (Reference 4.8-5), which was approved by the NRC in an SER (Reference 4.8-2), and updated per Columbia specific Integrated Surveillance Program (ISP) data. Time-Limited Aging Analyses Page 4.2-10 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information 4.2.4 Pressure-Temperature Limits To ensure that adequate margins of safety are maintained for various modes of reactor operation, 10 CFR 50, Appendix G specifies pressure and temperature requirements for affected materials for the service life of the reactor vessel. The basis for these fracture toughness requirements is ASME Section Xl, Appendix G. The ASME Code requires P-T limits be established for hydrostatic pressure tests and leak tests; for operation with the core not critical during heatup and cooldown; and for core critical operation.

The Columbia P-T limit curves were revised in 2005 to include the effects of power uprate to 3486 MWt (Reference 4.8-2). The P-T limits are valid for 33.1 EFPY through the end of the currently licensed period. P-T limits for the period of extended operation will be calculated using the most accurate fluence projections available at the time of the recalculation. The projectionsý may be adjusted if there are changes in core design or if additional surveillance capsule results show the need for an adjustment. The projected-ART for the period of extended operation, see Section 4.2.3 above, gives confidence that future P-T curves will provide adequate operating margin.License amendment requests to revise the P-T limits will be submitted to the NRC for approval, when necessary to comply with 10 CFR 50 Appendix G, as part of theReactor Vessel Surveillance Program.Disposition: 10 CFR 54.21(c)(1)(iii) -Reactor vessel pressure-temperature limits will be adequately managed for the period of extended operation as part of the Reactor Vessel Surveillance Program.4.2.5 Reactor Vessel Circumferential Weld Inspection Relief BWRVIP-74-A (Reference 4.8-7) reiterated the recommendation of BWRVIP-05 (Reference 4.8-8) that RPV circumferential welds could be exempted from examination. The NRC safety evaluation report (SER) for BWRVIP-74 agreed, but required that plants apply for this relief request individually. The relief request should demonstrate that at the expiration of the current license, the circumferential welds satisfy the limiting conditional failure probability for circumferential welds in the (BWRVIP-05) evaluation. This evaluation of circumferential weld mean adjusted reference temperature is a TLAA.Energy Northwest analysis of the conditional probability of failure for the Columbia RPV circumferential welds is consistent with the position in BWRVIP-05 and NRC Generic Letter 98-05. The NRC concluded that the conditional probability of failure for the Columbia RPV circumferential welds was sufficiently low to justify elimination of the volumetric examinations through 33.1 EFPY (Reference 4.8-9).Time-Limited Aging Analyses Page 4.2-11 January 2010* *

• 4.2.4 Limits Columbia Generating Station License Renewal Application Technical Information To ensure that adequate margins of safety are maintained for various modes of reactor operation, 10 CFR 50, Appendix G specifies pressure.

and temperature requirements for affected materials for the service life of the reactor vessel. The basis for these fracture toughness requirements is ASME Section XI, Appendix G. The ASME Code requires P-T limits be established for hydrostatic pressure tests and leak tests; for operation with the core not critical during heatup and cooldown; and for core critical operation. . ." The Columbia P-T limit curves were revised in 2005 to include the effects of power uprate to 3486 MWt (Reference 4.8-2). The P-T limits are valid for 33.1 EFPY through the end of the currently licensed period. P-T limits for the period of extended operation will be calculated using the most accurate fluence projections available at the time of the recalculation. The projections: may be adjusted if there are changes in core design or if additional surveillance capsule results show the need for an adjustment. The projected* ART for the period of extended operation, see Section 4.2.3 above, gives confidence that future P'-T curves will provide adequate operating margin. License amendment requests to revise the P-T limits will be submitted to the NRC for approval, when necessary to comply with 10 CFR 50 Appendix G, as part of the Reactor Vessel Surveillance Program . Disposition: 10 CFR 54.21 (c)(1)(iii) -Reactor vessel pressure-temperature limits will be i:ldequately managed for the period of extended operation as part of the Reactor Vessel Surveillance Program. 4.2.5 Reactor Vessel Circumferential Weld Inspection Relief BWRVIP-74-A 4.8-7) reiterated the recommendation of BWRVIP-05 (Reference 4.8-8) that RPV circumferential welds could be exempted from examination. The NRC safety evaluation report (SER) for BWRVIP-74 agreed, but required that plants 'apply for this relief request individually, The relief request should demonstrate that at the expiration of the current license, the circumferential welds satisfy the limiting conditional failure probability for circumferential welds in the (BWRVIP-05) evaluation. This evaluation of Circumferential weld mean adjusted reference temperature is a TLAA. Energy Northwest analysis of the conditional probability of failure for the Columbia RPV circumferential welds is consistent with the position in BWRVIP-05 and. NRC Generic Letter 98-05. The NHC concluded that the conditional probability of failure for the Columbia ,RPV circumferential welds was sufficiently low to justify elimination ,of the volumetric examinations through 33.1 EFPY (Reference 4.8-9) . Time-Limited Aging Analys(3S Page 4.2-11 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 4.2-6 shows that the Columbia reactor pressure vessel circumferential (girth) weld parameters at 54 EFPY will remain within the NRC's (64 EFPY) bounding vessel parameters from the BWRVIP-05 SER. As such, the conditional probability of failure for circumferential welds remains below that stated in the NRC's Final Safety Evaluation of BWRVIP-05. Disposition: 10 CFR 54.21(c)(1)(ii) -Reactor vessel circumferential weld TLAAshave been projected to the end of the period of extended operation. Table 4.2-6 Circumferential Weld Parameters at 54 EFPY Columbia's Limiting NRC Limiting Plant Weld Wire (5P6756) Specific Analyses Parameter Description 54 EFPY Parameters at 64 EFPY Weld Copper content, % 0.08 0.10 Weld Nickel Content, % 0.936 0.99 Weld Chemistry Factor, OF 153.97 134.9 End-of-life RPV inside diameter neutron fluence, n/cm 2 4.78E+17 1.02E+19 Initial (unirradiated) reference temperature (RTNDT), OF 65 Increase in reference temperature dueto irradiation (ARTNDT), OF 44.0 135.6 Mean adjusted reference temperature (Mean ART = RTNoT + ARTNDT), OF -6.0 70.6 4.2.6 Reactor Vessel Axial Weld Failure Probability The NRC SER for BWRVIP-74-A (Reference 4.8-7) evaluated the failure frequency of axially oriented welds in BWR reactor vessels and determined that this failure frequency is below 5.OE-06 per reactor year for 40 years of reactor operation. Applicants for license renewal must evaluate axially oriented RPV welds to show that their failurefrequency remains below the 5.OE-06 value calculated in the BWRVIP-74 SER. The SER states that an acceptable way to do this is to show that the mean RTNDT of the limiting axial beltline weld at the end of the period of extended operation is less than the values specified in the SER. The mean RTNDT value from Table 1 of the SER for BWRVIP-74 that corresponds to a failure frequency of 5.OE-6 (for Pilgrim, a BWR/3) is 1141F. This 114 °F is below the 117 OF determined in Table 2.6-5 of the SER for BWRVIP-05 (Reference4.8-15) for Chicago Bridge & Iron vessels (similar to the Time-Limited Aging Analyses Page 4.2-12 IJanuary 2010 Columbia Generating Station License Renewal Application

• Technical Information Table 4.2-6 shows that the Columbia reactor pressure vessel circumferential (girth) weld at 54 EFPY will remain within the NRC's (64 EFPY) bounding vessel parameters from the BWRVIP-05 SER. As such, the conditional probability of failure for circumferential welds remains below that stated in the NRC's Final Safety Evaluation of BWRVIP-05.

Disposition: 10 CFR 54.21 (c)(1 )(ii) -Reactor vessel circumferential weld TLAAs have been projected to the end of the period of extended operation. , Table 4.2-6 Circumferential Weld Parameters at 54 EFPY Columbia's Limiting NRC Limiting Plant Weld Wire (5P6756) Specific Analyses Parameter Description 54 EFPY Parameters at 64 EFPY Weld Copper content, % O.OB 0.10 Weld Nickel Content, % 0.936 0.99 Weld Chemistry Factor, of 153.97 134.9 End-of-life RPV inside diameter neutron fluence , n/cm 2 4.7BE+17 1.02E+19 Initial (unirradiated) reference temperature (RT NOT), OF 65 Increase in reference temperature due to irradiation NOT), OF 44.0 135.6 Mean adjusted reference temperature (Mean ART = RT NOT + NOT), OF -6.0 70.6 4.2.6 Reactor Vessel Axial Weld Failure Probability The NRC SER for BWRVIP-74-A (Reference 4.8-7) evaluated the failure frequency of axially oriented welds in BWR reactor vessels and determined that this failure frequency is below 5.0E-:06 per reactor year for 40 years of reactor operation. Applicants for license renewal must evaluate axially oriented RPV welds to show that their failure frequency remains below the 5.0E-06 value calculated in the BWRVIP-74 SER. The SER states that an acceptable way to do this is to show that the mean RT NDT of the limiting axial beltline weld at the end of the period of extended operation is less than the values. specified in the SER. The mean RT NDT value from Table 1 of the SER for BWRVIP-74 that corresponds to a failure frequency of 5.0E-6 (for Pilgrim, a BWR/3) is 114°F. This 114 of is below the 117 of determined in Table 2.6-5 of the SER for

• BWRVIP-05 (Reference 4.8-15) for Chicago Bridge & Iron vessels (similar to the. Time-Limited Aging Analyses Page 4.2-12 January 2010 Columbia Generating Station License Renewal Application Technical Information Columbia RPV). Columbia will compare to the more limiting value from the SER for BWRVIP-74.

Table 4.2-7 shows that the Columbia limiting axial weld mean RTNDT at 54 EFPY is~only 16.9 OF. The Columbia axial weld mean RTNDT remains well below the 114 OF from the SER for BWRVIP-74, thus the Columbia axial weld failure frequency is well below the acceptable limit of.5.OE-6. Disposition: 10 CFR 54.21(c)(1)(ii) -Reactor vessel axial weld TLAAs have been projected to the end of the period of extended operation. Table 4.2-7 Axial Weld Parameters at 54 EFPY Columbia's Bounding Axial Weld Parameter Description Heat/Lot 05P018/D211A27A Weld Copper content, % 0.09 Weld Nickel Content, % 0.90 Weld Chemistry Factor, OF 122 RPV inside diameter neutron fluence , n/cm 2 1.17E+18 Initial (unirradiated) reference temperature (RTNDT), OF -38 Increase in reference temperature due to irradiation (ARTNDT), OF .54.9 Mean adjusted reference temperature (Mean ART = RTNDT + ARTNDT), OF 16.9 Time-Limited Aging Analyses Page 4.2-13 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Columbia RPV). Columbia will compare to the more limiting value from the SER for BWRVIP-74.

Table 4.2-7 shows that the Columbia limiting axial weld mean RT NOT at 54 EFPY is,only 16.9 oF. The Columbia axial weld mean RT NOT remains well below the 114 OF from the SER for BWRVIP-74, thus the Columbia axial weld failure frequency is well below the acceptable limit of-5.0E*-6. Disposition: 10 CFR 54.21 (c)(1)(ii) -Reactor vessel axial weld TLAAs have been projected to the end of the period of extended operation. Table 4.2-7 Axial Weld Parameters at 54 EFPY Columbia's Bounding Axial Weld Parameter Description Heat/Lot 05P018/D211A27 A Weld Copper content, % 0.09 Weld ,Nickel Content, % 0.90 Weld 'Chemistry Factor, OF 122 l RPV inside diameter neutron f1uence , n/cm 2 1.17E+18 -Initial (unirradiated) reference temperature (RT NOT), OF -38 Increase in reference temperature due to irradiation (IlRT NOT), OF 54.9 Mean adjusted reference temperature (Me,an ART = RT NOT + llRT NOT), OF 16.9 Time-Limited Aging AnalysE3s Page 4.2-13 January 2010 ) , Columbia Generating Station License Renewal Application Technical Information (This page intentionally blank]Time-Limited Aging Analyses Page 4.2-14 January 2010[This page intentionally blank1 Time-Limited Aging Analyses Page 4.2-14 Columbia Generating Station License Renewal Application Technical Information January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information

4.3 METAL

FATIGUE Fatigue evaluations for mechanical components are identified as TLAAs; therefore, the effects of fatigue must be addressed for license renewal. Fatigue is an age-related degradation mechanism caused by cyclic duty on a component by either mechanical or thermal loads.The primary code governing design and construction of the systems, structures, and components (SSCs) of interest is the ASME Boiler and Pressure Vessel Code. The ASME Code requires evaluation of transient thermal and mechanical load cycles for Class 1 components. Design cycles and fatigue usage for Columbia are provided in stress reports for the Class 1 components and summarized in FSAR Section 3.9 and FSAR Table 3.9-1.Class 1 SSCs include the reactor pressure vessel and reactor coolant pressure boundary components. Evaluation of fatigue for the reactor vessel is provided in Section 4.3.1. Fatigue of the non-Class 1 reactor vessel internals is addressed in Section 4.3.2. Fatigue of Class 1 reactor coolant pressure boundary piping and piping components is addressed in Section 4.3.3.Calculation 'of fatigue usage values is not required for non-Class 1 SSCs. Instead, stress intensification factors and lower stress allowables are used to ensurecomponents are adequately designed for fatigue.Certain components of the 'Primary Containment were evaluated for fatigue. Results of evaluations are provided in Section 4.6.The evaluation of reactor coolant environmental effects on fatigue of plant components is provided in Section 4.3.5.The design cycles for Columbia are summarized in FSAR Section 3.9 and FSAR Table 3.9-1. FSAR Table 3.9-1 is reproduced as Table 4.3-1. Columbia counts all fatigue significant cycles, not only for the design transients listed in FSAR Table 3.9-1 but also for the analysis of other plant components. The events listed in FSAR Table 3.9-1 havebeen evaluated and in some cases regrouped for easier counting. Faulted conditions listed in the FSAR are not used in the fatigue analyses and are not counted. Additional transients determined to be fatigue significant after the original design have been added to the counting procedure, while FSAR Table 3.9-1 lists the original design cycles. The.projected number of occurrences of design transients to 60 years, as shown in Table 4.3-2, determined that some analyzed numbers of transients may be exceeded. Theseprojections were done using linear extrapolation from the beginning of plant life. Recent operating experience suggests lower projections and as additional operating data is accumulated, subsequent projections will refine the number of cycles expected in 60 years. The last column of Table 4.3-2 lists the number of cycles that will be used for Time-Limited Aging Analyses.Page 4.3-1 January 2010*

• 4.3 METAL FATIGUE Columbia Generating Station License Renewal Application Technical Information Fatigue evaluations for mechanical components are identified as TLAAs; therefore, the effects of fatigue must be addressed for license renewal. Fatigue is an age-related degradation mechanism caused by cyclic duty on a component by either mechanical or thermal loads. The primary code governing design and construction of the systems, structures, and components (SSCs) of interest is the ASME Boiler and Pressure Vessel Code. The ASME Code requires evaluation of transient thermal and mechanical load cycles for Class 1 components.

Design cycles and fatigue usage for Columbia are provided in stress reports for the Class 1 components and summarized in FSAR Section 3.9 and FSAR Table 3.9-1. Class 1 SSCs the reactor pressure vessel and reactor coolant pressure boundary components. Evaluation of fatigue for the reactor vessel is provided in Section 4.3.1. Fatigue of the non-Class 1 reactor vessel internals is addressed in Section 4.3.2. Fatigue of Class 1 reactor coolant pressure boundary piping and piping components is addressed in Section 4.3.3 . . Calculation of fatigue usage values is not required for non-Class 1 SSCs. Instead, stress intensification factors and lower stress allowables are used to ensure components are adequately designed for fatigue. ) Certain components of the 'Primary Containment were evaluated for fatigue. Results of evaluations are provided in Section. 4. 6. The evaluation of reactor coolant environmental effects on fatigue of plant components is provided in Section 4.3.5. The design cycles for Columbia are summarized in FSAR Section 3.9 and FSAR Table 3.9-1. FSAR Table 3.9-1 is reproduced as Table 4.3-1 .. Columbia counts all fatigue significant cycles, not only for the design transients listed in FSAR Table 3.9-1 but also for the analysis of other plant components. The events listed in FSAR Table 3.9-1 have been evaluated and in some cases regrouped for easier counting. Faulted conditions listed in the FSAR are not used in the fatigue analyses and are not counted. Additional transients determined to be fatigue significant after the original design have been added to the counting procedure, while FSAR Table 3.9-1 lists the original design cycles. The projected number of occurrences of design transients to 60 years, as shown in Table 4.3-'2, determined that some analyzed numbers of transients may be exceeded. These projections were done using linear extrapolation from the beginning of plant life. Recent operating experience suggests lower projections and as additional operating data is accumulated, subsequent projections will refine the number of cycles expected in 60

• years. The last column of Table 4.3-2 lists the number of cycles that will be used for Time-Limited Aging Analyses Page 4.3-1 January 2010 Columbia Generating StationLicense Renewal Application Technical Information any future fatigue analyses (including the environmental fatigue analysis discussed Section 4.3.5). Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached.'I Time-Limited Aging Analyses Page 4.3-2 January 2010 Time-Limited Aging Analyses Page 4.3-2 January 2010 Columbia Generating Station License Renewal Application Technical Information any future fatigue analyses (including the environmental fatigue analysis discussed Section 4.3.5). Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached. I Time-Limited Aging Analyses Page 4.3-2 January 2010 *
• Columbia Generating Station License Renewal Application Technical Information Table 4.3-1Plant Events (FSAR Table 3.9-1)Conditions Number of*Normal, upsand testi .Cycles Bolt up/unbolt a, b 123 Design pressure hydrostatic test b 130 Startup (100 °F/hr heatup rate) b, c, f 117 Daily reduction to 75 % powera 10,000 Weekly reduction to 50 % power a 2,000 Control rod pattern change a 400 Loss of feedwater heaters (80 cycles total) b 80 Operating basis earthquake event at rated operating conditions 10/50 d Scrams Turbine generator trip, feedwater on, isolation valves stay open b 40 Other scrams b 140 Loss of feedwater pumps, isolation valves closed b 10 Single safety or relief valve blowdown b, f 8 Reduction to 0 % power, hot standby, shutdown (100 °F/hr cooldown rate) b c.f 111 High-pressure core spray operation (10), standby liquid control operation (10), low- 40 pressure core spray operation (10), and low-pressure coolant injection operation (10) b Scrams Reactor overpressure with delayed scram feedwater stays on, isolation valves stay I e openf Automatic blowdown e Improper start of cold recirculation loop Sudden start of pump in cold recirculation loop e Improper startup with reactor drain shutoff followed by turbine roll and increase to rated 1 power Pipe rupture Safe shutdown earthquake at rated operating conditions 1 ISME-ghydrostatic test '1.25 x design pressure hydrostatic test ASME Section III, NB-6222 and NB-31 14, No allows up to 10 of these tests without stress calculation additional Notes: a Applies to reactor pressure vessel only.b Thermal cycles are tracked for indication of reactor cumulative fatigue usage.C Bulk average vessel coolant temperature change in any 1-hr period.d Includes 50 peak operating basis earthquake (OBE) cycles for NSSS piping and 10 peak OBE cycles for other NSSS equipment and components.

Fifty peak OBE cycles are postulated for all BOP piping and components. The annual encounter probability of the one-cycle events is 10 for emergency and 104 for faulted events.Time-Limited Aging Analyses.Page 4.3-3 January 2010* *

• Table 4.3-1 Plant Events (FSAR Table 3.9-1) Columbia Generating Station License Renewal Application Technical Information Number of 1.25 x design pressure hydrostatic test ASME Section III, NB-6222 and NB-3114, allows u to 10 of these tests without stress calculation No additional Notes: 'a b c d e Applies to reactor pressure vessel only. Thermal cycles are tracked for indication of reactor cumulative fatigue usage. Bulk average vessel coolant temperature change in any 1-hr period. Includes 50 peak operating basis earthquake (OBE) cycles for NSSS piping and 10 peak OBE cycles for other NSSS equipment and components.

Fifty peak OBE cycles are postulated for all BOP piping and components. ' The annual encounter probability of the one-cycle events is 10-2 for emergency and 10-4 for faulted events. Time-Limited Aging Analyses Page 4.3-3 January 2010 Columbia Generating Station License. Renewal Application Technical Information Columbia is analyzed for 120 startups and shutdowns. The 120 startups consist of 117 normal startups and 3 natural circulation startups. The 120 shutdowns consist of 111 normal shutdowns, 8 single safety or relief valve blowdowns, and I rapid depressurization with delayed trip.Table 4.3-2 Actual Cycles and Projected Cycles Actual cycles 12/13/1984 60 year Cycles for Analyzed through (1211312044) future Conditions cycles 7/31/2007 projection(3) analyses(4) Boltup/Unbolt 123 21 55 60 Reactor Startup (100 degF/hr) 120 88 233 250 Reactor Shutdown (100 degF/hr) 111 87 230 242 Vessel Pressure Tests 130 2(1 2) 2(1) 60 Loss of Feedwater Heaters 80 0 0 80 Scram -Loss of feedwater pumps, 10 7 18 20 isolation valves closed Scram -Single safety relief valve 8 0 0 8 blowdown Scram -TG trip, FW on, isolation 22 58 60 valves open Scram -Other 140 34 90 90 LPCS operation 10 0 01 10 HPCS operation 10 4 10 104 LPCI operation 10 0 0 10 SLC operation 10 0 0 10 (1) Vessel hydrostatic pressure tests are no longer performed. Vessel operational leak tests have replaced the hydrostatic pressure tests.(2) These two pressure tests were hydrostatic pressure tests.(3) Projections were not changed for those events that have not occurred.(4) The 20 Scrams with Loss of Feedwater assume 3 HPCS injections per scram.The HPCS initiation assumes 10 additional injections without a scram. The HPCS nozzle is analyzed for 70 cycles combined from the two events.Time-Limited Aging Analyses Page 4.3-4 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Columbia is analyzed for 120 startups and shutdowns.

The 120 startups consist of 117 normal startups and 3 natural circulation startups. The 120 shutdowns consist of 111 normal shutdowns, 8 single safety or relief valve blowdowns, and 1 rapid depressurization with delayed trip. Table 4.3-2 Actual Cycles and Projected Cycles Actual cycles 12/13/1984 60 year Analyzed (12/13/2044) Conditions cycles 7/31/2007 projection(3) Boltup/Unbolt 123 21 55 Reactor Startup (100 degF/hr) 120 88 233 Reactor Shutdown (100 degF/hr) 111 87 230 Vessel Pressure Tests 130 2(1,2) 2(1) Loss of Feedwater Heaters 80 0 0 Scram -Loss of feedwater pumps, 10 7 18 isolation valves closed Scram -Single safety relief valve 8 0 0 blowdown Scram -TG trip, FW on, isolation 40, 22 58 valves open Scram -Other 140 34 90 LPCS operation 10 0 O. HPCS operation 10 4 10 LPCI operation 10 0 0 SLC operation 10 0 0 (1) Vessel hydrostatic pressure tests are no longer performed. Vessel operational leak tests have replaced the hydrostatic pressure tests. (2) . These two pressure tests were hydrostatic pressure tests. (3) Projections were not changed for those events that have not occurred. (4) The 20 Scrams with Loss of Feedwater assume 3 HPCS injections per scram. The HPCS initiation assumes 10 additional injections without a scram. The HPCS nozzle is analyzed for 70 cycles combined from the two events. Time-Limited Aging Analyses Page 4.3-4 Cycles for future analyses(4) 60 250 242 60 80 20 8 60 90 10 10 4 10 10 ) January 2010 *

• Columbia Generating Station License Renewal Application Technical Information

4.3.1 Reactor

Pressure Vessel Fatigue Analyses The reactor vessel assembly, consists of the pressure vessel, the vessel support skirt, the shroud support, nozzles, penetrations, stub tubes, head closure flanges, head closure studs, refueling bellows support, and stabilizer brackets.The materials, fabrication procedures, and testing methods used in the construction of the reactor pressure vessel meet the requirements of' ASME Section III, Class 1 vessels. Codes and standards, design criteria, and specification definitions for reactor vessel assembly structures and components are provided in FSAR Section 5.3.Design cumulative usage factors for the limiting RPV assembly locations based on the original analyzed values obtained from design reports are summarized in Table 4.3-3.These cumulative usage factors (CUFs) were calculated based on the design transients listed in Table 4.3-2.The projected number of occurrences of design transients to 60 years, as shown in Table 4.3-2, determined that some analyzed numbers of transients may be exceeded.These projections were done using linear extrapolation from the beginning of plant life.Recent operating experience suggests lower projections and as additional operating data is accumulated, subsequent projections will refine the number of cycles expected in 60 years. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached.Disposition: 10 CFR54.21(c)(1)(iii) -The effects of aging on the intended functions of the RPV will be adequately managed for the period of extended operation by the Fatigue Monitoring Program.Time-Limited Aging Analyses Time-Limited Aging Analyses Page 4.3-5 January 2010 Page 4.3-5 January 2010* *

• 4.3.1 Reactor Pressure Vessel Fatigue Analyses Columbia Generating Station License Renewal Application Technical Information The reactor vessel assemblY' consists of the pressure vessel, the vessel support skirt, the shroud support, nozzles, penetrations, stub tubes, head closure flanges, head closure studs, refueling bellows support, and stabilizer brackets.

' The materials, fabrication procedures, and testing methoqs used in the construction of the reactor pressure vessel meet the requirements of' ASME Section III, Class 1 . vessels. Codes and standards, design criteria, and speCification definitions for reactor \ vessel assembly structures and components are provided in FSAR Section 5.3. Design cumulative factors for the limiting RPV assembly locations based on the original analyzed values obtained from design reports are summarized in Table 4.3-3. These cumulative usagl3 factors (CUFs) were calculated based on the design transients listed in Table 4.3-2. projected number of occurrences of design transients to 60 years, as shown in Table 4.3-2, determined that some analyzed numbers of transients may be exceeded. These projections were done using' linear extrapolation from the beginning of plant life. ' Recent operating experience suggests lower projections and as additional operating data is accumulated, subsequent projections will refine the number of cycles expected , in 60 years. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached. Disposition: 10 CFR 54.21 (c)(1)(iii) -The effects of aging on the intended functions of the RPV will be adequately managed for the period of . extended operation by the Fatigue Monitoring Program . Time-Limited Aging Analyses Page 4.3-5 January 2010 Columbia Generating Station.License Renewal Application Technical Information Table 4.3-3 Fatigue Usage for Reactor Vessel Locations CUF of Location: Record Base plate 0.003 Core DP nozzle stub tube 0.125 Core spray nozzle forging 0.018 Core spray nozzle safe end 0.801Core spray nozzle sleeve 0.005 Core spray nozzle stub 0.187 CRD housing 0.196 CRD return nozzle safe end 0.543 CRD return nozzle forging 0.330 CRD stub tube 0.083 Drain nozzle NA FW nozzle forging 0.000 FW nozzle safe end 0.696 FW nozzle thermal sleeve 0.013 FW nozzle-shell junction 0.650'Instrument Nozzles (N12, N13, NA'N14)Jet pump instrumentation NA nozzle (N9)MS nozzle forging 0.340 MS nozzle safe end 0.030 CUF of Location: Record MS nozzle shell 0.470 Refueling bellows support 0.453 RHR/LPCI nozzle forging 0.116 RHR/LPCI safe end 0.157 RHR/LPCI safe end ext. 0.189 RHR/LPCI thermal sleeve 0.430 RRC inlet nozzle forging 0.22 RRC inlet nozzle safe end 0.214 RRC inlet nozzle thermal 0.0013 sleeve RRC outlet nozzle clad 0.005 RRC outlet nozzle forging 0.24 RRC outlet nozzle safe end 0.005 Shroud support -Inconel 0.399 Shroud support -low-alloy 0.102 steel Stabilizer bracket 0.678 Steam dryer brackets 0.064 Support skirt 0.064 Top head flange 0.855Vessel head spray nozzle 0.249 Vessel studs 0.985 Time-Limited Aging Analyses Page 4.3-6 January 2010 Time-Limited Aging Analyses Page 4.3-6 January 2010 Table 4.3-3 Columbia Generating Station License Renewal Application Technical Information Fatigue Usage for Reactor Vessel Locations CUF of CUF of Location: Record Location: Record Base plate 0.003 MS nozzle shell 0.470 Core DP nozzle stub tube 0.125 Refueling bellows support 0.453 Core spray nozzle forging 0.018 RHR/LPClnozzle forging 0.116 Core spray nozzle safe end 0.801 . RHR/LPCI safe end 0.157 Core spray nozzle sleeve 0.005 \ RHR/LPCI safe end ext. 0.189 Core spray nozzle stub 0.187 RHR/LPCI thermal sleeve 0.430 CRD housing 0.196 RRC inlet nozzle forging 0.22 CRD return nozzle safe end 0.543 RRC *inlet nozzle safe end 0.214 CRD return nozzle forging 0.330 RRC inlet nozzle thermal 0.0013 sleeve CRD stub tube 0.083 RRC.outlet nozzle clad 0.005 Drain nozzle NA RRC outlet nozzle forging 0.24 FW nozzle forging 0.000 RRC outlet nozzle safe end 0.005 FW nozzle safe end 0.696 Shroud support -Inconel 0.399 FW nozzle thermal sleeve 0.013 . . .-! Shroud support -low-alloy 0.102 steel FW nozzle-shell junction 0.650 Stabilizer bracket 0.678 .Instrument Nozzles (N12, N13, NA :N14) Steam dryer brackets 0.064 Jet pump instrumentation NA nozzle (N9) Support skirt 0.064 MS nozzle forging 0.340 Top head flange 0.855 MS nozzle safe end 0.030 Vessel head spray nozzle 0.249 Vessel studs 0.985 Time-Limited Aging Analyses page 4.3-6 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information
• 4.3.2 Reactor Vessel [lnternals This section includes fatigue analyses of the overall reactor vessel internals performed as part of the plant design, as well as fatigue analyses of jet pumps performed in response to operating conditions.

4.3.2.1 Internals Fatigue Analyses The RPV internals are described in terms of two assemblies: Core Support Structures and Reactor Internals. Core Support Structures include the shroud, shroud support (included as part of the rea'ctor vessel for fatigue), core plate with wedges and hold-down bolts, top guide, fuel supports, and control rod guide tubes. Reactor internals include the jet pump assemblies, jet pump instrumentation, feedwater spargers, vessel head spray line, differential pressure line, incore flux monitor guide tubes, initial startup neutron sources (removed), surveillance sample holders, core spray lines (in-vessel) and spargers, incore instrument housings, LPCI coupling, steam dryer, shroud head and steam separator, assembly, guide rods, and control rod drive (CRD) thermal sleeves.Design cumulative usage factors for the limiting reactor vessel internals locations are obtained from design reports and are summarized in Table 4.3-4. These CUFs were calculated based on the design transients listed in Table 4.3-2.The projected number of occurrences of design transients to 60 years, as shown. in Table 4.3-2, determined that some analyzed numbers of transients may be exceeded.these projections were done using linear extrapolation from the beginning of plant life.Recent operating experience suggests lower projections and as additional operating data is accumulated, subsequent projections will refine the number of cycles expected in 60 years. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached.Disposition: 10 CFR 64.21(c)(1)(iii) -The effects of aging on the intended functions of the reactor vessel internals will be adequately managed for the period of extended operation by the Fatigue Monitoring Program.-,-I_ Ag-ng #niyePae4 -7Jn ry21 I ime-UmIted Aging Analyses Page 4.3-7 January 201.0* *

• 4.3.2 Reactor Vessel Iinternals Columbia Generating Station License Renewal Application , Technical Information This section includes fatigue analyses of the overall reactor vessel internals performed as part of the plant dE!sign, as well as fatigue analyses of jet pumps performed in response to operating conditions:

4.3.2.1 Internals Fatigue Analyses The RPV internals are described in terms of two assemblies: Core Support Structures and Reactor Internals. Core Support Structures include the shroud, shroud support (included as part of reactor vessel for fatigue), core plate with wedges and down bolts,top guide, fuel supports, and control rod guide tubes. . Reactor internals include the jet pump assemblies, jet pump instrumentation, feedwater spargers, vessel head spray line, differential pressure line, incore flux monitor guide tubes, initial startup neutron sources (removed), ,surveillance sample holders, core spray lines (in-vessel) and spargers, incore instrument housings, LpCI coupling, steam dryer, shroud head and steam separator \ assembly, guide rods, and control rod drive (CRD) thermal sleeves. DeSign cumUlative usage factors for the limiting reactor vessel internals locations are obtained from deSign reports and are summarized in Table 4.3-4. These CUFs were calculated based on thE! design transients listed in Table 4.3-2. . , The projected number of occurrences of design transients to 60 years, as shown, in 'Table 4.3-2, determined that some analyzed numbers of transients may be exceeded. These projections were done using linear extrapolation from the of plant life. , Recent operating expe!rience suggests lower projections and as additional operating data is accumulated, subsequent projections will refine the number of cycles expected in 60 years. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached. Disposition: 10 CFR S4.21 {c)(1)(iii} -The effects of aging on the intended functions of the reactor vessel internals will be adequately for the period of extended operation by the Fatigue Monitoring Program . Time-Limited Aging Analys(3S Page 4.3-7 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 4.3-4 CUFs for Reactor Vessel Internals Location CUF Core spray sparger 0.20 Core spray piping 0,0598 Shroud (top guide wedge to shroud junction) 0.316 Shroud head bolt 0.047 Top guide (longest beam) 0.1625 CRD indicator tube 0.093 CRD outer tube 0.41 CRD cylinder 0.08 CRD index tube 0 CRD piston tube 0.3 CRD pressure housing 0.003 Incore guide tube <1 Core Ap / LC <0.01 Core plate 0.005 LPCI coupling 0.004 Jet pump riser brace 0.920(1)Vessel head spray line assembly 0.640 (1) The jet pump riser brace was analyzed in significant detail in response to an operating event at Columbia. This CUF contains usage for 1.5 times the design cycles shown in Table 4.3-2 plus operation at unbalanced flow plus the remainder of 60 years at balanced flow. See Section 4.3.2.2 for details.4.3.2.2 Jet Pump Fatigue Analyses In August 2000, Columbia operated for a period of time with the recirculation pumps in an unbalanced mode (pump speeds different by more than 50 percent). The effect of that flow imbalance on the fatigue usage of the jet pumps was an additional 0.0035.Inspections during the Spring 2001 outage (R-15) identified gaps in the jet pump set screws. To justify operation through cycle 16, a fatigue analysis of the jet pumps was done. The original fatigue a usage factor for all jet pumps was 0.50 due to the design cycles. The additional usage due to the gaps is 0.119 for jet pu'nps 1 and 6 (risers 1/2 and 5/6) plus a usage of 0.001 for the unbalanced flow event. This gives a cumulative Time-Limited Aging Analyses Page 4.3-8 January 2010 Table 4.3-4 CUFs for Reactor Vessel Internals Location Core spray sparger Core spray piping Shroud (top guide wedge to shroud junction) Shroud head bolt Top guide (longest beam) CRD indicator tube CRD outer tube CRD cylinder CRD index tube CRD piston tube CRD pressure housing Incore guide tube Core / LC \ Core plate* LPCI coupling Jet pump riser brace -Vessel head spray line assembly Columbia Generating Station License Renewal Application Technical Information CUF 0.20 0,0598 0.316 0.047 0.1625 0.093 0.41 0.08 0 0.3 0.003 <1 <0.01 \ 0.005 0.004 0.920(1) 0.640 (1) The Jet pump riser brace was analyzed In slgmficant detail In response to an operating event at Columbia. This CUF contains usage for 1.5 times the design cycles shown in Table 4.3-2 plus operation at unbalanced flow plus the remainder of 60 years at balanced flow. See Section 4.3.2.2 for details. 4.3.2.2 Jet Pump Fatigue Analyses In August 2000, Columbia operated for a period of time with the recirculation pumps in an unbalanced mode (pump speeds different by more than 50 percent). The effect of that flow imbalance on the fatigue usage of the jet pumps was an additional 0.0035. Inspections during the Spring 2001 outage (R-15) identified gaps in the jet pump set screws. To justify operation through cycle 16, a fatigue analysis of the jet pumps was done. The original fatigue a usage factor for all jet pumps was 0.50 due to the design cycles. The additional usage due to the gaps is 0.119 for jet pumps 1 and 6 (risers 1/2 and 5/6) plus a usage of 0.001 for the unbalanced flow event. This gives a cumulative Time-Limited Aging Analyses Page 4.3-8 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information usage factor of 0.620 for risers 1/2 and 5/6 while retaining the original 0.50 for the other eight risers.Jet pump clamps were installed on all 20 jet pumps during R-1 7 (2005).. Each jet pump mixer was clamped to its diffuser to minimize flow induced vibration caused by leakage at the mixer to diffuser slip joint interface.

As long as the set screw gaps remain within their revised criteria, no additional fatigue due to bypass leakage flow induced vibration is accumulated. These clamps greatly reduced the future potential for riser brace fatigue.The, latest gap status was reviewed after the 2007 outage. The usage factors were extended to 60 years by assuming the usage due to design cycles would increase from 0.5 to 0.75. Further assuming no subsequent unbalanced flow operation and no subsequent operation with gaps, results in a cumulative usage factor of, 0.87 (0.75 + 0.119 + 0.001) for risers 1/2 and 5/6 and 0.75 for the other eight risers. The maximum 60-year CUF of any jet pump riser has been conservatively projected at 0.920.The projected number of occurrences of design transients to 60 years, as shown in Table 4.3-2, determined that some analyzed numbers of transients may be exceeded.These projections were done using linear extrapolation from the beginning of plant life.Recent operating experience suggests lower projections and as additional operating data is accumulated, subsequent projections will refine the number of cycles expectedin 60 years. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached. The Fatigue Monitoring Program will also monitor the occurrence of design cycles and will monitor the jet pump gaps, effectively .managing the fatigue of the jet pumps through the period of extended operation. Disposition: 10CFR54.21(c)(1)(iii) -The effects of aging on the intended functions of the, jet pumps will be adequately managed for the period of extended operation by the Fatigue Monitoring Program.4.3.3 Reactor Coolant Pressure Boundary Piping and Piping Component Fatigue Analyses Fatigue analyses of Class 1 piping are based on the transients found in the Columbia Piping Specification that are in turn based on the design transients listed in FSAR Section 3.9. The Class 1 boundary encompasses all reactor coolant pressure boundary piping (pipe and fittings) and in-line components subject, to ASME Section Xl, Subsection IWB, inspection requirements. FSAR Tables 3.2-1, 3.2-2, and 3.2-3 give codes and standards, design criteria, and specification definitions for Class 1 piping.These components are generally, designed in compliance with ASME Section 111, Subsection NB-3600 (NC-3600 for <1" piping).Time-Limited Aging Analyses Time-Limited Aging Analyses Page 4.3-9 January2010 Page 4.3-9 I January2010

• *
• Columbia Generating Station License Renewal Application Technical Information usage factor of 0.620 for risers 1/2 and 5/6 while retaining the original 0.50 for the other eight risers. Jet pump clamps were installed on all 20 jet pumps during R-17 (2005). Each jet pump mixer was clamped to its diffuser to minimize flow induced vibration caused by leakage at the mixer to diffuser slip jOint interface.

As long as the set screw gaps remain within their revised criteria, no additional fatigue due to bypass leakage flow i'nduced vibration is accumulated. These clamps greatly reduced the future potential for riser brace fatigue. The, latest gap status was reviewed after the 2007' outage. The usage factors were* extended to 60 years by assuming the usage due to design cycles would increase from 0.5 to 0.75. Further assuming no subsequent unbalanced flow operation and no subsequent operation with gaps, results in a cumulative usage factor of. 0.87 (0.75 + 0.119 + 0.001) for risers 1/2 and 5/6 and 0.75 for the risers. The maximum 60:..year CUF of any jet pump riser has been conservatively projected at 0.920. The projected number of occurrences of design transients to 60 years, as shown in Table 4.3-2, determined that some analyzed numbers of transients may be exceeded. These projections were done using linear extrapolation from the beginning of plant life. Recent operating experience suggests lower projections and as additional operating data is accumulated, subsequent projections will refine the number of cycles expected in 60 years. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached. The Fatigue Monitoring Program will also monitor the occurrence of design cycles and will monitor the jet pump gaps, effectively managing the fatigue of the jet pumps through the period of extel1ded operation. Dis position: 10 CFR 54.21 (c)(1)(iii) -The effects of aging on the intended functions of the. jet pumps will be adequately managed for the period of extended operation by the Fatigue Monitoring Program. 4.3.3 Reactor Coolant Pressure Boundary Piping and Piping Component Fatigue Analy!ses Fatigue analyses of Class 1 piping are based on the transients found in the Columbia Piping Specification that are in turn based on the. design transients listed in FSf.\R Section 3.9. The Class 1 boundary encompasses all reactor coolant pressure boundary piping (pipe and fittings) and in-line components subject to ASME Section XI, Subsection IWB, inspe!ction requirements. FSAR Tables 3.2-1, 3.2-2, and 3.2-3 give codes and standards, design criteria, and specification definitions for Class 1 piping. These components are generally* designed in compliance with ASME' Section III, Subsection NB-3600 (NC-3600 for S1" piping) . Time-Limited Aging Analyses Page 4.3-9 , January 2010 Columbia Generating Station License Renewal Application Technical Information FSAR Section 3.6.2 indicates that potential intermediate high energy line break locations can be eliminated based on CUFs being less than 0.1 if other stress criteria are also met. The usage factors, as calculated in the design fatigue analyses, account for the design transients assumed for the original 40-year life of the plant. Therefore,the determination of cumulative usage factors used in the selection of postulated high energy line break locations are TLAAs The Fatigue Monitoring Program will identify when the transients for piping systems are approaching their analyzed numbers of cycles. Prior to any transient exceeding its analyzed number of cycles for a piping system, the design calculations for that system will be reviewed to determine if any additional locations should be designated as postulated high energy line breaks, under the original criteria of FSAR Section 3.6. If other locations are determined to require consideration as postulated break locations,. actions will be taken to address the new break locations. During initial plant startup, an induction heating stress improvement (IHSI) process was used on various RPV nozzles to safe end and safe end to pipe welds. In the 1994 refueling outage, Columbia performed a mechanical stress improvement process (MSIP) for multiple RPV nozzles to safe end and safe end'to pipe welds. No credit is taken for MSIP or IHSI in the calculation of CUFs for the Columbia vessel nozzles and safe ends.All Class 1 piping was reviewed for the power uprate. The power uprate evaluation scaled existing fatigue analyses based on the changes in stress expected from the power uprate. This evaluation showed that there was adequate margin in each system to accommodate the power uprate (the increased CUF after the power uprate was approximated by the report). The maximum CUFs for Class 1 piping are shown in Table 4.3-5. The Fatigue Monitoring Program uses the systematic counting of plant transient cycles to ensure that component design fatigue usage limits are not exceeded.Design fatigue usage for 40 years of operation is provided in Table 4.3-5 for the limiting reactor coolant pressure boundary components. A review of Columbia's documentation found several fatigue analyses for Class 1 valves that were TLAAs. The fatigue usage for those valves is based on transients that are tracked by the Fatigue Monitoring Program. The maximum CUFs for any Class 1 valves is 0.84 for the head spray inside containment check valve and 0.6599 for five 12 inch containment isolation valves. These CUFs are included in Table 4.3-5.Metal fatigue for all Class 1 reactor coolant pressure boundary piping and in-line components (as listed in Table 4.3-5) is managed by the Fatigue Monitoring Program.The Fatigue Monitoring Program will identify when the transients for piping systems are approaching their analyzed numbers of cycles. Prior to any transient exceeding its analyzed number of cycles for a piping system, the design calculations for that system will be reviewed and appropriate actions will be taken.Time-Limited Aging Analyses Page 4.3-10 January 2010 Columbia Generating Station License Renewal Application Technical Information FSAR Section 3.6.2 indicates that potential intermediate high energy line break locations can be eliminat.ed based on CUFs being less than 0.1 if other stress criteria are also met. The usage factors, as calculated in the design fatigue analyses, account for the design transients assumed for the original 40-year life of the plant. Therefore, the determination of cumulative usage factors used in the selection of postulated high energy line break locations are TLAAs The Fatigue Monitoring" Program will identify when the transients for piping systems are approaching their analyzed numbers of cycles. Prior to any transient exceeding its analyzed number of cycles for a piping system, the design calculations for that system will be reviewed to determine if any additional locations should be designated as postulated high energy line breaks, under the original criteria of FSAR Section 3.6. If other locations are determined to require consideration as postulated break locations, actions will be taken to address the new break locations. During initial plant startup, an induction heating stress improvement (IHSI) process was used on various RPV nozzles to safe end and safe end to pipe welds. In the 1994 refueling outage, Columbia performed a mechanical stress improvement process (MSIP) for multiple RPV nozzles to safe end and safe end'to pipe welds. No credit is taken for MSIP or IHSI in the calculation of CUFs for the Columbia vessel nozzles and safe ends.

• All' Class 1 piping was reviewed for the power uprate. The power uprate evaluation
• scaled existing fatigue analyses based on the changes in stress expected from the power uprate. This evaluation showed that there was adequate margin in each system to accommodate the power uprate (the increased CUF after the power uprate was approximated by the report). The maximum CUFs for Class 1 piping are shown in Table 4.3-5. The Fatigue Monitoring Program uses the systematic counting of plant transient cycles to ensure that component design fatigue usage limits are not exceeded.

Design fatigue usage for 40 years of operation is provided in Table 4.3-5 for the limiting reactor coolant pressure boundary components. A review of Columbia's documentation found several fatigue analyses for Class 1 valves that were TLAAs. The fatigue usage for those valves is based on transients that are tracked by the Fatigue Monitoring Program. The maximum CUFs for any Class 1 valves is 0.84 for the head spray inside containment check valve and 0.6599 for five 12 inch containment isolation valves. These CUFs are included in Table 4.3-5. Metal fatigue for all Class 1 reactor coolant pressure boundary piping and in-line components (as listed in Table 4.3-5) is managed by the Fatigue Monitoring Program. _ The Fatigue Monitoring Program will identify when the transients for piping systems are approaching their analyzed numbers of cycles. Prior to any transient exceeding its analyzed number of cycles for a piping system, the design calculations for that system will be reviewed and appropriate actions will be taken. . Time-Limited Aging Analyses Page 4.3-10 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information Disposition:

10 CFR 54.21(c)(1)(iii) The effects of aging on the intended functions of the reactor coolant pressure boundary piping and components will be adequately managed for the period of extended operation by the Fatigue Monitoring Program.Table 4.3-5 CUFs for Reactor Pressure Boundary Piping and Piping Components System or Component Max CUF Reactor Feedwater Line A 0.250 Reactor Feedwater Line B 0.137 Reactor Feedwater / RWCU 0.588 Main Steam Line A 0.446 Main Steam Line B 0.7225 Main Steam Line C 0.222 Main Steam Line D 0.647 Main Steam Isolation Valves 0.0093 Reactor Recirculation Loop A 0.850 Reactor Recirculation Loop B 0.920 Reactor Recirculation Isolation Valves 0.0036 Reactor Water Cleanup 0.152 High Pressure Core Spray 0.237 Low Pressure Core Spray 0.145 Residual Heat Removal .0.001 Reactor Core Isolation Cooling 0.487 Reactor Vessel Head Spray 0.209 Reactor Vessel Head Vent to Main Steam 0.940 Reactor Vessel Level Instrument Lines and Condensing Pots 0.49 Standby Liquid Control System 0.262 Head spray check valve 0.8412 inch containment isolation valves (5) 0.6599 Time-Limited Aging Analyses Page 4.3-11 January 2010 Time-Limited Aging Analyses Page 4.3-11 January 2010* ". Columbia Generating Station License Renewal Application Technical Information Disposition: 10 CFR 54.21 (c)(1)(iii) -The effects of aging on the intended functions of the reactor coolant pressure boundary piping and components will be adequately managed for the period of extended operation by the Fatigue Monitoring Program. . Table 4.3-5 CUFs for React4Jr Pressure Boundary Piping and Piping Components System or Component Max CUF Reactor Feedwater Line A 0.250 Reactor Feedwater Line B 0.137 Reactor Feedwater / RWCU 0.588 Main Steam Line A 0.446 Main Steam Line B 0.7225 Main Steam Line C 0.222 Main Steam Line D 0.647 Main Steam Isolation Valves 0.0093 Reactor Recirculation Loop A 0.850 Reactor Recirculation Loop B 0.920 Reactor Recirculation Isolation Valves 0.0036 Reactor Water Cleanup 0.152 -High Pressure Core Spray 0.237 Low Pressure Core Spray 0.145" , Residual Heat Removal 0.001 Reactor Core Isolation Cooling 0.487 Reactor Vessel Head Spray 0.209 Reactor Vessel Head VEmt to Main Steam 0.940 Reactor Vessel Level Instrument Lines and Condensing Rots 0.49 Standby Liquid Control System 0.262 Head spray check valve 0.84 12 inch containment isolation valves (5) 0.6599 Time-Limited Aging AnalysEls Page 4.3-11 January 2010 Columbia Generating Station License Renewal Application Technical Information 4.3.4 Non-Class 1 Component Fatigue Analyses The specific codes and standards to which SSCs were designed are listed in FSAR Table 3.2-1 and FSAR Table 3.2-2.Non-class 1 components that are Quality Group B or C are designed and constructed to the ASME Boiler and Pressure Vessel Code. The design of ASME III Code Class 2 and 3 piping systems incorporates a cycle based stress range reduction factor fordetermining acceptability of piping design with respect to thermal stress range.Columbia SSCs designated as quality group D are designed to ANSI B31.1, which also incorporates stress range reduction factors based Upon the number of thermal cycles.In general, a stress range reduction factor of 1.0 in the stress analyses applies for up to 7,000 thermal cycles. The allowable stress range is reduced by the stress range reduction factor if the number of thermal cycles exceeds 7,000. If fewer than 7,000 cycles are expected through the period of extended operation, then the fatigue analysis (stress range reduction factor) of record will remain valid through the period of extended operation. The non-Class 1 aging management reviews for Columbia determined piping locations susceptible to fatigue. The fatigue evaluation of non-Class 1 components determined whether the associated operating temperature exceeded threshold values for the affected materials and, if so, evaluated the number of transient cycles expected. In every case, the number of projected cycles for 60 years was found to be less than 7,000for -piping and in-line components whose temperatures exceed threshold values.Therefore, fatigue for non-Class 1 piping and in-line components remains valid for the period of extended operation. None of the non-Class 1 vessels, heat exchangers, storage tanks, or pumps were designed to ASME Section VIII, Division 2 or ASME Section III, Subsection NC-3200.Therefore, there is no fatigue TLAA for these components. Disposition: 10 CFR 54.21(c)(1)(i) -The analyses remain valid for the period of extended operation. Time-Limited Aging Analyses Page 4.3-12 January 2010 Columbia Generating Station

• License Renewal Application Technical Information 4.3.4 Non-Class 1 Component Fatigue Analyses The specific codes and standards to which SSCs were designed are listed in FSAR Table 3.2-1 and FSAR Table 3.2-2. Non-class 1 components that are Quality Group B or C are designed and constructed to the ASME Boiler and Pressure Vessel Code. The design of ASME III Code Class 2 and 3 piping systems incorporates a cycle based stress range reduction factor for determining acceptability of piping design with respect to thermal stress range. Columbia SSCs designated as quality group D are designed to ANSI B31.1, which also incorporates stress range reduction factors based upon the number of thermal cycles. In general, a stress range reduction factor of 1.0 in the stress analyses applies for upto 7,000 thermal cycles. The allowable stress range is reduced by the stress range reduction factor if the number of thermal cycles exceeds 7,000. If fewer than 7,000 cycles are expected through the period of extended operation, then the fatigue analysis (stress range reduction factor) of record will remain valid through the period of extended operation.

The non-Cla,ss 1 aging management reviews for Columbia determined piping locations susceptible to fatigue. The fatigue evaluation of non-Class 1 components determined whether the associated operating temperature exceeded threshold values for the affected materials and, if so, evaluated the number of transient cycles expected. In

• every case, the number of proJected cycles for 60 years was found to be less than 7,000 for -piping and in-line components whose temperatures exceed threshold values. Therefore, fatigue for non-Class 1 piping and in-line components remains valid for the period of extended operation.

None of the non-Class 1 vessels, heat exchangers, storage tanks, or pumps were designed to ASME Section VIII, Division 2 or ASME Section III, Subsection NC-3200. Therefore, there is n,o fatigue TLAA for these components. Disposition: 10 CFR 54.21(c)(1)(i) -The analyses remain valid for the period of extended operation. Time-Limited Aging Analyses Page 4.3-12 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information

.4.3.5 Effects of Reactor Coolant Environment on Fatigue Life of Components and Piping 4.3.5.1 Background The NRC requires applicants for license renewal to address the reactor coolant environmental effects on fatigue of plant components (NUREG-1800 Section 4.3). The minimum set of components for a BWR of Columbia's vintage is derived from NUREG/CR-6260 (Reference 4.8-10), as follows: 1. Reactor vessel shell and lower head 2. Reactor vessel feedwater nozzle 3. Reactor recirculation piping (including inlet and outlet nozzles)4. Core spray line reactor vessel nozzle and associated Class 1 piping 5. Residual heat removal return line Class 1 piping 6. Feedwater line Class 1 piping In NUREG-1800, the NRC mentions using the calculational approach whereby the fatigue life adjustment factor (Fen) is determined for each fatigue-sensitive component and applying those environmental fatigue correction factors to the component CUFs to verify acceptability of the components for the period of extended operation. In NUREG-1800, the NRC further points out equations for calculating Fen values as being those contained in NUREG/CR-6583 (Reference 4.8-11) for carbon steel and low alloy steel components and in NUREG/CR-5704 (Reference 4.8-12) for austenitic stainless steel components. Nickel alloy components were also analyzed using the stainless steel equations in NUREG/CR-5704. Environmentally assisted fatigue (EAF) evaluations are not applied during the current licensing basis. EAF evaluations done for the period of extended operation apply the EAF correction factors per NUREG-6260. 4.3.5.2 Columbia Evaluation Using projected cycles from the Fatigue Monitoring Program and methodology accepted by the NRC, as noted above, the limiting locations (a total of 14 component locations corresponding to the six NUREG/CR-6260 components) for the material for each component location were evaluated. None of the 14 locations evaluated have an environmentally adjusted CUF of greater than 1.0 (see Table 4.3-6).Values for dissolved oxygen, before and after the adoption of Hydrogen Water Chemistry (HWC), were used in the Fen determination. The plant operated with Normal Water Chemistry (NWC) for 20.9 years from January 19, 1984 (initial startup) until November 28, 2004. The plant has operated with HWC from November 28, 2004, and is assumed to continue operating with HWC until January 13, 2044; a combined time of Time-Limited Aging Analyses Page 4.3-13 January 2010*

• Columbia Generating Station License Renewal Application Technical Information

4.3.5 Effects

of Reactor Coolant Environment on Fatigue Life of Components and Piping 4.3.5.1 Background \ The NRC requires applicants for license renewal to address the reactor coolant environmental effects on fatigue of plant components (NUREG-1800 Section 4.3). The minimum set of components for a BWR of Columbia's vintage is derived from NUREG/CR-6260 (Reference 4.8-10), as follows: 1. Reactor shell and lower head 2. Reactor feedwater nozzle 3. Reactor recirculation piping (including inlet and outlet nozzles) 4. Core spray line reactor vessel nozzle and associated Class 1 piping 5. Residual heat removal return line Class 1 piping 6. Feedwater line Class 1 piping In NUREG-1800, the NRC mentions using the calculational approach whereby the fatigue life adjustment factor (Fen) is deteni1ined for each fatigue-sensitive component and applying those environmental fatigue correction factors to the component CUFs to verify acceptability of the components for the period of extended operation. In NUREG-1800, the NRC further points out equations for calculating Fen values as being those contained in NUREG/CR-6583 (Reference 4.8-11) for carbon steel and low alloy steel components and in NUREG/CR-5704 (Reference 4.8-12) for austenitic stainless steel components. Nickel alloy* components were also analyzed using the stainless steel equations inNUREG/CR-5704. Environmentally fatigue (EAF) evaluations are not applied during the current licensing basis. EAF Ewaluations done for the period of extended operation apply the EAF correction factors per NUREG-6260. 4.3.5.2 Columbia Evaluation Using projected cycles from the Fatigue Monitoring Program and methodology accepted by the NRC, as noted above, the limiting locations (a total of 14 component locations corresponding to the six NUREG/CR-6260 components) for the material for each component location were evaluated. None of the 14 locations evaluated have an environmentally adjusted CUF of greater than 1.0 (see Table 4.3-6). Values for dissolved oxygen, before and after the adoption of Hydrogen Water Chemistry (HWC), were used in the Fen determination. The plant operated with Normal Water Chemistry (NWC) for 20.9 years from January 19, 1984 (initial startup) until November 28, 2Q04. The plant has operated with HWC from November 28, 2004, and is assumed to continuEl operating with HWC until January 13, 2044; a combined time of Time-Limited Aging Page 4.3-13 January 2010 Columbia Generating StationLicense Renewal Application Technical Information 39.1 years. The time Columbia has operated under both NWC (21 years) and HWC (39 years) conditions was considered in the estimation of an effective Fen based on a time weighted average of the HWC and NWC Fen values over 60 years of operation. The cumulative fatigue usage factor incorporating the effects of reactor coolant environment is obtained by multiplying the usage factor by Fen.Original fatigue usage calculations were reviewed, and the transient groupings and load pairs used in those analyses were carried over to the EAF analyses. This ranged from a single transient grouping with a single load pair for the RRC inlet nozzle safe end to nearly a dozen load pairs and individual transients for the feedwater nozzle and RRC piping. For each load pair, a value of Fen was calculated. The environmentally adjusted usage factor for each load pair was then obtained by multiplying the usage factor by the Fen for that load pair. The environmentally adjusted cumulative usage factor for each location was obtained by summing the individual environmentally adjusted usage factors for each load pair.The environmentally-adjusted CUFs for Columbia are shown in Table 4.3-6. The minimum Fen for any load pair, the maximum Fen for any load pair, and an "average Fen for each location is given. The average Fen is simply the final environmentally assisted CUF divided by the non-environmentally assisted CUF.Columbia will manage the aging effect of fatigue for the period of extended operation, with consideration of the environmental effects using the Fatigue Monitoring Program in accordance with 10 CFR 54.21(c)(1)(iii). Disposition: 10 CFR 54.21(c)(1)(iii) -The effects of environmentally-assisted fatigue will be adequately managed for the period of extended operation using the Fatigue Monitoring Program.Time-Limited Aging Analyses' Page 4.3-14 January 2010 Time-Limited Aging Analyses'Page 4.3-14 January 2010 l Columbia Generating Station License Renewal Application

• Technical Information 39.1 years. The time Columbia has operated under both NWC (21 years) and HWC (39 years) conditions was considered in the estimation of an effective Fen based on a time
• weighted average of the HWC and NWC Fen values over 60 years of operation.

The. cumulative fatigue usage factor incorporating the effects of reactor coolant environment is obtained by multiplying the usage factor by Fen. Original fatigue usage calculations were reviewed, and the transient groupings and load pairs used in those analyses were carried over to the EAF analyses. This ranged from a single transient grouping with a single load pair for the RRC inlet nozzle safe end to nearly a pozen load pairs and individual transients for the feedwater nozzle and RRC piping. For each load pair, a value of Fen was calculated. The environmentally adjusted usage factor for each load pair was then obtained by multiplying the usage factor by the Fen for that load pair. The environmentally adjusted cumulative usage factor for each location was obtained by summing the individual environmentally adjusted usage factors for each load pair. The environmentally-adjusted CUFs for Columbia are shown in Table 4.3-6. The minimum Fen for any load pair, the maximum Fen for any load pair, and an "average Fen" for each location is given. The average Fen is simply the final environmentally assisted CUF divided by the non-environmentally assisted CUF. Columbia will manage the aging effect of fatigue for the period of extended operation,

• with consideration of the environmental effects using the Fatigue Monitoring Program in accordance with 10 CFR 54.21(c)(1)(iii).

Disposition: 10 CFR 54.21(c)(1)(iii) -The effects of environmentally-assisted fatigue will be adequately managed for the period of extended operation using the Fatigue Monitoring Program. Time-Limited Aging Analyses\ Page 4.'3-14 January 2010

• Columbia Generating Station License Renewal Application Technical Information Table 4.3-6 CUFs for NUREG/CR-6260 Locations Columbia MRevised Per NUREG/CR-5704 and NUREGICR-6583 NUREG/CR-6260 generic plant-specific CUF in laonspati type air (2) Min. Average Max. Environmentally locationslocations 3 3 assisted CUF Fen(3 Fen(3 asse U 1 Reactor vessel shell and CRD stub tube Nickel 0.0125 12.90 12.90 12.90 0.162 lower head Alloy 1Reactor vessel shell and 008 1 lower head CRD housing SS 0.0007 12.90 12.90 12.90 0.0088 2 Reactor vessel feedwater FW nozzle to nozzle shell junction ( LAS 0.132 3.04 6.72 20.52 0.887 Reactor vessel feedwater FW nozzle safe Nickel 2 nozzle end (1) Alloy 0.00126 3.29 4.77 6.43 0.00601 Reactor recirculation piping Reactor vessel 3 (including inlet and outlet RRC inlet nozzle SS 0.026 12.90 12.90 12.90 0.335 nozzles) safe end Reactor recirculation piping Reactor vessel 3 (including inlet and outlet RRC outlet LAS 0.054 10.51 10.51 10.51 0.567 nozzles) nozzle forging _Reactor recirculation piping 3 (including inlet and outlet RRC piping SS 0.373 2.55 2.66 12.90 0.994 nozzles)Core spray line reactor Reactor vessel Nickel 4 vessel nozzle and nozzle safe end 0.241 2.55 3.95 3.96 0.953 associated Class 1 piping -Core Spray AI Ioy I II Time-Limited Aging Analyses Page 4.3-15 January 2010 Time-Limited Aging Analyses Page 4.3-15 January 2010* . , NUREG/CR-6260 generic locations 1 Reactor vessel shell and lower head 1 Reactor vessel shell and lower head 2 Reactor vessel feedwater nozzle 2 Reactor vessel feedwater nozzle Reactor recirculation piping 3 (including inlet and outlet nozzles) Reactor recirculation piping 3 (including inlet and outlet nozzles) Reactor recirculation piping 3 (including inlet and outlet nozzles) Core spray line reactor 4 vessel nozzle and associated Class 1 piping -Time-Limited Aging Analyses
• Table 4.3-6
• Columbia Generating Station License Renewal Application Technical Information CUFs for NUREG/CR-6260 Locations Columbia . Revised Per NUREG/CR-5704 and NUREG/CR-6583 plant-specific Material CUFin locations*

type air (2) Min. Average Max. Environmentally Fen (3) Fen (3) Fen (3) assisted CUF CRD stub tube Nickel 0.0125 12.90 12.90 12.90 0.162 Alloy CRD housing SS 0.0007 12.90 12.90 12.90 0.0088 FW nozzle to LAS 0.132 3.04 6.72 20.52 0.887 shell junction (1) FW nozzle safe Nickel 0.00126 3.29 4.77 6.43 0.00601 end (1) Alloy . Reactor vessel RRC inlet nozzle SS 0.026 12.90 12.90 12.90 0.335 safe end Reactor vessel RRC outlet LAS 0.054 10.51 10.51 10.51 0.567 nozzle forging RRC piping SS 0.373 2.55 2.66 12.90 0.994 Reactor vessel Nickel nozzle safe end Alloy 0.241 2.55 3.95 3.96 0.953 -Core Spray Page 4.3-15 January 2010 Columbia Generating Station License Renewal Application Technical Information Table 4.3-6 (continued) CUFs for NUREG/CR-6260 Locations Columbia MRevised Per NUREG/CR-5704 and NUREG/CR-6583 NUREG/CR-6260 generic plant-specific CUF in .locations locations type 'air (2) Min. Average Max. Environmentally Fen(3) Fen(3) Fen(3) assisted CUF Core spray line reactor 4 vessel nozzle and LPCS piping CS 0.155 1.74 5.22 7.33 0.809 associated Class 1 piping Core spray line reactor 4 vessel nozzle and HPCS piping CS 0.321 1.74 2.25 2.49 0.723 associated Class 1 piping Residual Heat Removal RHRILPCI Nickel 5 (RHR) nozzles and 0.139 Nicl0.856 associated Class 1 piping nozzle safe end Alloy Residual Heat Removal RHR/LPCl 5 (RHR) nozzles and nozzle safe end CS 0.190 1.74 2.39 2.75 0.455associated Class 1 piping extensionResidual Heat Removal 5 (RHR) nozzles and RHR/LPCI piping CS 0.001 20.49 20.49 20.49 0.02 associated Class 1 piping Feedwater line Class 1 RFW/RWCU Tee CS 0.210 1.74 1.85 2.85 0.389 6 piping .(1)Note: CS is carbon steel, LAS is low alloy steel, SS is stainless steel (1) Assumed NWC dissolved oxygen concentration equaled to 150 ppb for the RFW nozzle and RFW/RWCU Tee Fen calculation. (2) CUF of record previously identified in Table 4.3-3 and Table 4.3-5.(3)' Effective Fen determined for each load pair based on a time weighted average for HWC and NWC for 60 years of operation. Average Fen is the reported environmentally assisted CUF divided by the non-environmentally assisted CUF.Time-Limited Aging Analyses Page 4.3-16 January 2010 Time-Limited Aging Analyses Page 4.3-16 January 2010 Table 4.3-6 (continued) Columbia Generating Station License Renewal Application Technical Information , CUFs for NUREG/CR-6260 Locations Per NUREG/CR-5704 and NUREG/CR-6583 Columbia Revised NUREG/CR-6260 generic plant-specific Material CUFin locations locations type , air (2) . Min. Average Max . Environmentally Fen (3) Fen (3) Fen (3) assisted CUF Core spray line reactor 4 vessel nozzle and LPCS piping CS 0.155 1.74 5.22 7.33 0.809 associated Class 1 piping Core spray line reactor 4 vessel nozzle and HPCS piping CS 0.321 .1.74 2.25 2.49 0.723 associated Class 1 piping Residual Heat Removal RHRlLPCI Nickel 5 (RHR) nozzles and nozzle safe end Alloy 0.139 . 2.55 6.16 6.94 0.856 associated Class 1 piping Residual Heat Removal RHRlLPCI 5 (RHR) nozzles and nozzle safe end CS 0.190 1.74 2.39 2.75 0.455 associated Class 1 piping extension Residual Heat Removal 5 (RHR) nozzles and RHRlLPCI piping CS 0.001 20.49 20.49 20.49 0.02 associated Class 1 pipinQ -6 Feedwater line Class 1 RFW/RWCU Tee CS 0.210 1.74 . 1.85 2.85 0.389 piping (1) Note: CS is carbon steel, LAS is low alloy steel, SS is stainless steel (1) Assumed NWC dissolved oxygen concentration equaled to 150 ppb for the RFW nozzle and RFW/RWCU Tee Fen calculation. (2) CUF ofrecord previously identified in Table 4.3-3 and Table 4.3-5. (3)' Effective Fen determined for each load pair based on a time weighted average for HWC and NWC for 60 years of operation. Average Fen is the reported environmentally assisted CUF divided by the non-environmentally assisted CUF. Time-Limited Aging Analyses Page 4.3-16 January 2010 . * *

• Columbia Generating Station License Renewal Application Technical Information

4.4 ENVIRONMENTAL

QUALIFICATION OF ELECTRICAL EQUIPMENT Environmental qualification (EQ) analyses for those components with a qualified life of.40 years or greater are identified as TLAAs. NRC regulation 10CFR50.49"Environmental Qualification of Electric Equipment Important to Safety for Nuclear Power Plants" requires licensees to identify electrical equipment covered under this regulation and to maintain a qualification file demonstrating that the equipment is qualified for its application and will perform its safety function up to the end of its qualified life. The EQ Program implements the requirements of 10 CFR 50.49 and will be used to manage the effects of aging on the intended functions of the components associated with EQ TLAAs for the period of extended operation.Review of Columbia EQ qualification information documents (QIDs) for electrical equipment concluded that the majority are TLAAs. There are 113 QIDs for equipment covered by 10 CFR 50.49. Of these, 100 are TLAAs because they meet all six of the criteria established in the TLAA definition of 10 CFR 54.3. The remaining 13 are not TLAAs because the subject equipment has a qualified life of less than 40 years.The EQ TLAAs were evaluated per 10 CFR 54.21(c)(1). Any required update of the QIDs will be performed in accordance with the EQ Program requirements and processes. Update of the QIDs is not a license renewal commitment. The license renewal commitment is that the EQ Program will be used to manage aging of EQ components. Ultimately any needed updates of the QIDs to extend qualified life prior to entering the period of extended operation will be driven by the EQ Program, using the same methodology as in the current license term to ensure components do not exceed-their qualified life. The updates may include re-analysis of the qualified life, refurbishment of the equipment, or replacement of the equipment. A re-analysis will beperformed in a timely manner (that is, with sufficient time available to refurbish, replace, or re-qualify the component if the re-analysis is unsuccessful). The EQ Component Re-analysis Attributes (from NUREG-1800, Table 4.4-1) are addressed below.EQ Component Re-analysis Attributes The re-analysis of an aging evaluation is normally performed to extend the qualification of the component by reducing excess conservatism incorporated in the previous evaluation. Re-analysis of an aging evaluation to extend the qualification of a component is performed on a routine basis pursuant to 10 CFR 50.49(e) as part of the Columbia EQ Program. A component's life-limiting condition may be due to thermal,radiation, or. cyclical aging; however, the majority of component aging limits are based on thermal conditions. Conservatism may exist in aging evaluation parameters, such as the assumed peak ambient temperature of the component, an unrealistically low activation energy, or in the specific application of a component (energized vs. de-energized). The re-analysis of an aging evaluation is documented according to Columbia quality assurance program requirements, which require the verification of assumptions and conclusions. As already noted, important attributes of a re-analysis Time-Limited Aging Analyses Page 4.4-1 January 2010',* *

• Columbia Generating Station License Renewal Application Technical Information

4.4 ENVIRONMENTAL

QUALIFICATION OF ELECTRICAL EQUIPMENT Environmental qualification (EQ) analyses for those components with a qualified life of. 40 years or greater are identified as TLAAs. NRC regulation 10 CFR 50.49 "Environmental Qualification of Electric Equipment Important to Safety for Nuclear Power Plants" requires licensees to identify electrical equipment covered under this regulation and to maintain a qualification file demonstrating that the equipment is qualified for its application and will perform its safety function up to the, end of its qualified life. The EQ Program implements the requirements of 10 CFR 50.49 and will be used to manage the effects of aging on the intended functions of the components, associated with EQ TLAAs for the period of extended operation. \ , Review of Columbia EQqualification information documents (QIDs) for electrical equipment concluded that the majority are TLAAs. There are 113 QIDs for equipment covered by 10 CFR 50.49. Of these, 100 are TLAAs because they meet all six of the criteria established in the TLAA definition of 10 CFR 54.3. The remaining 13 are not TLAAs because the subject equipment has a qualified life of less than 40 years. I ' The EQ TLAAs were E!valuated per 10 CFR 54.21 (c)(1). Any required update of the QIDs will be performed in accordance with the EQ Program requirements and processes. Update of the QIDs is not a ,license renewal commitment. The license renewal commitment is that the EQ Program will be used to manage aging of EQ components. Ultimately any needed updates of the QIDs to extend qualified life prior to entering the period of E!xtended operatior;1 will be driven by the EQ Program, using the same methodology as in the current license term to ensure components do not exceed* their qualified life. ,The updates may include re-analysis of the qualified life, refurbishment of the equipment, or replacement of the equipment. A re-analysis will be performed in a timely manner (that is, with sufficient time available to refurbish, replace, , or re-qualify the component if the re-analysis is unsuccessful). The EQ Component analysis Attributes (from NUREG-1800, Table 4.4-1) are addressed below. EQ Component Re-analysis Attributes The re-analysis of an aging evaluation is normally performed to extend the qualification of the component by reducing excess conservatism incorporated in the previous evaluation., Re-analysis of an aging evaluation to extend the qualification of a component is perform*!don a routine basis pursuant to 10 CFR 50.49(e) as part of the Columbia EQ Program. A component's life-limiting condition may be due to thermal, radiation, or cyclical aging; however, the majority of component aging limits are based on thermal conditions. Conservatism may exist in aging evaluation parameters, such as the assumed peak ambient temperature of the component, an unrealistically low activation energy, or in the specific application of a component (energized vs. .energized). The re-analysis of an aging evaluation is documented according to Columbia quality assurance program requirements, which require the verification of assumptions and conclusions. As already noted, important attributes of are-analysis Time-Limited Aging Analyses Page 4.4-1 January 2010', Columbia Generating Station License Renewal Application Technical Information include analytical methods, data collection and reduction methods, underlying assumptions, acceptance criteria, and corrective actions (if the acceptance criteria are not met). These attributes are discussed below.Analytical Methods The Columbia EQ Program uses the same analytical models in the re-analysis of'an aging evaluation as those applied during the previous qualification analysis. The Arrhenius methodology is an acceptable thermal model for performing a thermal aging evaluation. The analytical method used for a radiation aging evaluation is to demonstrate qualification for the total integrated dose (that is, normal radiation dose for the projected installed life plus accident radiation dose). For license renewal, one acceptable method of establishing the 60-year normal radiation dose is to multiply the 40-year normal radiation dose by 1.5 (that is, 60 years divided by 40 years). The result is added to the accident radiation dose to obtain the total integrated dose for the component. For cyclical aging, an approach similar to that used for radiation dose may be used. Other models may be justified on a case-by-case basis.Data Collection and Reduction Methods Reducing excess conservatism in the component service conditions (for example, temperature, radiation, cycles) used in the previous aging evaluation is a method used for a re-analysis in the Columbia EQ Program. Temperature data used in an aging evaluation should be conservative and based on plant design temperatures or on actual plant temperature data. When used, plant temperature data can be obtained in several ways, including monitors used for technical specification compliance, other installed monitors, measurements made by plant operators during rounds, and temperature sensors installed on large motors (while the motor is not running). A representative number of temperature measurements are evaluated to establish the temperatures used in an aging evaluation.- Plant temperature data may be used in an agingevaluation in different ways, such as: a) directly applying the'plant temperature data inthe evaluation, or b) using the plant temperature data to demonstrate conservatism when using plant design temperatures for an evaluation. Any changes to material activation energy values as part of a re-analysis must be justified. Similar methods of reducing excess conservatism in the component service conditions used in previous aging evaluations can be used for radiation and cyclical aging.Underlying Assumptions The Columbia EQ Program environmental qualification evaluations contain sufficient conservatism to account for most environmental changes occurring due to plant conditions and events. When unexpected adverse conditions are identified during operational or maintenance activities that affect the environment of a qualified component, the affected EQ component is evaluated, and appropriate corrective actions are taken, which may include changes to the qualification bases and conclusions.Time-Limited Aging Analyses Page 4.4-2 January 2010 Columbia Generating Station License Renewal Application

• Technical Information include analytical methods, data collection and reduction methods, underlying assumptions, acceptance criteria, and corrective actions (if the acceptance criteria are not met). These attributes are discussed below. Analytical Methods The .columbia EO Program uses the same analytical models in the re-analysis of' an aging evaluation as those applied during the previous qualification analysis.

The Arrhenius methodology is an acceptable thermal model for performing a thermal aging evaluation. The analytical method used for a radiation aging evaluation is to demonstrate qualification for the total. integrated dose (that is, normal radiation dose for the projected installed life plus accident radiation dose). For license renewal, one acceptable method of establishing the 60-year normal radiation dose is to multiply the 40-year normal radiation dose by 1.5 (that is, 60 years divided by40 years). The result is added to the accident radiation dose to obtain the total integrated dose for the component. For cyclical aging, an approach similar to that used for radiation dose may be used. Other models may be justified on a case-by-case basis. Data Collection and Reduction Methods Reducing excess conservatism in the component service conditions (for example, temperature, radiation, cycles) used in the previous aging evaluation is a method used

• for a re-analysis in the Columbia EO Program. Temperature data used in an aging , evaluation should be conservative and based on plant design temperatures or on actual plant temperature data. When used, plant temperature data can be obtained in several ways, including monitors used for technical specification compliancE( other installed monitors, measurements made by plant operators during rounds, and temperature sensors installed on large motors (while the motor is not running).

A representative number of temperature measurements are evaluated to establish the temperatures used in an aging evaluation.- Plant temperature data may be used in an aging evaluation in different ways, such as: a) directly applying the plant temperature data in the evaluation, or b) using the plant temperature data to demonstrate conservatism when using plant design temperatures for an evaluation. Any changes to material activation energy values as part of a re-analysis must be justified .. Similar)methods of reducing excess conservatism in the component service conditions used in previous aging evaluations can be used for radiation and cyClical aging. Underlying Assumptions The Columbia EO Program environmental qualification evaluations contain sufficient conservatism to account for most environmental changes occurring due to plant conditions and events. When unexpected adverse conditions are idE;mtified during operational or maintenance activities that affect the environment of a qualified component, the affected EO component is evaluated, and appropriate corrective actions are taken, which may include changes to the qualification bases and conclusions. Time-Limited Aging Analyses Page 4.4-2 January 2010

• Columbia Generating Station License Renewal Application Technical Information Acceptance Criteria and Corrective Actions Under the Columbia EQ Program, the re-analysis of an aging evaluation could extend the qualification of a component.

If the qualification cannot be extended by re-analysis,the component must be refurbished, replaced, or re-qualified prior to exceeding-the current qualified life. A re-analysis should be performed in a timely manner (such that sufficient time is available to refurbish, replace, or re-qualify the component if the re-analysis is unsuccessful). Therefore, the EQ TLAAs are dispositioned per 10 CFR 54.21(c)(1)(iii). The Columbia EQ Program is part of the current licensing basis, is in compliance with 10 CFR 50.49, and is the basis for managing the aging of EQ equipment in the current license term.In Section X.E1 of NUREG-1801, the NRC has already generically evaluated EQ programs put in place to meet 10 CFR 50.49 and found them acceptable for managing the aging of electrical EQ equipment during the period of extended operation. NUREG-1800, Section 4.4.2.1.3, states that if a licensee takes credit for this generic evaluation of the EQ Program, "...the applicant should indicate that the material referenced is applicable to the specific plant involved and should provide the information necessary to adopt the finding of program acceptability as described and evaluated in this report." To this end, a comparison of the EQ Program to the evaluation in NUREG-1801, Section X.E1 was performed with the results documented in Appendix B of this Application. From this review, it was concluded that the Columbia EQ Program contains the same program elements evaluated in NUREG-1801 and that the EQ Program is consistent with the generic evaluation performed by the NRC and documented in NUREG-1801. Continued effective implementation of the Columbia EQ Program assures that the aging effects will be adequately managed and that EQ components will continue to perform their intended functions for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(iii) -The effects of aging on the intended functions of the EQ components will be adequately managed for the period of extended operation by the EQ Program.Time-Limited Aging Analyses Page 4.4-3 January 2010* *

• Acceptance Criteria and Corrective Actions Columbia Generating Station License Renewal Application Technical Information Under the Columbia Eel Program" the re-analysis of an aging evaluation could extend the qualification of a component.

If the qualification cannot be extended by re-analysis, the component be refurbished, replaced, or re-qualified prior to exceeding the current qualified life. A re-analysis should be performed in a timely manner (such that sufficient time is available to refurbish, replace, or re-qualify the component if the analysis is unsuccessful). Therefore, the EO TLAAs are dispositioned per 10 CFR 54.21 (c)(1 )(iii). The Columbia EO Program is part of the current licensing basis, is in compliance with 10 CFR 50.49, and isthe basis for managing the aging of EO equipment in the current license term. In Section X.E1 of NUREG-1801, the NRC has already genericaliy evaluated EO programs put in place to meet 10 CFR 50.49 and found them acceptable

• for managing the aging of electrical EO equipment during the' period of extended operation.

NUREG-1800, Section 4.4.2.1.3, states that if a licensee takes credit for this generic evaluation of the EO Program, ": .. the applicant should indicate that the material referenced is applicable! to the specific plant involved and should provide the information necessary to adopt the finding of program acceptability as described and evaluated in this report." To this end, a comparison of the EO Program to the evaluation in NUREG-1801, Section X.E1 was performed with the results documented in Appendix B of this Application. From this review, it was concluded that the Columbia EO Program contains the same program elements evaluated in NUREG-1801 and that the EO Program is consistent with the generic evaluation performed by .the NRC and documented in NUREG-1801. Continued effective implementation of the Columbia ,EO Program assures that the aging effects will be adequately managed and that EO components will continue to perform their intended functions for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(iii) -The effects of aging on the intended functions of the EQ components will be adequately managed ,for the period of extended operation by the EQ Program. , . Time-Limited Aging Analyses Page 4.4-3 January 2010 Columbia Generating StationLicense Renewal Application Technical Information [This. page intentionally blank]Time-Limited Aging Analyses Page 4.4-4 January 2010 Time-Limited Aging Analyses Page 4.4-4 January 2010[This page intentionally blank] Time-Limited Aging Analyses Page 4.4-4 Columbia Generating Station License Renewal Application, Technical Information January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information

4.5 CONCRETE

CONTAINMENT TENDON PRESTRESS Section 4.5 of NUREG-1800 addresses the issue of TLAAs associated with concrete containment tendon prestress. Columbia has a Mark II primary containment, and this structure does not contain pre-stressed tendons. Therefore, evaluations for tendon prestress are not applicable to Columbia.Disposition: TLAAs for tendon prestress are not applicable to Columbia.Time-Limited Aging Analyses Page 4.5-1 January 2010 Time-Limited Aging Analyses Page 4.5-1 January 2010* * * / 4.5 CONCRETE CONTAINMENT TENDON PRESTRESS Columbia Generating Station License Renewal Application Technical Information Section 4.5 of NUREG**1800 addresses the issue of TLAAs associated with concrete containment tendon prestress. Columbia has a Mark " primary containment, and this . structure does not contain pre-stressed tendons. Therefore, evaluations for tendon prestress are not applicable to Columbia. Disposition: TLAAs for tendon prestress are not applicable to Columbia . Time-Limited Aging Page 4.5-1 January 2010 Columbia Generating Station License Renewal Application Technical Information [This page intentionally blank] Time-Limited Aging Analyses Page 4.5-2 January 2010 Columbia Generating Station License Renewal Application

• Technical Information

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• Time-Limited Aging Analyses Page 4.5-2 January 2010 Columbia Generating Station License Renewal Application Technical Information

4.6 CONTAINMENT

LINER PLATE, METAL CONTAINMENTS, AND PENETRATIONS FATIGUE ANALYSES The Columbia Primary Containment utilizes a GE Mark II over-under pressure-, suppression configuration. The drywell and suppression chamber (or wetwell) are large sealed'volumes designed to contain and condense escaping reactor coolant. Both contain structures and piping systems with the suppression chamber approximately half filled with water (suppression pool) for steam quenching. The drywell is connected to the suppression pool by 99 downcomer pipes (3 of the 102 original pipes have been capped) that channel steam released during a LOCA for quenching and pressure suppression. (see FSAR Section 3A.3.2.1)Codes and standards for the containment structure are given in FSAR Section 3.8.2.2 and FSAR Table 3.8-4. The cycles used in the fatigue evaluation of the containment components is given in FSAR Table 3A.4.1-3, which is reproduced below.No operating basis earthquake has occurred through 2007, and thus are projected to remain within the 5 analyzed events through 60 years. The safe shutdown earthquake and post-LOCA chugging are once in a lifetime events and thus will not exceed the one analyzed event through 60 years of operation. A review of plant data indicates that no more than 636 SRV cycles have occurredthrough 2007. This conservatively projects to 2,400 cycles through 60 years of operation, and remains well below the 13,434 cycles that have been analyzed. The fatigue analyses performed using these cycles will remain valid for the period of extended operation, as indicated by the table below.FSAR Table 3A.4.1-3 Equivalent Stress Cycles for Fatigue Evaluation i Number of Number of Equivalent Total Number of Load Events Stress Cycles per Event Stress Cycles Operating basis earthquake 5 10 50 Safe shutdown earthquake 1 10 10 SRV a 4,478 3 13,434 Chugging 1 1,000 1,000 a This includes the cycles due to building motion, direct pressure, and fluid transients during SRV actuations. Time-Limited Aging Analyses Page 4.6-1 January 2010*

• Columbia Generating Station License Renewal Application Technical Information , > 4.6 CONTAINMENT LINER PLATE, > METAL . > CONTAINMENTS, AND PENETRATIONS FATIGUE ANALYSES The Columbia Primary Containment utilizes a GE Mark II over-under pressure-'" suppression configuration.

The drywell and suppression chamber (or wetwell) a're large sealed'volumes designed to contain and condense escaping reactor coolant. Both contain structures and piping systems with the suppression chamber approximately half filled with water (suppression pool) for steam quenching. The drywell is connected to the suppression pool by 99 downcomer pipes (3 of the 102 original pipes have been capped) that channel steam released during a LOCA for quenching and pressure suppression. (see FSAR Section 3A.3.2.1) Codes and standards for the containment structure are' given in FSAR Section 3.8.2.2 and FSAR Table 3.8-4. The cycles used in the fatigue evaluation of the containment components is given in FSAR Table 3A.4.1-3, which is reproduced below. No operating basis earthquake has occurred through 2007, and thus are projected to remain within the 5 analyzed events through 60 years. The safe shutdown earthquake and post-LOCA chugging are once in a lifetime events and thus will not exceed the one analyzed event through 60 years of operation . A review of plant data indicates that no more than 636 SRV cycles have occurred through ,2007. This conservatively projects to 2,400 cycles through 60 years of operation, and remains well below the 13,434 cycles that have been analyzed. The fatigue analyses performed using these cycles will remain valid for the period of extended operation, as indicated by the table below. FSAR Table 3A.4.1-3 Equilvalent Stress Cycles for Fatigue Evaluation Number of Number of Equivalent Total Number of Load Events Stress Cycles per Event Stress Cycles Operating basis earthquake 5 10 50 Safe shutdown earthquake 1 10 10 SRV a 4,478 3 13,434 Chugging 1 1,000 1,000 a This includes the cycles due to building motion, direct pressure, and fluid transients during SRV actuations . Time-Limited Aging Analyses Page 4.6-1 January 2010 Columbia Generating Station License Renewal Application Technical Information As the cycles on which the containment fatigue analysis is based will not be exceeded for 60 years of operation, the analyses .discussed in the following sections will remain valid for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(i) - The TLAAs associated with fatigue of the containment remain valid for the period of extended operation. 4.6.1 ASME Class MC Components Class MC components include the primary containment vessel shell, large openings (equipment hatch, personnel hatches, and access hatch), penetrations (all except the large openings), and attachments (pipe supports in the wetwell, welding pads in the drywell, supports for the stabilizer truss, seal and shear lugs at the drywell floor, supports for the downcomer bracing system, pipe whip supports, radial beam supports, cap truss supports, catwalks, monorail, and platforms). The Class MC components were analyzed for fatigue using the transients listed in FSAR Table 3A.4.1-3, reproduced in Section 4.6 above. As these cycles will not be exceeded for 60 years of operation, the Class MC component fatigue analysis will remain valid for the period of extended operation. A specific fatigue analysis was performed for the main steam penetrations. Main steam penetrations were analyzed using the transients listed in FSAR Table 3A.4.1-3, reproduced in Section 4.6 above. The maximum revised CUF was 0.174. As this CUF was calculated based on the cycles identified above, this analysis will remain valid for the period of extended operation. In May 1995, the NRC staff granted Columbia an amendment to the operating license to allow an increase in the power level of the plant (Reference 4.8-13). For short-term containment pressure response, the peak pressure values are below design values and remain virtually unaffected by power uprate and extended load line limit. The loss-of-coolant accident (LOCA) containment dynamic loads are not affected by power uprate, and SRV containment loads will remain below their design allowables. (see FSAR Appendix 3A)All events project to remain below the. containment cyclic basis from FSAR Table 3A.4.1-3 for 60 years of operation as discussed in Section 4.6 above. Consequently, the analysis of the Class MC containment components remains valid for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(i) - The TLAAs for fatigue of the ASME Class MC components remain valid through the end of the period of extended operation.Time-Limited Aging Analyses Page 4.6-2 January 2010 Columbia Generating Station License Renewal Application

• Technical Information As the cycles on which the containment fatigue analysis is based will not be exceeded for 60 years of operation, the analyses discussed in the following sections will remain valid for the period of extended operation.

Disposition: 10 CFR 54.21(c)(1)(i) -The TLAAs associated with fatigue of the containment remain valid for the period of extended operation. 4.6.1 ASME Class MC Components Class MC components include the primary containment vessel shell, large openings (equipment hatch, personnel hatches, and access hatch), penetrations (all except the large openings), and attachments (pipe supports in the wetwell, welding pads in the drywell, supports for the stabilizer truss, seal and shear lugs at the drywell floor, supports for the downcomer bracing system, pipe whip supports, radial beam supports, cap truss supports, catwalks, monorail, and platforms). The Class MC components were analyzed for fatigue using the transients listed in FSAR Table 3A.4.1-3, reproduced in Section 4.6 above. As these will not be exceeded for 60 years of operation, the Class MC component fatigue analysis will remain valid for the period of extended operation. A specific fatigue analysis was performed for the main steam penetrations. Main steam penetrations were analyzed using the transients listed in FSAR Table 3A.4.1-3, reproduced in Section 4.6 above. The maximum revised CUF was 0.174. As this CUF was calculated based on the cycles identified above, this analysis will remain valid for the period of extended operation. In May 1995, the NRC staff granted Columbia an amendment to the operating license to allow an increase in the power level of the plant (Reference 4.8-13). For short-term containment pressure response, the peak pressure values are below design values and remain virtually unaffected by power uprate and extended load line limit. The coolant accident (LOCA) containment dynamic loads are not affected by power uprate, and SRV containment loads will remain below their design allowables. (see FSAR Appendix 3A) All events project to remain below the, containment cyclic basis from FSAR Table 3A.4.1-3 for 60 years of operation as discussed in Section 4,6 above. Consequently, the analysis of the Class MC containment components remains valid for the period of extended operation. Disposition: 10 CFR 54.21 (c)(1)(i) -The TLAAs for fatigue of the ASME Class MC components remain valid through the end of the period of extended operation. Time-Limited Aging Analyses Page 4.6-2 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information

4.6.2 Downcomers

There are 84 24-inch diameter downcomers and 18 28-inch downcomers. Three of the downcomers are capped (see FSAR Section 6.2.1.1.3.2). The downcomer vent pipes are designed to contain and direct uncondensed drywell steam into the suppression pool following a pipe break accident. The upper portion of the downcomers are designed and constructed in accordance with ASME Section III Class 2 requirements while the lower portion are designed and constructed to ASME Section III Class 3 requirements. The only effect of this code break is to eliminate radiography requirements for the circumferential weld joining the upper and lower portions of the downcomers (see FSAR Section 3.8.3.4.9). A fatigue evaluation of the downcomers was performed even though it is not an ASMECode requirement. The fatigue evaluation of the downcomer lines in the wetwell air volume was based on the number of cycles as presented in FSAR Table 3A.4.1-3 (reproduced in Section 4.6 above). The maximum fatigue usage factor for the 24-inch downcomers is 0.0346 and the maximum usage factor for the 28-inch downcomers is 0.0629. (see FSAR Table 3A.4.2-4 and Table 3A.4.2-5)All events project to remain below the containment cyclic basis from FSAR Table 3A.4.1-3 for 60 years of operation as discussed in Section 4.6 above. Consequently, the analysis of the downcomers remains valid for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(i) -The TLAA for fatigue of the downcomers remains valid through the end of the period of extended operation. Time-Limited Aging Analyses Page 4.6-3 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Downcomers There are 84 24-inch diameter downcomers and 18 28-inch downcomers.

Three of the downcomers are capped (see FSAR Section 6;2.1.1.3.2). The downcomer vent pipes are designed to contain and direct uncondensed drywell steam into the suppression pool following a pipe break accident. The upper portion of the downcomers are designed and constructed in accordance with ASME Section III Class 2 requirements while the lower portion are designed and constructed to ASME Section III Class 3 requirements. The only effect of this code break is to eliminate radiography requirements for the circumferential weld joining the upper and lower portions of the downcomers (see FSAR Section 3.8.3.4.9). A fatigue evaluation of the downcomers was performed even though it is not an ASME Code requirement. The fatigue evaluation of the downcomer lines in the wetwell air volume was based on the number of cycles as presented in FSAR Table 3A.4.1-3 (reproduced in Section 4.6 above). The maximum fatigue usage factor for the 24-inch downcomers is 0.0346 and the maximum usage factor for the 28-inch downcomers is 0.0629. (see FSAR Table 3A.4.2-4 and Table 3A.4.2-5) All events project to remain below the containment cyclic basis from FSAR Table 3A.4.1-3 for 60 years of operation as discussed in Section 4.6 above. Consequently, the analysis of the downcomers remains valid for the period of extended operation. Disposition: 10 CFR 54.21 (c)(1 )(i) -The TLAA for fatigue of the downcomers* remains valid through the end of the period of extended operation . Time-Limited Aging Analyses Page 4.6-3 January 2010 Columbia Generating Station License Renewal Application Technical Information

4.6.3 Safety

Relief Valve Discharge Piping Each of the 18 SRVs on the main steam lines in the drywell chamber have a discharge line into the wetwell that terminates in a quencher in the suppression pool. To pass through the drywell floor, the discharge lines are routed through downcomers. (see FSAR Section 3A.3.1.1)A fatigue evaluation of the SRV discharge piping was performed even though it is not an ASME Code requirement. The fatigue evaluation used the number of cycles as presented in FSAR Table 3A.4.1-3, reproduced in Section 4.6 above. The maximum fatigue usage factor for all 18 SRV discharge lines in the wetwell air volume was found to be 0.896, below ASME allowable limits of 1.0 (see FSAR Section 3A.4.2.4.6). All events project to remain below the containment cyclic basis from FSAR Table 3A.4.1-3 for 60 years of operation as discussed in Section 4.6 above. Consequently,the analysis of the SRV discharge piping remains valid for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(i) -The TLAA for fatigue of the SRV discharge piping remains valid through the end of the period of extended operation.

4.6.4 Diaphragm

Floor Seal The diaphragm floor seal is located at the inside surface of the primary containment vessel periphery. It provides a flexible, pressure tight seal between the primary containment vessel and the diaphragm floor and is capable of accommodating differential thermal expansion between them.The fatigue evaluation was performed using the cycles in Section 4.6 above. The maximum CUF is 0.7 per FSAR Table 3A.4.1-5. All events project to remain below the containment cyclic basis from FSAR Table 3A.4.1-3 for 60 years of operation as discussed in Section 4.6 above. Consequently, the analysis of the diaphragm floor seal remains valid for the period of extended operation. Disposition: 10 CFR 54.21 (c)(1)(i) -The TLAA for fatigue of the diaphragm floor seal remains valid through the end of the period of extended operation. Time-Limited Aging Analyses Page 4.6-4 January 2010 Time-Limited Aging Analyses Page 4.6-4 January 2010 Columbia Generating Station License Renewal Application Technical Information

4.6.3 Safety

Relief Valve Discharge Piping Each of the 18 SRVs on the main steam lines in the drywell chamber have a discharge line into the wetwell that terminates in a quencher in the suppression pool. To pass through the drywell floor, the discharge lines are routed through downcomers. (see* FSAR Section 3A.3.1.1) . A fatigue evaluation of the SRV discharge piping was performed even though it is not an ASME Code requirement. The fatigue evaluation used the number of cycles as presented in FSAR Table 3A.4.1-3, reproduced in Section 4.6 above. The maximum* fatigue usage factor for all 18 SRV discharge lines in the wetwell air volume was found to be 0.896, below ASME allowable limits of 1.0 (see FSAR Section 3A.4.2.4.6). All events project to remain below the containment cyclic basis from FSAR Table 3A.4.1-3 for 60 years of operation as discussed in Section 4.6 above. Consequently, the analysis of the SRV discharge piping remains valid for the period of extended operation. Disposition: 10 CFR 54.21 (c)(1)(i) -The TLAA for fatigue of the SRV discharge piping remains valid through the end of the period of extended operation.

4.6.4 Diaphragm

Floor Seal The diaphragm floor seal is located at the inside surface of the primary containment vessel periphery. It provides a flexible, pressure tight seal between the* primary containment vessel and the diaphragm floor and is capable of accommodating differential thermal expansion between them. The fatigue evaluation was performed using the cycles in Section 4.6 above. The maximum CUF is 0.7 per FSAR Table 3A.4.1-5. All events project to remain below the containment cyclic basis from FSAR Table 3A.4.1-3 for 60 years of operation as discussed in Section 4.6 above. Consequently, the analysis of the diaphragm floor seal remains valid for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(i) -The TLAA for fatigue of the diaphragm floor seal remains valid through the end of the period of extended operation. Time-Limited Aging Analyses Page 4.6-4 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information 4.6.5 ECCS Suction Strainers The original Columbia ECCS suction strainers were replaced with a new strainer design constructed from cold-worked austenitic stainless steel. A linear elastic fracture mechanics analysis was performed to bound all the martensitic material in the suction strainer screens. A crack depth was assumed based on the depth of the Alpha Prime martensite in the strainer screen material.Cyclic stresses were included in the crack growth analysis of the suction strainers.

The fatigue crack evaluation determined that the assumed cracks will not propagate to a critical size for the remaining life of the plant. The maximum computed stress intensity value (K) was less than that required to cause cracking in Alpha martensite formed in austenitic stainless steel.The stress value included direct pressure and inertial components from SRV actuation, OBE loads, and SRV steam chugging. (see FSAR Table 3A.4.1-3 as reproduced in Section 4.6 above.)All events are projected to remain below the containment cyclic basis from FSAR Table 3A.4.1-3 for 60 years of operation as discussed in Section 4.6 above. Consequently, the analysis of the ECCS suction strainers remains valid for the period of extended operation. Disposition: 10 CFR54.21(c)(1)(i) -The TLAA for crack growth of the ECCS suction strainers remains valid through the end of the period of extended operation.Time-Limited Aging Analyses Page 4.6-5 January 2010* . \ *

• 4.6.5 ECCS Suction Strainers Columbia Generating Station* License Renewal Application Technical Information The original Columbia ECCS suction strainers were replaced with a new strainer design constructed from cold-worked austenitic stainless steel. A linear elastic fracture . mechanics analysis was performed to bound all the martensitic material in the suction strainer screens. A crack depth was assumed based on the depth of the Alpha Prime martensite in the strainer screen material.

Cyclic stresses were included in the crack growth analysis of the suction strainers. The . fatigue crack evaluation determined that the assumed cracks will not propagate to a critical size for the remaining life of the plant. The maximum computed stress intensity value (K) was less than that required to cause cracking in Alpha martensite formed in austenitic stainless steel. The stress value included direct pressure and inertial components from SRV actuation, aBE loads, and SRV steam chugging. (see FSAR Table 3A.4.1-3 as reproduced in Section 4.6 above.) All events are projected to remain below the containment cyclic basis from FSAR Table 3A.4.1-3 for 60 years of operation as discussed in Section 4.6 above. Consequently, the analysis of the ECCS suction strainers remains valid for the period of extended operation. Disposition: 10 CFR 54.21 (c)(1)(i) -The TLAA for crack growth of the ECCS suction strainers remains valid through the end of the period of extended operation . Time-Limited Aging Page 4.6-5 January 2010 Columbia Generating Station License Renewal Application Technical Information [This page intentionally blank] Time-Limited Aging Analyses Page 4.6-6 January 2010 Time-Limited Aging Analyses Page 4.6-6 January 2010[This page intentionally blank] Time-Limited Aging Analyses Page 4.6-6 Columbia Generating Station License Renewal Application Technical Information / 2010 * *

• Columbia Generating Station License Renewal Application Technical Information

4.7 OTHER

PLANT-SPECIFIC TIME-LIMITED AGING ANALYSES 4.7.1 Reactor Vessel Shell Indications Two indications in the reactor vessel shell were identified using ultrasonic testing methods during the 2005 inservice inspections. The indications were 'present in past inservice inspection examinations, but became rejectable under current ASME Section XI, IWB-3610 requirements. The rejected indications were evaluated and determined to be acceptable for continued service without repair, as reported to the NRC in Energy Northwest letter G02-05-153 (Reference 4.8-14)._ The indications were evaluated per the guidelines of ASME Section XI, IWB-3610, which include acceptance criteria based on the applied stress intensity factors, using conservative assumptions in the applied stresses to determine the stress intensity factors for comparison to Code allowables. This evaluation calculated a fatigue crack growth (0.0064 inches) at the end of 33.1 EFPY vessel service life) that is insignificant in comparison to the bounding initial crack size-of 0.39 inch. It also determined that the applied stress intensity factor (about 30 ksi*in) is well below the allowable Kic of 63.25 ksilin.The calculation used two time-limited assumptions based on the 1 40-year life of the plant, and thus is a TLAA.1. The /4 T neutron fluence at weld BG (5.11E+17 n/cm 2 at 33.1 EFPY) was used for both welds. This fluence was used to calculate the material properties of the cracked area, and hence the crack propagation. As can be seen from Table 4.2-1, the projected .1/4 T fluence for Weld BG at 54 EFPY is 8.1 0E+1 7 n/cm 2.2. 500 significant thermal transients were assumed (SRV blowdown cycles being the worst case thermal cycle). From Table 4.3-2, it can be seen that no SRV blowdown cycles are expected through 60 years of operation; furthermore, only 409 significant thermal transients are expected (233 heatup/cooldowns, 166-scrams, and 10 HPCS actuations). Although this calculation easily meets the. acceptance criteria, it is based on a time-limited assumption of neutron fluence that will not remain valid for the period of extended operation. This indication is currently scheduled for re-inspection in 2015.Columbia will re-evaluate the indication based on the results of the 2015 inspection and either project this analysis through the period of extended operation or continue augmented inspections as required by the ASME code. As such, Columbia will manage the aging of the reactor vessel shell indications using the Inservice Inspection (ISI)Program for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(iii) -Cracking of the reactor vessel shell near welds BG and BM will be adequately managed through the period of extended operation by the Inservice Inspection (ISI) Program.Time-Limited Aging Analyses Page 4.7-1 January 2010* * ( e_ 4.7 Columbia Generating Station License Renewal Application Technical Information OTHER PLANT*SPECIFIC TIME-LIMITED AGING ANALYSES 4.7.1 Reactor Vessel Shell Indications Two indications in the reactor vessel shell were identified using ultrasonic testing methods'during the 2005 'inservice inspections. The indications were 'present in pa'st inservice inspection examinations, but became rejectable under current ASME Section XI, IWB-3610 requirem*!nts. The rejected indications were evaluated and determined to be acceptable for continued service without repair, as reported to the NRC in Energy Northwest letter G02-05,-153 (Reference 4.8-14) .. The indications were evaluated per the guidelines of ASME Section XI, IWB-36,10, which include acceptance criteria based on the applied stress intensity factors, using conservative ass,umptions in the applied stresses to determine the stress intensity factors for comparison to Code allowables. This evaluation calculated a fatigue crack growth (0.0064 inches) at the end of 33.1 EFPY vessel service ,Iifl3 that is insignificant in comparison to the bounding initial crack size of 0.39 inch. It also determined .that the applied stress intensity factor (about 30 ksi..Jin) is well below the allowable K 1c of 63.25 ksi..Jin. The calculation used two time-limited assumptions based on the ,40-year life of the plant, and thus is a TLAA. ' 1. The T neutron fluence at weld BG (5.11 E+17 n/cm 2 at 33.1 EFPY) was used for both welds. This fluence was used to calculate the material(properties of the cracked area,and hence the crack propagation. As can be seen from Table 4.2-1, the T'fluence for Weld BG at54 EFPY is 8.10E+17 n/cm 2* . . 2. 500 significant thermal transients were assumed (SRV blowdown cycles being the worst case thermal cycle). From Table 4.3-2, it can be seen that no SRV blowdown cycles are expected through 60 years of operation; furthermore, only 409 significant thermal transients are expected (233 heatup/cooldowns, 166 scrams, and 10 HPCS actuations). Although this calculation easily meets the acceptance criteria, it is based on a time-' limited assumption of neutron fluence that will not remain valid for the period of extended operation. This indication is currently scheduled for re-inspection in Columbia will re-evaluate the indication based on the results of the 2015 inspection and either project this 'analysis through the period of extended operation or continue augmented inspections as required by the ASME code. As such, Columbia will manage the aging of the reactor vessel shell indications using the Inservice Inspection (lSI) Program for the period of extended operation. Disp'osition: 10 CFR 54.21(c)(1)(iii)

• Cracking of the reactor vessel shell near welds BG and BM will be adequately managed through the period of extended operation by the Inservice Inspection (151) Program. Time-Limited Aging Analyses . Page 4.7-1 January 2010 Columbia Generating StationLicense Renewal Application Technical Information

4.7.2 Sacrificial

Shield Wall.The sacrificial shield wall (SSW) is discussed in FSAR Section 3.8.3.6, which states "it has been determined that in the 40-year life expectancy of the station, the outside face of the SSW will experience a neutron fluence of less than 2 x 1016 nvt." (For the discussion in this section, nvt is equivalent to n/cm 2 with neutron energy greater than 1 MeV).Projected fluence at the SSW outer wall for 60 years of operation, including an increase in the neutron flux at the SSW of 5.28 percent due to power uprate, remains below 2 x 1016 nvt. As the estimated neutron fluence on the sacrificial shield wall is projected to remain below the FSAR value for 60 years, this TLAA has been projected through the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(ii) -The TLAA associated with the sacrificial shield wall fluence has been projected to the end of the period ofextended operation. Time-Limited Aging Analyses Page 4i7-2 January 2010 Time-Limited Aging Analyses Page 4.7-2 January 2010 Columbia Generating Station

• License Renewal Application Technical Information

4.7.2 Sacrificial

Shield Wall \ The sacrificial shield wall (SSW) is discussed in FSAR Secti.on 3.8.3.6, which states "It has been determined that in the 40-year life expectancy of the station, the outside face of the SSW will experience a neutron fluence of less than 2 x 10 16 nvt." (For the discussion in this section, nvt is equivalent tQ n/cm 2 with neutron energy greater than 1 MeV). I Projected fluence at the SSW outer wall for 60 years of operation, including an increase in the neutron flux at the SSW of 5.28 percent due to power uprate, remains below 2 x 10 16 nvt. As the estimated neutron fluence on the sacrificial shield wall is projected to remain below the FSAR value for 60 years, 'this TLAA has been projected through the period of extended operation, Disposition: 10 CFR 54.21(c)(1)(ii) -The TLAA associated with the sacrificial shield wall fluence ,",as been projected to the end of the period of extended operation. / Time-Limited Aging Analyses Page 4.7-2 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information 4.7.3 Main Steam Line Flow Restrictor Erosion Analyses FSAR Section 5.4.4 indicates that a main steam line flow restrictor is provided for each of the four main steam lines. The restrictor is a complete assembly welded into the main steam line between the last main steam line SRV and the inboard main steam isolation valve (MSIV). The restrictor is designed to limit coolant flow rate from the reactor vessel (before the MSIVs are closed) to less than 200 percent of normal flow in the event a main steam line break occurs outside the containment.

The restrictor assembly has no moving parts and consists of a venturi-type nozzle insert welded-into the main steam line.FSAR Section 5.4.4.4 indicates that only very slow erosion of the main steam flow restrictor is expected. Erosion of a flow restrictor is a safety concern since it could impair the ability of the flow restrictor to limit vessel blowdown following a main steam line break. Since erosion is a time-related phenomenon, the analysis for the effect it has on the flow restrictors over the life of the plant is a TLAA. Cast stainless steel (SA351, Type CF8) was selected for the steam flow restrictor material because it has excellent resistance to erosion-corrosion from high velocity steam.Columbia has projected the erosion of the main steam flow restrictors for the period of extended operation. The projection concludes that after 60 years of erosion on the main steam flow restrictors, the choked flow will still be less than 200 percent of normal flow. Therefore, the main steam flow restrictors will continue to perform their intended function for the period of extended operation. Disposition: 10 CFR 54.21(c)(1)(ii) - The TLAA for erosion of the main steam line flow restrictors has been projected to the end of the period ofextended operation. Time-Limited Aging Analyses Page 4.7-3 January 2010 Time-Limited Aging Analyses Page 4.7-3 January 2010,* *

• 4.7.3 Main Steam Line Flow Restrictor Erosion Analyses Columbia Generating Station' License Renewal Application Technical Information FSAR Section 5.4.4 indicates that a main steam line flow restrictor is provided for each of the four main steam lines. The restrictor is a complete assembly welded into the main steam line between the last main steam line SRV and the inboard main steam isolation valve (MSIV). The restrictor is designed to limit coolant flow rate from the reactor vessel (before the MSIVs are closed) to less than 200 percent of normal flow in the event a main steam line break occurs outside the containment.

The restrictor assembly has no moving parts and consists of a venturi-type nozzle insert welded-into the main steam line. .. FSAR Section 5.4.4.4 indicates that only very slow erosion of the main steam flow restrictor is expected. Erosion of a flow restrictor is a safety concern since it could impair the ability of the flow restrictor to limit vessel blowdown following a main steam line break. Since erosion is a time-related phenomenon, the analysis for the effect it has on the flow restrictors over the life of the plant isa TLAA. Cast stainless steel (SA351, Type CF8) was selected for tt'le steam flow restrictor material because it has excellent resistance to erosion-corrosion from high velocity steam. Columbia has projected the erosion of the main steam flow restrictors for the period of extended operation. The prOjection concludes that after 60 years of erosion on the main steam flow restrictors, the choked flow will still be less than 200 percent of normal flow. Therefore, the main steam flow restrictors will continue to perform their intended . function for the period of extended operation. Disposition: 10 CFR 54.21 (c)(1)(ii)

• The TLAA for erosion of the main steam line flow restrictors has been projected to the end of the period of extended operation.

/ Time-Limited Aging Analyses Page 4.7-3 January 2010 Columbia Generating Station License Renewal Application Technical Information [This page intentionally blank]Time-Limited Aging Analyses Page 4.7-4 January 2010 Columbia Generating Station License Renewal Application

• Technical Information

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• Time-Limited Aging Analyses Page 4.7-4 January 2010 Columbia Generating Station License Renewal Application Technical Information

4.8 REFERENCES

4.8-1 G02-04-107, Energy Northwest Letter to USNRC Document Control Desk,"License Amendment Request to Revise Technical Specification 3.4.11 Reactor Coolant System (RCS) Pressure and Temperature (P/T) Limits," June 9, 2004 (includes excerpts from NEDO-33144). 4.8-2 G12-05-076, NRC to J.V. Parrish (Energy Northwest), "Columbia Generating Station -Issuance of Amendment RE: Reactor Coolant System (RCS)Pressure and Temperature Limits," May 12, 2005 (includes SER).4.8-3 General Electric Report GE-NE-0000-0023-5057-RO, "Energy Northwest Columbia Generating Station Neutron Flux Evaluation," April 2004 (GE Proprietary Information). 4.8-4 NRC letter, S. A. Richard, USNRC, to J. F. Klaproth, GE-NE, "Safety Evaluation for NEDC-32983P., General Electric Methodology for Reactor Pressure Vessel Fast Neutron Flux Evaluation (TAC No. MA9891)", MFN 01-050, September 14, 2001.4.8-5 General Electric Report NEDO-33144, "Pressure-Temperature Curves for Energy Northwest Columbia," April 2004 (Non-proprietary version of NEDO-33144P).4.8-6 NRC Regulatory Guide 1.99, Radiation Embrittlement of Reactor VesselMaterials, Revision 2.4.8-7 BWRVIP-74-A: "BWR Vessel and Internals Project, BWR Reactor Pressure Vessel Inspection and Flaw Evaluation Guidelines for License Renewal," EPRI, Palo Alto, CA: 2003. 1008872. (EPRI Proprietary). 4.8-8 BWRVIP-05: "BWR Vessel and Internals Project, BWR Reactor Pressure Vessel Shell Weld Inspection Recommendations," EPRI, Palo Alto, CA. 1995.105697. (EPRI Proprietary). 4.8-9 G12-05-090, NRC to J.V. Parrish (Energy Northwest), "Safety Evaluation for Columbia Generating Station -Relief Request for Alternatives to Volumetric Examination of Reactor Pressure Vessel Circumferential Shell Welds in Accordance with BWRVIP-05 (TAC No. MC3916)," June 1, 2005.4.8-10 NUREG/CR-6260, "Application of NUREG/CR-5999 Interim Fatigue Curves to Selected Nuclear Power Plant Components," March 1995.4.8-11 NUREG/CR-6583, "Effects of LWR Coolant Environments on Fatigue Design Curves of Carbon and Low-Alloy Steels," March 1998.4.8-12 NUREG/CR-5704, "Effects of LW Coolant Environments on Fatigue Design Curves of Austenitic Stainless Steels," April 1999.4.8-13 G12-95-099, J. W. Clifford (NRC) to J. V. Parrish, "Issuance of Amendment for the Washington Public Power Supply System Nuclear Project No. w (TAC Nos. M87076 and M88625)," May 2, 1995.Time-Limited Aging Analyses Page 4.8-1 January 2010* /

• 4.8 4.8-1 4.8-2 4.8-3 4.8-4 4.8-5 REFERENCES Columbia Generating Station License Renewal Application Technical Information . G02-04-107, Energy Northwest Letter to USNRC Document Control Desk, "License Amendment Request to Revise Technical Specification 3.4.11 Reactor Coolant System (RCS) Pressure and Temperature (PIT) Limits," June 9, 2004 (includes excerpts from NEDO-33144).

GI2-05-076, NRC toJ.V. Parrish (Energy Northwest), "Columbia Generating Station -Issuance of Amendment RE: Reactor Coolant System (RCS) Pressure an.d Temperature Limits," May 12, 2005 (includes SER). General Electric Report GE-NE-0000-0023-5057-RO, "Energy Northwest Columbia Generating Station Neutron Flux Evaluation," April 2004 (GE Proprietary Information). . NRC letter, S. A. Richard, USNRC, to J. F. Klaproth, GE-NE,"Safety Evaluation for NEDC-32983P., General Electric Methodologyfor Reactor Pressure Vessel Fast Neutron Flux Evaluation (TAC No. MA9891)"., MFN 01-050, September 14, 2001. General Electric Report NEDO-33144, "Pressure-Temperature Curves for Energy Northwest Columbia," April 2004 (Non-proprietary version of NEDO-33144P). 4.8-6 NRC Regulatory Guide 1.99, Radiation Embrittlement of Reactor Vessel Materials, Revision 2. 4.8-7 BWRVIP-74-A: "BWR Vessel and Internals Project, BWR Reactor Pressure Vessel Inspection and Flaw Evaluation Guidelines for License Renewal," EPRI, Palo Alto, CA: 2003. 1008872. (EPRI Proprietary). 4.8-8 BWRVIP-05: "BWR Vessel and Internals Project, BWR Reactor Pressure Vessel Shell Weld Inspection Recommendations," EPRI, Palo Alto, CA. 1995. 105697. (EPRI Proprietary). 4.8-9 GI2-05-090, NRC to JV. Parrish (Energy Northwest), "Safety Evaluation for Columbia Generating Station -Relief Request for Alternatives to Volumetric Examination of Reactor Pressure Vessel Circumferential Shell We.lds in Accordance with BWRVIP-05 (TAC No. MC3916)," June 1, 2005. 4.8-10 NUREG/CR-6260, "Application of NUREG/CR-5999 Interim Fatigue Curves to Selected Nuclear Power Plant Components," March 1995. 4.8-11 NUREG/CR-6583, "Effects of LWR Coolant Environments on Fatigue Design Curves of Calrbon and Low-Alloy Steels," March 1998. 4.8-12 NUREG/CR-5704, "Effects of LW Coolant Environmentson Fatigue Design CurVes of Austenitic Stainless Steels," April 1999. . 4.8-13 GI2-95-099, J. W. Clifford (NRC).to J. V. Parrish, "Issuance of Amendment for the Washington Public Power Supply System Nuclear Project No. w (TAC Nos. M8707*5 and M88625)," May 2, 1995 . Time-Limited Aging Analyses Page 4.8-1. January 2010 Columbia Generating StationLicense Renewal Application Technical Information 4.8-14 G02-05-153, W Oxenford (Energy Northwest) Letter to NRC Document Control Desk, "Columbia Generating Station, Docket No. 50-397 Analytical Evaluation of Inservice Inspection Examination Results," September 15, 2005.4.8-15 NRC letter, Gus C. Lainas to Carl Terry, BWRVIP Chairman, "Final Safety Evaluation of the BWR Vessel and Internals Project BWRVIP-05 Report (TAC No. M93925)," July 28, 1998.Time-Limited Aging Analyses Page 4.8-2 January 2010 Columbia Generating Station License Renewal Application

• Technical Information 4.8-14 G02-05-153, W Oxenford (Energy Northwest)

Letter to NRC Document Control Desk, "Columbia Generating Station, Docket No. 50-397 Analytical Evaluation of Inservice Inspection Examination Results," September 15, 2005. 4.8-15 NRC letter, Gus C. Lainas to Carl Terry, BWRVIP Chairman, "Final Safety Evaluation of the BWR Vessel and Internals Project BWRVIP-05 Report (TAC No. M93925)," July 28, 1998. Time-Limited Aging Analyses Page 4.8-2 January 2010 *

• Columbia Generating Station*License Renewal Application Technical Information APPENDIX A FINAL SAFETY ANALYSIS REPORT SUPPLEMENT Final Safety Analysis Report Supplement Page A-1 January 2010'. *
• APPENDIX A Columbia Generating Station . License Renewal Application Technical Information FINAL SAFETY ANALYSIS REPORT SUPPLEMENT Final Safety Analysis Report Supplement Page A-1 January 2010 Columbia Generating Station License Renewal Application Technical Information

[This page intentionally blank]Final Safety Analysis Report Supplement ~ageA-2 January 2010 Final Safety Analysis Report Supplement Page A-2 January 2010. Columbia Generating Station License Renewal Application

• Technical Information

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• Final Safety Analysis Report Supplement I?age January 2010 Columbia Generating StationLicense Renewal Application Technical Information APPENDIX A TABLE OF CONTENTS A.0 Final Safety Analysis Report Supplement

............................ .............................

................

7 A .1 In tro d u c tio n ..............................................................................

.....................................

7 A .1.1 N ew FSA R S ection ........................................................................................ ..7 A.1.2 Aging Management Program and Activities ................................... I ..................... 7 A.1.2.1 Aboveground Steel Tanks Inspection ......................................................... 8 A.1.2.2 Air Quality Sampling Program ..................................................................... 8A.1.2.3 Appendix J Program ...................................... 8 A.1.2;4 Bolting Integrity Program ............................................................................ 9 A.1.2.5 Buried Piping and Tanks Inspection Program ........................................... 9 A.1.2.6 BWR Feedwater Nozzle Program ............................................................. 9 A.1.2.7 BWR Penetrations Program ..................................................................... 10 A.1.2.8 BWR Stress Corrosion Cracking Program ................................................ 10 A.1.2.9 BWR Vessel ID Attachment Welds Program... ....................................... 10 A.1.2.10 BWR Vessel Internals Program ................................................................. 11 A.1.2.11 BWR Water Chemistry Program .............................................................. 11 A.1.2.12 Chemistry Program Effectiveness Inspection ........................................... 12 A.1.2.13 Closed Cooling Water Chemistry Program ................................................ 12 A .1.2.14 C ooling U nits Inspection ............................................................................ 12 A.1.2.15 CRDRI Nozzle Program ......................................................................... 13 A.1.2.16 Diesel Starting Air Inspection .................................................................. 13 A.1.2.17 Diesel Systems Inspection ........................

..............................................

13 A.1.2.18 Diesel-Driven Fire Pumps Inspection ....................................................... 13 A.1.2.19 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program ................................... 14 A.1.2.20 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program ............. 14A.1.2.21 Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ R equirem ents Inspection .......................................................................... 15 A .1.2 .22 E Q P rogram ............................................................................................. ..15 A.1.2.23 External Surfaces Monitoring Program ...................................................... 15 A.1.2.24 Fatigue Monitoring Program ..................................... 16 Final Safety Analysis Report Supplement Page A-3 January.2010

• *
• APPENDIX A TABLE OF CONTENTS Columbia Generating Station License Renewal Application Technical Information A.O Final Safety Analysis-Report Supplement..

.............. -.............................. , .........

................

7 A.1 Introduction ..............................................................................

.....................................

7 A.1.1 New FSAR Section ................................................................................................ 7 A.1.2 Aging Management Program and Activities .............................

...... ; .....................

7 A.1.2.1 Aboveground Steel Tanks Inspection .............................................................. 8 A.1.2.2 Air Quality Sampling Program ......................................................................... 8 A .. 1.2.3 Appendix J Program ........................................................................................ 8 A.1.2A Bolting Integrity Program ................................................................................. 9 A.1.2.5 Buried Piping and Tanks Inspection Program ................................................. 9 A.1.2.6 BWR Feedwater Nozzle Program ................................................................... 9 A.1.2.7 BWR Penetrations Program .......................

..................................................

10 A.1.2.8 BWR Stress Corrosion Cracking Program .................................................... 10 A.1.2.9 BWR VessellD Attachment Welds Program ... ; ............................................. 10 A.1.2.10 BWRVessellnternals Program ..................................................................... 11 A.1.2.11 BWR Water Chemistry Program .................................................................... 11 A.1.2.12 Chemistry Program Effectiveness Inspection ................................................ 12 A.1.2.13 Closed Cooling Water Chemistry Program .................................................... 12 A.1.2.14 . Units Inspection ................................................................................ 12 A.1.2.15 CRDRL Nozzle Program ............................................................................... 13 A.1.2.16 Diesel Starting Air Inspection .................................................................... , ... 13 A.1.2.17 Diesel Systems Inspection ........................

...................................................

13 A.1.2.18 Diesel-Driven Fire Pumps Inspection ............................................................ 13 A.1.2.19 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program ......................................

............................

• ................

14 A.1.2.20 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program ...............

.............

14 A.1.2.21 Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection ....................

..........................................................

15 A.1.2.22 EQ Program ........................................................................

..........................

15 A.1.2.23 External Surfaces Monitoring Program .......................................................... 15 A.1.2.24 Fatigue Monitoring Program ............................................................. .' ............ 16 Final Safety Analysis Report Supplement Page A-3 January 2010 Columbia Generating Station License Renewal Application Technical Information APPENDIX A TABLE OF CONTENTS A .1.2.25 Fire P rotection P rogram ................................................................................ 16 A .1.2.26 Fire W ater Program ................................................................................... 16 A .1.2.27 Flexible Connection Inspection ................................................................ 17 A.1.2.28 Flow-Accelerated Corrosion (FAC) Program ........................................... 17 A.1.2.29 Fuel Oil Chemistry Program ................................ 17 A.1.2.30 Heat Exchangers Inspection ..................................................................... 18 A.1.2.31 High-Voltage Porcelain Insulators Aging Management Program ............. 18 A.1.2.32 Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program ................................... 18 A.1.2.33 Inservice Inspection (ISI) Program ........................................................... 19 A.1.2.34 Inservice Inspection (ISI) Program- IWE ............................ 19A.1.2.35 Inservice Inspection (ISI) Program -IWF ................................................ 20 A.1.2.36 Lubricating Oil Analysis Program .............................................................. 20 A .1.2.37 Lubricating O il Inspection ......................................................................... 21 A .1I.2.38 M asonry W all Inspection ......................................................................... 21 A.1.2.39 Material Handling System Inspection Program ......................................... 21 A.1.2.40 Metal-Enclosed Bus Program ................................................................... 21 A.1.2.41 Monitoring and Collection Systems Inspection ......................................... 22 A.1.2.42 Open-Cycle Cooling Water Program ......... .................. ................. 22 A.1.2.43 Potable Water Monitoring Program ......................................................... 23 A.1.2.44 Preventive Maintenance -RCIC Turbine Casing .................................... 23 A.1.2.45 Reactor Head Closure Studs Program ..................................................... 23 A.1.2.46 Reactor Vessel Surveillance Program ........................ I ............................ 23 A.1.2.47 Selective Leaching Inspection ................................................................... 24 A.1.2.48 Service Air System Inspection ............................... 24 A.1.2.49 Small Bore Class 1 Piping Inspection ....................................................... 24 A.1.2.50 Structures Monitoring.Program ........................ ""/ ....................................... 25 A.1.2.51 Supplemental Piping/Tank Inspection ....................................................... 25 A.1.2.52 Thermal Aging and Neutron Embrittlement of Cast Austenitic Stainless Steel (C A S S ) P rogram ............................................................................... 26 A.1.2.53 Water Control Structures Inspection ....................................................... 26 Final Safety Analysis Report Supplement Page A-4. January 2010 A.1.2.25 A.1.2.26 A.1.2.27 A.1.2.28 A.1.2.29 A.1.2.30 A.1.2.31 A.1.2.32 A.1.2.33 A.1.2.34 A.1.2.35 A.1.2.36 A.1.2.37 A.1.2.38 A.1.2.39 A.1.2.40 A.1.2.41 A.1.2.42 A.1.2.43 A.1.2.44 A.1.2.45 A.1.2.46 A.1.2.47 A.1.2.48 A.1.2.49 A.1.2.50 A.1.2.51 A.1.2.52 Columbia Generating Station License Renewal Application .* Technical Information APPENDIX A TABLE OF CONTENTS Fire Protection Program ................................................................................ 16 Fire Water Program ....................................................................................... 16 Flexible Connection Inspection ............................................ .......................... 17 Flow-Accelerated Corrosion (FAC) Program ................................................. 17 . \ Fuel Oil Chemistry Program .............................. ........................................... 17 Heat Exchangers Inspection ................ , ........................... .............................. 18 High-Voltage Porcelain Insulators Aging Management Program .................. 18 Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program ................................................................................. 18 Inservice Inspection (lSI) Program ...................................................... .......... 19 Inservice Inspection (lSI) Program -IWE ..................................................... 19 Inservice Inspection (lSI) Program -IWF ................. ..................................... 20 Lubricating Oil Analysis Program ........................................................... ....... 20 Lubricating Oil Inspection ...................................................... ........................ 21 Masonry Wall Inspection ...................................................... ......................... 21 Material Handling System Inspection Program ............................................. 21 Metal-Enclosed Bus Program ........................................................................ 21 Monitoring and Collection Systems Inspection .............................................. 22 Open-Cycle Cooling Water Program ...........................................

..........

....... 22 Potable Water Monitoring Program .................... ...................................... ..... 23 Preventive Maintenance -RCIC Turbine Casing .......................................... 23 Reactor Head Closure Studs Program ...................................................... .... 23 Reactor Vessel Surveillance Program ...............

........ : ... : .........................

..... 23 Selective Leaching Inspection ................................................................... .... 24 Service Air System Inspection ...................................................... ................. 24 Small Bore Class 1 Piping Inspection ........................................................... ,*24 Structures Monitoring.Program ......................... "( ............ ............................... 25 Supplemental PipingfTank Inspection ...................................................... ..... 25 Thermal Aging and Neutron Embrittlement of Cast Austenitic Stainless Steel (CASS) Program ............ ................................................... ................... 26

• A.1.2.53 Water Control Structures Inspection

...........................................................

.. 26

• Final Safety Analysis Report Supplement Page A-4* January 2010 Columbia Generating StationLicense Renewal Application Technical Information APPENDIX A TABLE OF CONTENTS A.1.3 Evaluation of Time-Limited Aging Analyses .................................................

26 A.1.3.1 Reactor Vessel Neutron Embrittlement ..................................................... 27 A .1.3 .2 M etal Fatigue ......................................................................................... ..3 1 A.1.3.3 Non-Class 1 Component Fatigue Analyses ...................... 34 A.1.3.4 Effects of Reactor Coolant Environment on Fatigue Life of Components a n d P ip ing ............................................................. .................................. ..3 5 A.1.3.5 Environmental Qualification of Electrical Equipment ................................ 36 A.1.3.6 Fatigue of Primary Containment, Attached Piping, and Components ..... 37 A.1.3.7. Other Plant-Specific Time-Limited Aging Analyses.................... 40A .1.4 R efe re nces .................................................................................................... ..4 1 A.1.5 License Renewal Commitment List .............................................................. 41 Final Safety Analysis Report Supplement Page A-5 January 2010* ( *

• APPENDIX A TABLE OF CONTENTS' Columbia Generating Station License Renewal Application Technical Information A.1.3 Evaluation of Time-Limited Aging Analyses ... : ....................................................

26 A.1.3.1 Reactor Vessel Neutron Embrittlement ......................................................... 27 A.1.3.2 Metal ................................................................ 1, ******************************* 31 A.1.3.3 Non-Class 1 Component Fatigue Analyses ................................ ................ 34 A.1.3.4 Effects of Reactor Coolant Environment on Fatigue life of Components and Piping ........................................................ .' ............................................. 35 A.1.3.5 Environmental Qualification of Electrical Equipment ..................................... 36 A.1.3.6 FatiguE! of Primary Containment, Attached Piping, and Components ........... 37 A.1.3.7. Other Plant-Specific Time-limited Aging Analyses ...................................... .40 A.1.4 References .......................................................................................................... 41 A.1.5 license REmewal Commitment list .................................................................... 41 Final Safety Analysis Report Supplement PageA-5 Jan'uary 2010 Columbia Generating Station License Renewal Application Technical Information [This page intentionally blank]Final Safety Analysis Report Supplement Page A-6 January 2010[This page intentionally blank] Final Safety Analysis Report Supplement Page A-6 . Columbia Generating Station License Renewal Application Technical Information January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information A.0 FINAL SAFETY ANALYSIS REPORT SUPPLEMENT A.1 INTRODUCTION This appendix provides the information to be submitted in a Final Safety Analysis Report (FSAR) Supplement as required by 10 CFR 54.21(d) for the License Renewal Application (LRA). The LRA contains the technical information required by 10 CFR 54.21(a) and (c). Section 3 of the LRA contains the results of the aging management reviews. The programs and activities credited to manage the effects of aging. are described in LRA Appendix B. Section 4 of the LRA documents the evaluations of time-limited aging analyses for the period of extended operation.

LRA Section 3, Section 4, and Appendix B have been used to prepare the program and activity descriptions that are contained in this appendix. In addition, this appendix contains a listing of commitments associated with license renewal. The information presented in LRA Sections A.1.2, A.1.3, and A.1.4 will be incorporated into the FSAR following issuance of the renewed operating license. 'The listing of commitments for license renewal in LRA Section A.1.5 is provided for information, but will not be included in the FSAR. The license renewal commitments will be'tracked within the Columbia regulatory commitment management program (see Commitment Item Number 57).A.1.1 New FSAR Section The information contained in LRA Sections A.1.2, A.1.3, and A.1.4 will be incorporated into the FSAR to document aging management programs and activities credited in the Columbia integrated plant assessment and time-limited aging analyses evaluated for the period of extended operation. A.1.2 Aging Management Program and Activities The license renewal integrated plant assessment identified existing and new aging management programs necessary to provide reasonable assurance that components within the scope of license renewal will continue to perform their intended functions consistent with the current licensing basis (CLB) for the period .of extended operation. This section describes the aging management programs and activities identified during the integrated plant assessment. The aging management programs will be implemented prior to the period of extended operation. One-time inspections will be conducted within the 10-year period prior to beginning the period of extended operation. The aging management programs identified as necessary in association with the evaluation of time-limited aging analyses are described in Section A. 1.3.Three elements of an effective aging management program that are common to each of the aging management programs are corrective actions, confirmation process, andadministrative controls. These elements are included in the Operational Quality Final Safety Analysis Report Supplement Page A-7 January 2010* Columbia Generating Station License Renewal Application Technical Information A.O FINAL SAFETY ANALYSIS REPORT SUPPLEMENT A.1 INTRODUCTION This appendix provides the information to be submitted in a Final Safety Analysis Report (FSAR) Supplement as required by 10 CFR 54.2t(d) for the License Renewal' Application (LRA). The LRA contains the technical information required by , 10 CFR 54.21(a) and (c). Section 3 of the LRA contains the results of the aging management reviews. The programs and activities credited to manage the effects of aging, are described in LRA Appendix B. Section 4 of the LRA documents the evaluations of time-limited aging analyses for the period of extended operation. LRA Section 3, Section 4, and Appendix B have been used to prepare the program and activity descriptions that are contained in this appendix. In addition, this appendix contains a iisting of commitments associated with license renewal., The information presented in LRA Sections A.1.2, A.1.3, and A.1.4 will be incorporated into the FSAR following issuance of the renewed operating license. The listing of commitments for license renewal in LRA Section A.1.5 is provided for information, but will not be included in the FSAR. The license renewal commitments will be itracked within the Columbia regulatory commitment management program (see Commitment Item Number 57).

• A.1.1 New FSAR Sect:ion
• The information contained in lRA Sections A.1.2, A.1.3, and A.1.4 will be incorporated into the FSAR to document aging management programs and activities credited in the . Columbia integrated plant assessment and time-limited aging analyses evaluated for the period of extended operation.

' A.1.2 Aging Management Program and Activities The license renewal integrated plant assessment identified existing and new aging management programs necessary to provide reasonable assurance that components within the scope of license renewal will continue to perform their intended functions consistent with the current licensing basis (CLB) for the period *ofextended operation. This section describes the aging management programs and activities identified during the integrated plant assessment. The aging management programs will be implemented prior to the period of extended operation. One-time inspections will be conducted within the 10-year period prior to beginning the period of extended operation. The aging managememt programs identified as necessary' in association with the evaluation bf time-limitBd aging analyses are described in SectionA.1.3. Three elements of an effective aging management program that are common to each of the aging management programs are corrective actions, confirmation proGess, and administrative controls. 'These elements are included in the Operational Quality Final Safety Analysis Repol1 Supplement Page A-7 January 2010 ( Columbia Generating Station License Renewal Application Technical Information Assurance Program Description (OQAPD) for Columbia, which implements the requirements of 10 CFR 50, Appendix B.Prior to the period of extended operation, the elements of corrective actions, confirmation process, and administrative controls in the OQAPD will be applied to required aging management programs for both safety-related and non-safety related structures and components determined to require aging management during the period of extended operation. A.1.2.1 Aboveground Steel Tanks Inspection The Aboveground Steel Tanks Inspection detects and characterizes the conditions on the bottom surfaces of the condensate storage tanks. The inspection provides direct evidence through volumetric examination as to whether, and to what extent, a loss of material due to corrosion has occurred in inaccessible areas (i.e., tank base and bottom surface).The Aboveground Steel Tanks Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.2 Air Quality Sampling Program The Air Quality Sampling Program is an existing prevention and condition monitoring program that manages loss of material due to corrosion for Diesel Starting Air (DSA)components that contain compressed air through periodic sampling of the air for hydrocarbons, dewpoint, and particulates and periodic ultrasonic inspection of the DSA System air receivers. In addition, the Air Quality Sampling Program ensures that the Control Air System remains dry and free of contaminants, such that no aging effects require management. The Air Quality Sampling Program is supplemented by the Diesel Starting Air Inspection, which provides verification of the effectiveness of the program in mitigating the effects of aging in the DSA System dryers and the downstream piping and components (excluding the DSA System air receivers). A.1.2.3 Appendix J ProgramThe Appendix J Program is an existing monitoring program that detects degradation of the Primary Containment and systems penetrating the Primary Containment, which are the containment shell and primary containment penetrations including (but not limited to) the personnel airlock, equipment hatch, control rod drive hatch, and drywell head.The Appendix J Program provides assurance that leakage from the Primary Containment will not exceed maximum values for containment leakage.Final Safety Analysis Report Supplement Page A-8 January 2010 Columbia Generating Station License Renewal Application Technical Information Assurance Program Description (OQAPD) for Columbia, which implements the requirements of 10 CFR 50, Appendix B. Prior to the period of extended operation, the elements of corrective actions, confirmation process, and administrative controls in the OQAPD will be applied to required aging management programs for both safety-related and non-safety related structures and components determined to require aging management during the period of extended A.1.2.1 Aboveground Steel Tanks Inspection The Aboveground Steel Tanks Inspection detects and characterizes the conditions on the bottom surfaces of the condensate storage tanks. The inspection provides direct evidence through volumetric examination as to whether, and to what extent, a loss of material due to corrosion has occurred in inaccessible areas (i.e., tank base and bottom surface). The Aboveground Steel Tanks Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 1 a-year period prior to the period of extended operation. A.1.2.2 Air Quality Sampling Program The Air Quality Sampling Program is an existing prevention and condition monitoring program that manages loss of material due to corrosion for Diesel Starting Air (DSA) components that contain compressed air through periodic sampling of the air for hydrocarbons, dewpoint, and particulates and periodic ultrasonic inspection of the DSA System air receivers. In addition, the Air Quality Sampling Program ensures that the Control Air System remains dry and free of contaminants, such that no aging effects require management. The Air Quality Sampling Program is supplemented by the Diesel Starting Air Inspection, which provides verification of the effectiveness of the program in mitigating the effects of aging in the DSA System dryers and the downstream piping and ( components (excluding the DSA System air receivers). A.1.2.3 Appendix J Program The Appendix J Program is an existing monitoring program* that detects degradation of the Primary Containment and systems penetrating the Primary Containment, which are the containment shell and primary containment penetrations including (but not limited to) the personnel airlock, eqUipment hatch, control rod drive hatch, and drywell head. The Appendix J Program provides assurance that leakage from the Primary Containment will not exceed maximum values for containment leakage. Final Safety Analysis Report Supplement . Page A-8 January 2010 * *

• Columbia Generating Station* License Renewal Application Technical Information A.1.2.4 Bolting Integrity Program The Bolting Integrity Program is a combination of existing activities that, in conjunction with other credited programs, address the management of aging for the bolting of mechanical components and structural connections within the scope of license renewal.The Bolting Integrity Program relies on manufacturer and vendor information and industry recommendations for the proper selection, assembly, and maintenance ofbolting for pressure-retaining closures and structural connections.

The Bolting IntegrityProgram includes, through the Inservice Inspection (ISI) Program, Inservice Inspection (ISI) Program -IWF, Structures.Monitoring Program, and External Surfaces Monitoring Program, the periodic inspection of bolting for indications of degradation such as leakage, loss of material due to corrosion, loss of pre-load, and cracking due to stress corrosion cracking (SCC) and fatigue.A.1.2.5 Buried Piping and Tanks Inspection Program The Buried Piping and Tanks Inspection Program manages the effects of loss of material due to corrosion on the external surfaces of piping and tanks exposed to a buried environment. The Buried Piping and Tanks Inspection Program is a combination of a mitigation program (consisting of protective coatings) and a condition monitoring program (consisting of visual inspections). An inspection of buried piping will be performed within the 10-year period prior to entering the period of extended operation. An, additional inspection of buried piping willbe performed within 10 years after entering the period of extended operation. The Buried Piping and Tanks Inspection Program is an existing program that requires enhancement prior to the period of extended operation. A.1.2.6 BWR Feedwater Nozzle Program The BWR Feedwater Nozzle Program is an existing program that manages cracking due to stress corrosion cracking and intergranular attack (SCC/IGA) and flaw growth of the feedwater nozzles. The BWR Feedwater Nozzle Program is in accordance with ASME Section XI and NRC augmented requirements. The BWR Feedwater Nozzle Program consists of: (a) enhanced inservice inspection in accordance with the requirements of the ASME Boiler and Pressure Vessel Code, Section Xl, Subsection IWB, Table IWB 2500-1 (2001 edition including the 2002 and 2003 Addenda) and the recommendations of General Electric report NE-523-A71-0594-A [Reference A.1.4-1], and (b) system modifications, as described in FSAR Section 5.3.3.1.4.5, to mitigate cracking. The program specifies periodic ultrasonic inspection of critical regions of the feedwater nozzles.Final Safety Analysis Report Supplement Page A-9 January 2010 N\* *

• A.1.2.4 . Bolting Integrity Program Columbia Generating Station . License Renewal Application Technical Information The Bolting Integrity Program is a combination of existing activities that, in conjunction with other credited programs, address the management of aging for the bolting of mechanical components and structural connections within the scope of license renewal. The Bolting Integrity Program relies on manufacturer.

and vendor' information and industry recommendations for the proper selection, assembly, and maintenance of bolting for pressure-retciining closures and structural connections. The Bolting Integrity Program includes, through the Inservice Inspection (lSI) Program, Inservice Inspection '(ISI) Program -IWF, Structures.Monitoring Program, and External Surfaces Monitoring Program, the periodic inspection of bolting for indications of degradation such as leakage, loss 'of material due to corrosion, loss of pre-load, and cracking due to stress corrosion cracking (SCC) and fatigue .. A.1.2.S Buried Piping and Tanks Inspection Program The Buried Piping and Tanks Inspection Program manages the effects of loss of materi<;il due to corrosion on the external surfaces of piping and tanks exposed to a buried environment. The Buried Piping and Tanks Inspection Program is a combination of a mitigation program (consisting of protective coatings) and a condition monitoring program (consisting of visual inspe.ctions) . An inspection of' buried piping will be performed within the 10-year period prior to entering the period of e!xtended operation. An, additional inspection of buried piping will be performed within 10 years after entering the period of extended operation. The Buried Piping and Tanks Inspection Program is an existing program that requires enhancement prior to the period of extended operation. A.1.2.6 BWR Feedwater Nozzle Program The BWR Feedwater 1\I0zzie Program is an existing program that manages cracking due to stress corrosion cracking and intergranular attack (SCCIIGA) and flaw growth of the feedwater nozzles. The BWR Feedwater Nozzle Program is in accordance with ASME Section XI and NRC augmented requirements. The BWR Feedwater Nozzle Program consists of: (a) enhanced inservice inspection in accordance with the requirements of the ASME Boiler .and Pressure Vessel Code, Section XI, Subsection IWB, Table IWB 2500-1 (2001 edition including the 2002 and 2003 Addenda) and the recommendations of General Electric report NE-523-A71-0594-A [Reference A.1.4-1], and (b) system modifications, as described in FSAR Section 5.3.3.1.4.5, to mitigate cracking. The program specifies periodiC ultrasonic inspection of critical regions of the fe!edw.ater nozzles . Final Safety Analysis Report Supplement Page A-9 . January 2010 Columbia Generating Station License Renewal Application Technical Information The BWR Feedwater Nozzle Program credits portions of the Inservice Inspection (ISI)Program.A.1.2.7 BWR Penetrations Program The BWR Penetrations Program is an existing condition monitoring program that manages cracking due to SCC or intergranular stress corrosion cracking (IGSCC) of reactor vessel instrument penetrations, jet pump instrument penetrations, control rod drive penetrations, and incore instrument penetrations. The BWR Penetrations Program detects and sizes cracks in accordance with the guidelines of approved Boiling Water Reactor Vessel and Internals Project (BWRVIP) documents and the requirements of the ASME Boiler and Pressure Vessel Code, Section Xl. The BWR Water Chemistry Program monitors and controls reactor coolant water chemistry in accordance with BWRVIP guidelines to ensure the long-term integrity and safe operation of the vessel components. The program credits portions of the Inservice Inspection (ISI) Program and the BWR Vessel Internals Program.A.1.2.8 BWR Stress Corrosion Cracking Program The BWR Stress Corrosion Cracking Program is an existing, condition monitoring program that manages cracking due to SCC/IGA for stainless steel and nickel alloy reactor coolant pressure boundary piping, nozzle safe ends, nozzle thermal sleeves, valve bodies, flow elements, and pump casings.The BWR Stress Corrosion Cracking Program consists of (a) preventive measures to mitigate SCC/IGA, and (b) inspection and flaw evaluation to monitor SCC/IGA and its effects. The BWR Water Chemistry Program monitors and controls reactor coolant water chemistry in accordance with BWRVIP guidelines to ensure the long-term mitigation of SCC/IGA. The program includes the scope of the Generic Letter 88-01 program, as modified by the staff-approved BWRVIP-75 report.The program credits portions of the Inservice Inspection (ISI) Program and the BWR Water Chemistry Program.A.1.2.9 BWR Vessel ID Attachment Welds Program The BWR Vessel ID Attachment Welds Program is an existing program that manages cracking due to SCC/IGA of the welds for internal attachments to the reactor vessel.The BWR Vessel ID Attachment Welds Program performs examinations and inspections as required by ASME Section Xl, augmented by BWRVIP-48-A. These inspections include enhanced visual inspections with resolution to the guidelines in BWRVIP-03. The BWR Water Chemistry Program monitors and controls reactor Final Safety Analysis Report Supplement Page A-1 0 January 2010 Columbia Generating Station License Renewal Application Technical Information The BWR Feedwater Nozzle Program credits portions of the Inservice Inspection (lSI) Program. A.1.2.7 BWR Penetrations Program The BWR Penetrations Program is an existing condition monitoring program that manages cracking due to SCC or intergranular stress corrosion cracking (IGSCC) of reactor vessel instrument penetrations, jet pump instrument penetrations, control rod drive penetrations, and incore instrument penetrations. The BWR Penetrations Program detects and sizes cracks in accordance, with the guidelines of approved Boiling Water Reactor Vessel and Internals Project (BWRVIP) documents and the requirements of the ASME Boiler and Pressure yessel Code, Section XI. The BWR Water Chemistry Program monitors and controls reactor coolant water chemistry in accordance with BWRVIP guidelines to ensure the long-term integrity and safe operation of the vessel components. The program credits portions of the Inservice Inspection (lSI) Program and the BWR Vessel Internals Program. A.1.2.S BWR Stress Corrosion Cracking Program

• The BWR Stress Corrosion Cracking Program is an existing I condition monitoring
• program that manages cracking due to SCC/IGA for stainless steel and nickel alloy reactor coolant pressure boundary piping, nozzle safe ends, nozzle thermal sleeves, valve bodies, flow elements, and pump casings. The BWR Stress Corrosion Cracking Program consists of (a) preventive measures to mitigate SCCIIGA, and (b) inspectiOn and flaw evaluation to monitor SCCIIGA and its effects. The BWR Water Chemistry Program monitors and controls reactor coolant water chemistry in accordance with BWRVIP guidelines to ensure the long-term mitigation of SCCIIGA. The program includes the scope of the Generic Letter 88-01 program, as modified by the staff-approved BWRVIP-75 report. ' The program credits portions of the Inservice Inspection (lSI) Program and the BWR Water Chemistry Program. A:1.2.9 BWR Vessel 10 Attachment Welds Program The BWR Vessel ID Attachment Welds Program is an existing program that manages cracking due to SCCIIGA of the welds for internal attachments to the reactor vessel. The BWR Vessel ID Attachment Welds Program performs examinations and inspections as required by ASME Section XI, augmented by BWRVIP-48-A..

These inspections include enhanced visual inspections with resolution to the guidelines in BWRVIP-03. The BWR Water Chemistry Program monitors and controls reactor Final Safety Analysis Report Supplement Page A-1 0 January 2010

• Columbia Generating Station License Renewal Application Technical Information coolant water chemistry in accordance with BWRVIP guidelines to ensure the long-term integrity and safe operation of the vessel internal attachment welds.The BWR Vessel ID Attachment Welds Program credits portions of the BWR VesselInternals Program and the Inservice Inspection (ISI) Program.A.1.2.16 BWR Vessel Internals Program The BWR Vessel Internals Program is an existing condition monitoring program that manages cracking due to stress corrosion cracking and irradiation assisted stress corrosion cracking (SCC/IASCC), SCC/IGA, flaw growth, and flow-induced vibration for various components and subcomponents of the reactor vessel internals.

The BWR Vessel Internals Program consists of mitigation, inspection, flaw evaluation, and repair in accordance with the guidelines of BWRVIP reports and the requirements of theASME Boiler and Pressure Vessel Code, Section XI. The BWR Water Chemistry Program monitors and controls reactor coolant water chemistry in accordance with BWRVIP guidelines to ensure the long-term integrity and safe operation of the vessel internal components. The BWR Vessel Internals Program credits portions of the Inservice Inspection (ISI)Program.A.1.2.11 BWR Water Chemistry Program The BWR Water Chemistry Program is an existing program that mitigates degradation of components that are within the scope of license renewal and contain or are exposed to treated water, treated water in the steam phase, reactor coolant, or treated water in a sodium pentaborate solution. The program manages the relevant conditions that could lead to the onset and propagation of a loss of material due to corrosion or erosion, cracking due to SCC, or reduction in heat transfer due to fouling through proper monitoring and control of chemical concentrations consistent with BWRVIP water chemistry guidelines. The BWR Water Chemistry Program is supplemented by the Chemistry Program Effectiveness Inspection and the Heat Exchangers Inspection, to provide verification of the effectiveness of the program in managing the effects of aging. Additionally, the BWR Water Chemistry Program is supplemented by the BWR Feedwater Nozzle Program, BWR Stress Corrosion Cracking Program, BWR Penetrations Program, BWR Vessel ID Attachment Welds Program, BWR Vessel Internals Program, Inservice Inspection (ISI) Program, and Small Bore Class 1 Piping Inspection to provide verification of the program's effectiveness in managing the effects of aging for reactor pressure vessel- reactor vessel internals, and reactor coolant pressure boundary components. Final Safety Analysis Report Supplement , Page A-1 1 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information coolant water chemistry in accordance with BWRVIP guidelines to ensure the long-term integrity and safe operation of the vessel internal attachment welds. The BWR Vessel 10 Attachment Welds Program credits portions of the BWR Vessel Internals Program and tl1e Inservice Inspection (lSI) Program. A.1.2.10 BWR Vessel Internals Program The BWR Vessel Internals Program is an existing condition monitoring program that manages cracking due! to stress corrosion cracking and irradiation assisted stress corrosion cracking (SCCIIASCC), SCCIIGA, flaw growth, and flow-induced vibration for various components and subcomponents of the reactor vessel internals.

The BWR Vessel Internals Program consists of mitigation, inspection, flaw evaluation, and repair in accordance with the guidelines of BWRVIP reports and the requirements of the ASME Boiler and Pressure Code, Section XI. The BWR Water Chemistry Program monitors and controls re'actor coolant water chemistry in accordance with BWRVIP guidelines to ensure the long-term integrity and safe operation of the vessel internal components, The BWR Vessel Internals Program credits portions of the ,Inservice Inspection (lSI) ProQ,ram . A.1.2.11 BWR Water Chemistry Program The BWR Water Chemistry Program is an existing program that mitigates degrapation of components that are within the scope of license renewal and contain or are exposed to treated '!!Vater, treated water in the steam phase, reactor ,coolant, or treated water in a sodium pentaborate solution. The program manages the relevant conditions that could lead to the onset and propagation of a loss of material due to corrosion or erOSion, cracking due to SCC, or reduction in heat transfer due to fouling through proper monitoring and control of chemical concentrations consistent with BWRVIP water chemistry guidelines. The BWR Water Che!mistry Program is supplemented by the Chemistry Program Effectiveness Inspection and the Heat Exchangers Inspection; to provide verification of the effectiveness of the program in managing the effects of aging. Additionally, the BWR Water Chemistry Program is supplemented by the BWR Feedwater Nozzle Program, BWR Stress Corrosion Program, BWR Penetrations Program, BWR Vessel 10 Attachment Welds Program, BWR Vessel Internals Program, Inservice Inspection (lSI) Program, and Small Bore Class 1 Piping Inspection to provide verification of the program's effectiveness in managing the effects of aging for reactor pressure vessel; reactor vessel internals, and reactor coolant pressure boundary components . Final Safety Analysis Report Supplement , Page A-11 January 2010 Columbia Generating Station License Renewal Application Technical Information A.1.2.12 Chemistry Program Effectiveness InspectionThe Chemistry Program Effectiveness Inspection detects and characterizes the condition of materials 'in representative low flow -and stagnant areas of systems with water chemistry controlled by the BWR Water Chemistry Program or the Closed Cooling Water Chemistry Program, and with fuel oil chemistry controlled by the Fuel Oil Chemistry Program. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion has occurred. The inspection also determines whether cracking due to SCC of susceptible materials in susceptible locations has occurred.The Chemistry Program Effectiveness Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1,2.13 Closed Cooling Water Chemistry Program The Closed Cooling Water Chemistry Program mitigates degradation of componentsthat are within the scope of license renewal and contain closed cooling water. The program manages the relevant conditions that could lead to the onset and propagation of a loss of material due to corrosion or erosion, cracking due to SCC, or reduction in heat transfer due to fouling through proper monitoring and control of corrosion inhibitor concentrations consistent with EPRI closed cooling water chemistry guidelines. The Closed Cooling Water Chemistry Program includes corrosion rate measurement in reactor building closed cooling water locations and is supplemented by the one-time Chemistry Program Effectiveness Inspection and Heat Exchangers Inspection, which provide verification of the effectiveness of the program in managing the effects of aging.The Closed Cooling Water Chemistry Program is an existing program that requires enhancement prior to the period of extended operation. A.1.2.14 Cooling Units Inspection The Cooling Units Inspection detects and characterizes the material condition of aluminum, steel, copper alloy, and stainless steel cooling unit components, that are exposed to condensation. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion, a reduction in heat transfer due to fouling of heat exchanger tubes and fins, or cracking due to SCC of aluminum components, has occurred.The Cooling Units Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted withinthe 10-year period prior to the period of extended operation. Final Safety Analysis Report Supplement Page A-1 2 January 2010 Columbia Generating Station License Renewal Application

• Technical Information A.1.2.12 Chemistry Program Effectiveness Inspection The Chemistry Program Effectiveness Ins'pection detects and characterizes the condition of materials

'in representative low flow and stagnant areas of systems with water chemistry controlled by the BWR Water Chemistry Program or the Closed Cooling Water Chemistry Program, and with fuel oil chemistry controlled by the Fuel Oil Chemistry Program. The inspection provides direct evidence as Jo whether, and to what extent, a loss of material due to corrosion has occurred. The inspection also determines whether cracking due to SCC of susceptible materials in susceptible locations has occurred. The Chemistry Program Effectiveness Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 1 O-year period prior to the period of extended operation. A.1.2.13 Closed Cooling Water Chemistry Program The Closed Cooling Water Chemistry Program mitigates degradation of components that are within the scope of license renewal and contain closed cooling water. The program manages the relevant conditions that could lead to the onset and propagation of a loss of material due to corrosion or erosion, cracking due to SCC, or reduction in heat transfer due to fouling through proper monitoring and control of corrosion inhibitor

• concen"trations consistent with EPRI closed cooling water chemistry guidelines.

The Closed Cooling Water Chemistry Program includes corrosion rate measurement in reactor building closed cooling water locations and is supplemented by the one-time Chemistry Program Effectiveness Inspection and Heat Exchangers Inspection, which provide verification of the effectiveness of the program in managing the effects* of aging. The Closed Cooling Water Chemistry' Program is an existing program that requires enhancement prior to the period of extended operation. A.1.2.14 Cooling Units Inspection The Cooling Units Inspection detects and characterizes the material condition of aluminum, steel, copper alloy, and stainless steel cooling unit components that are exposed to condensation. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion, a reduction in heat transfer due to fouling of heat exchanger tubes and fins, or cracking due to SCC of aluminum components, has occurred. The Cooling Units Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 1 O-year period prior to the period of extended operation. Final Safety Analysis Report Supplement Page A-12 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information A.1.2.15 CRDRL Nozzle Program The CRDRL Nozzle Program is an existing mitigation and condition monitoring program that manages cracking due to flaw growth of the control rod drive return line (CRDRL)nozzle, safe end, cap, and connecting welds. The CRDRL Nozzle Program consists of a) mitigation activities, and b) inspection, flaw evaluation, and repair in accordance with the ASME Boiler and Pressure Vessel Code, Section Xl, Subsection IWB, Table IWB 2500-1 (2001 Edition through 2003 Addenda) and the recommendations of NUREG-0619.

System modifications were implemented by the original equipment manufacturer prior -to initial startup to mitigate cracking. The BWR Water Chemistry Program monitors and controls reactor coolant water chemistry in accordance with BWRVIP guidelines to ensure the long-term integrity and safe operation of the critical regions of the CRDRL nozzle.The CRDRL Nozzle Program credits portions of the Inservice Inspection (ISI) Program.A.1.2.16 Diesel Starting Air Inspection The Diesel Starting Air Inspection detects and characterizes the condition of materials for the DSA System air dryers and downstream piping and components (excluding the DSA System air receivers). The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion has occurred.The Diesel Starting Air Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.17 Diesel Systems Inspection The Diesel Systems Inspection detects and characterizes the condition of materials for the interior of the exhaust piping for the Division 1, 2, and 3 diesels in the Diesel Engine Exhaust System, including the loop seal drains from the exhaust piping, and the drain pans and drain piping associated with air-handling units of the Diesel Building HVAC systems. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion has occurred.The Diesel Systems Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted. within the 10-year period prior to the period of extended operation. A.1.2.18 Diesel-Driven Fire Pumps Inspection The Diesel-Driven Fire Pumps Inspection detects and characterizes the material condition of the interior~of the Fire Protection System diesel engine exhaust piping, and of Fire Protection System diesel heat exchangers exposed to a raw water environment. Final Safety Analysis Report Supplement Page A-1 3 January 2010* *

• A.1.2.1S CRDRL NIDzzie Program Columbia Generating Station License Renewal Application Techhicallnforrilation The CRDRL Nozzle Program is an existing mitigation and condition monitoring program that manages cracking due to flaw growth of the control rod drive return line (CRDRL) nozzle, safe end, cap, cmd connecting welds. The CRDRL Nozzle Program consists of a) mitigation activities, and b) inspection, flaw evaluation, and repair in accordance with the ASME Boiler and Pressure Vessel Code, Section XI, Subsection IWB, Table IWB 2500-1 (2001 Edition through' 2003 Addenda) and the recommendations of NUREG-0619.

System mpdifications were implemented by the original equipment manufacturer prior -to initial startup to mitigate cracking. The BWR Water Chemistry Program monitors and controls reactor coolant water chemistry in accordance with BWRVIP guidelines to ensure the long-term integrity and safe operation of the critical regions of the CRDRL nozzle. The CRDRL Nozzle Program credits portions of the Inservice Inspection (lSI) Program. A.1.2.16 Diesel Stinting Air Inspection The Diesel Starting Air Inspection detects and characterizes the condition of materials. for the DSA System air dryers and downstream piping and components (excluding the DSA System air The inspection provides direct evidence as to whether, and to what extent, a loss of material to corrosion has occurred. The Diesel Starting Air Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 1 O-year period prior to the period of extended operation. Diesel Systems Inspection The Diesel Systems Inspection detects and characterizes the condition of materials for the interior of the exhaust piping for the Division 1, 2, and 3 diesels in the Diesel Engine Exhaust System, including the loop seal drains from the exhaust piping, and the drain pans and drain piping associated with air-handling units of the Diesel Building HVAC systems. The inspection provides direct evidence as to whether, and to what extent, a loss' of material due to corrosion has occurred. The Diesel Systems Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted_ within the 1 O-year period prior to the period of extended operation. A.1.2.18 Diesel-Dlriven Fire Pumps Inspection The Diesel-Driven Fire Pumps detects and characterizes the material condition of the interior\of the Fire Protection System diesel engine exhaust piping, and of Fire Protection Sysb3m diesel heat exchangers exposed tq a raw water environment. Final Safety Analysis RepOit Supplement Page A-13 January 2010 Columbia Generating StationLicense Renewal Application Technical Information The inspection provides direct evidence as to whether, and to what. extent, a loss of material due to corrosion or erosion, or a reduction in heat transfer due to fouling has occurred. The inspection also determines whether cracking due to SCC of susceptible materials has occurred.The Diesel-Driven Fire Pumps Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.19 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program is an inspection program that detects degradation of electrical cables andconnections that are not environmentally qualified and are within the scope of license renewal. The program provides for periodic visual inspection of accessible, non-environmentally qualified cables and connections in order to determine if age-related degradation is occurring, particularly in plant areas with adverse localized environments. An adverse localized environment is a condition in a limited plant area that is significantly more severe than the specified design or bounding, plant environment for the general area.The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program is a new aging management program that will be implemented prior to the period of extended operation. The inspection frequency of the program will be once every 10 years, with the initial inspection to Ile pe'rformed prior to the period of extended operation. A.1.2.20 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ RequirementsUsed in Instrumentation Circuits Program is a monitoring program that detects degradation of electrical cables and connections that are not environmentally qualified and used in circuits with sensitive, low-current applications (such as radiation monitoring and nuclear instrumentation loops). The program provides for a review of calibration records for the low-current instruments, in order to detect and identify degradation of the cable system insulation resistance. The program retains the option to perform direct cable testing.The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ RequirementsUsed in Instrumentation Circuits Program is a new aging management program that will be implemented prior to the period of extended operation. The frequency of the program will be once every 10 years, with the initial review to be performed prior to the period of extended operation. Final Safety Analysis Report Supplement Page A-1 4 January 2010 Columbia Generating Station License Renewal Application

• Technical Information The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion or erosi6n, or a reduction in heat transfer due to fouling has occurred.

The inspection also determines whether cracking due to SCC of susceptible materials has occurred. The Diesel-Driven Fire Pumps Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 1 a-year period prior to the period of extended operation. A.1.2.19 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program is an inspection program that detects degradation of electrical cables and connections that are not environmentally qualified and are within the scope of license. renewal. The program provides for periodic visual inspection of accessible, non-environmentally qualified cables and connections in order to determine if related degradation is occurring, particularly in plant areas with adverse localized environments. An adverse localized environment is a condition in a limited plant area that is significantly* more s,evere than the specified design or bounding* plant environment for the general area. . . The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program is a new aging management program that will be implemented prior to the period of extended operation. The inspection ffequency of the program will be once every 10 years, with the initial inspection to be performed prior to the period of extended operation. A.1.2.20 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program is a monitoring program that detects degradation of electrical cables and connections that are not environmentally qualified and used in circuits with sensitive, low-current applications (such as radiation monitoring and nuclear instrumentation loops). The program provides for a review of calibration records for the low-current instruments, 'in order to detect and identify degradation of the cable system insulation resistance. The program retains the option to perform direct cable testing. The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program is a new aging management program that will be implemented prior to the period of extended operation. The frequency of the program will be once every 10 years, with the initial review to be performed prior to the period of extended operation. Final Safety Analy.sis Report Supplement Page A-14 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information A.1.2.21 Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection detects and characterizes the material condition of metallic electrical connections within the scope of license renewal. The inspection uses thermography (augmented by contact resistance testing) to detect loose-or degraded connections that lead to increased resistance for a representative sample of metallic electrical connections in various plant locations.

The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.22 EQ Program Environmental qualification (EQ) analyses for electrical components with a qualified life of 40 years or greater are identified as TLAAs; therefore, the effects of aging must be addressed for license renewal.NRC regulation 10 CFR 50.49, "Environmental Qualification of Electrical Equipment Important to Safety for Nuclear Power Plants," requires licensees to identify electrical equipment covered under this regulation and to maintain a qualification file demonstrating that the equipment is qualified for its application and will perform its safety function up to the end of its qualified life. The EQ Program is an existing program that implements the requirements of 10 CFR 50.49 (as further defined by the Division of Operating. Reactor Guidelines, NUREG-0588, and Regulatory Guide 1.89 Revision 1).In accordance with 10 CFR 54.21 (c)(1)(iii), the EQ Program will be used to manage the effects of aging on the intended functions of the components associated with EQ TLAAs for the period of extended operation. A.1.2.23 External Surfaces Monitoring Program The External Surfaces Monitoring Program consists of observation and surveillance activities intended to detect degradation resulting from loss of material due to corrosion and cracking due to SCC for mechanical components, as well as hardening and loss of strength for elastomers. The External Surfaces Monitoring Program is a condition-monitoring program.The External Surfaces Monitoring Program is an existing program that requires enhancement prior to the period of extended operation. Final Safety Analysis Report Supplement Page A-1 5 January 2010* *

• A.1.2.21 Columbia Generating Station License Renewal Application Technical Information Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection detects and characterizes the material condition of metallic electrical connections within the scope of license renewal. The inspection uses thermography (augmented by contact resistance testing) to detect loose or degraded connections that lead to increased resistance for a representative sample of metallic electrical connections in various plant locations.

The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection is a new inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.22 EQ Program . Environmental qualification (EQ) analyses for electrical components with a qualified life of 40 years ot greater are identified as TLAAs; therefore, the effects of aging must be addressed for license rEmewal. NRC regulation 10 CFR 50.49, "Environmental Qualification of Electrical Equipment Important to Safety for Nuclear Power Plants," requires licensees to identify electrical equipment covered LInder this regulation and to maintain a qualification file demonstrating that the equipment is qualified for its application and will perform its safety function up to end of its qualified life. The EQ Program is an existing program that implements the requirements of 10 CFR 50.49 (as further defined by the Division of Operating. Reactor Guidelines, NUREG-0588, and Regulatory Guide 1.89 Revision 1). In accordance with 10 CFR 54.21 (c)(1)(iii), the EQ Program will be used to manage the effects of aging on the intended functions of the components associated with EQ TLAAs for the period of extended operation. ' A.1.2.23 External Surfaces Monitoring Program The External Surfaces Monitoring Program consists of observation and surveillance activities intended to detect degradation re'sulting from loss of material due to corrosion and cracking due to sec for mechanical components, as well as hardening and loss of strength for elastomers. The External Surfaces Monitoring Program is a monitoring program. The External Surfaces Monitoring Program is an existing program that requires enhancement prior to the period of extended operation . Final Safety Analysis Report Supplement Page A-15 January 2010 Columbia Generating Station License Renewal Application Technical Information A.1.2.24 Fatigue Monitoring Program Fatigue evaluations for mechanical components are identified as TLAAs; therefore, the effects of fatigue have been addressed for license renewal.Columbia monitors fatigue of various components (including ASME Class 1 reactor coolant pressure boundary, high energy line break locations, and Primary Containment) via the Fatigue Monitoring Program, which tracks transient cycles and calculates fatigue usage. Columbia has assessed the impact of the reactor coolant environment on the sample of critical components identified in NUREG/CR-6260. Calculation of fatigue usage values is not required for non-Class 1 SSCs. Instead, stress intensificationfactors and lower stress allowables are used to ensure components are adequately designed for fatigue.In accordance with 10 CFR 54.21(c)(1)(iii), the Fatigue Monitoring Program will be used to manage the. effects of aging due to fatigue on the intended functions of the components associated with fatigue TLAAs for the period of extended operation. The Fatigue Monitoring Program is an existing program that requires enhancement prior to the period of extended operation. A.1.2.25 Fire Protection Program The Fire Protection Program is an existing program, described in Appendix F of the FSAR, that detects degradation of components in the scope of license renewal that have fire barrier functions. Periodic visual inspections and functional tests are performed of fire dampers, fire barrier walls, ceilings and floors, fire-rated penetration seals, fire wraps, fire proofing, and fire doors to ensure that functionality and operability are maintained. In addition, the Fire Protection Program supplements the Fuel Oil Chemistry Program and External Surfaces Monitoring Program through performancemonitoring of the diesel-driven fire pump fuel oil supply components and testing and inspection of the halon suppression system, respectively. The Fire Protection Program is a condition monitoring program, comprised of tests and inspections based on National Fire Protection Association (NFPA) recommendations. A.1.2.26 Fire Water Program The Fire Water Program (sub-program of the overall Fire Protection Program) is described in Appendix F of the FSAR, and is credited with managing loss of material due to corrosion, erosion, macrofouling, and selective leaching, cracking due to SCC/IGA of susceptible water-based fire suppression components in the scope of license renewal. Periodic inspection and testing of the water-based fire suppression systems provides reasonable assurance that the systems will remain capable of performing their intended function. Periodic inspection and testing activities include hydrant and hose station inspections, fire main flushing, flow tests, and sprinkler Final Safety Analysis Report Supplement Page A-1 6 January 2010 A.1.2.24 Fatigue Monitoring Program Columbia Generating Station License Renewal Application Technical Information Fatigue evaluations for mechanical components are identified as TLAAs; therefore, the effects of fatigue have been addressed for license renewal. , Columbia monitors fatigue of various components (including ASME Class 1 reactor coolant pressure boundary, high energy line break locations, and Primary Containment) via the Fatigue Monitoring Program, which tracks transient cycles and calculates fatigue usage. Columbia has assessed the impact of the reactor coolant environment on the sample of critical components identified in NUREG/CR-6260. Calculation of fatigue usage values is not required for non-Class 1 SSCs. Instead, stress intensification factors and lower stress allowables are used to ensure components are adequately designed for fatigue. In accordance with 10 CFR 54.21 (c)(1 )(iii), the Fatigue Monitoring Program will be used to manage the. effects of aging due to fatigue on the intended functions of the components associated with fatigue TLAAs for the period of extended operation. The Fatigue Monitoring Program is an existing program that requires enhancement prior to the period of extended operation. A.1.2.25 . Fire Protection Program The Fire Protection Program is an existing program, described in Appendix F of the FSAR, that detects degradation of components in the scope of license renewal that have fire barrier functions. Periodic visual inspections and functional tests are performed of fire dampers, fire barrier walls, ceilings and floors, fire-rated penetration seals, fire wraps, fire proofing, and fire doors to ensure that functionality and operability are maintained. In addition, the Fire Protection Program supplements the Fuel Oil Chemistry Program and External Surfaces Monitoring Program through performance monitoring of the diesel-driven fire pump fuel oil supply components and testing and inspection of the halon suppression system, respectively. The Fire Protection Program is a condition monitoring program, comprised of tests and inspections based on National Fire Protection Association (NFPA) recommendations. A.1.2.26 Fire Water Program The Fire Water Program (sub-program of the overall Fire Protection Program) is described in Appendix F of the FSAR, and is credited with managing loss of material due to corrosion, erosion, macrofouling, and selective leaching, cracking due to SCCIIGA of susceptible* water-based fire suppression components in the scope of license renewal. Periodic inspection and testing of the water-based fire suppression systems provides reasonable assurance that the systems will remain capable of performing their intended function. Periodic inspection and testing activities include hydrant and hose station inspections, fire main flushing, flow tests, and sprinkler Final Safety Analysis Report Supplement Page A-16 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information inspections.

The Fire Water Program is a condition monitoring,program, comprised of tests and inspections based on NFPA recommendations. The Fire Water Program is an existing program that requires enhancement prior to the period of extended operation. A.1.2.27 Flexible Connection Inspection The Flexible Connection Inspection detects and characterizes the material condition of elastomer components exposed to treated water, dried air, gas, and indoor air environments. The inspection provides direct evidence as to whether, and to what extent, hardening and loss of strength has occurred.The Flexible Connection Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.28 Flow-Accelerated Corrosion (FAC) ProgramThe Flow-Accelerated Corrosion (FAC) Program manages loss of material for steel and gray cast iron components located in the treated water environment of systems that are susceptible to FAC, also called erosion-corrosion. The FAC Program combines the elements of predictive analysis, inspections (to baseline and monitor wall-thinning), industry experience, station information gathering and communication, and engineering judgment to monitor and predict FAC wear rates. The program is a condition monitoring program that implements the recommendations of NRC Generic Letter 89-08, and follows the guidance and recommendations of EPRI NSAC-202L [Reference A. 1.4-2], to ensure that the integrity of piping systems susceptible to FAC is maintained. The FAC Program is an existing program that requires enhancement prior to the period of extended operation. A.1.2.29 Fuel Oil Chemistry Program The Fuel Oil Chemistry Program is an existing program that maintains fuel oil quality in order to mitigate degradation of the storage tanks and associated components containing fuel oil that are within the scope of license renewal. The program includes diesel fuel oil testing for emergency diesel generator and diesel-driven fire pump fuel.The Fuel Oil Chemistry Program manages the relevant conditions that could lead to the onset and propagation of loss of material due to corrosion, or cracking due to SCC ofsusceptible copper alloys, through proper monitoring and control of fuel oil contamination consistent with plant technical specifications and American Society for Testing and Materials (ASTM) standards for fuel oil. The relevant conditions are specific contaminants such as water or microbiological organisms in the fuel oil that could lead to corrosion of susceptible materials. Exposure to these contaminants is Final Safety Analysis Report Supplement Page A-1 7 January 2010 e e e,' Columbia Generating Station . License Renewal Application Technical Information . inspections. The Fire VVater Program is a condition monitoring,program, comprised of tests and inspections based on NFPA recommendations. The Fire Water Program is an existing program that requires prior to the period of extended operation. A.1.2.27 Flexible Connection Inspection The Flexible Connection Inspection detects and characterizes the material condition of elastomer components exposed to treated water, dried air, gas, and indoor air environments. The inspection provides direct evidence as to whether, and to what extent, hardening and loss of strength has occurred. The Flexible Connection Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 1 O-year period prior to the period of extended operation. , A.1.2.28 Flow-A.ccelerated Corrosion (FAC) Program The Flow-Accelerated Corrosion (FAC) Program manages loss of material for steel and gray cast iron components located' in the treated water environment of systems that are susceptible to FAC, al:so called erosion-corrosion. The FAC Program combines th.e elements of predictive analysis, inspections (to baseline and monitor wall-thinning), industry experience, station information gathering and communication, and engineering judgment to monitor and predict FAC wear rates. The program is a condition monitoring program that implements the recommendations of NRC Generic Letter 89-08, and follows the guidance and recommendations of EPRI NSAC-202L [Reference A. 1.4-2], to ensure that the integrity of piping systems susceptibleto FAG is maintained. The FAC Program is qn existing program that requires enhancement prior to the period of extended operation. . A.1.2.29 Fuel Oil Chemistry Program The Fuel Oil Chemistry Program is an existing program that fuel oil quality in order to mitigate of the storage tanks and associated components containing fuel oil that are within the sC9pe of license renewal. The program includes diesel fuel oil testing for emergency diesel generator and diesel-driven fire pump fuel. The Fuel Oil Chemistry Program manages the relevant conditions that could lead to the onset and propagation of loss of material due to corros,ion, or cracking due to SCC of susceptible copper alloys, through proper monitoring and control of fuel oil contamination consistent with plant technical specifications and American Society for Testing and Materials (ASTM) standards for fuel oil. The relevant conditions are specific contaminants such as water or microbiological organisms in the fuel Oil that could lead to corrosiol1 of susceptible materials. Exposure to these contaminants is Final Safety AnalysiS Report Supplement Page A-17 January 2010 Columbia Generating Station License Renewal Application Technical Information minimized by verifying the quality of new fuel oil before it enters the emergency diesel generator storage tanks and by periodic sampling to ensure that both the emergency diesel generator tanks and fire protection tanks are free of water and particulates. The Fuel Oil Chemistry Program is a mitigation program.The Fuel Oil Chemistry Program is supplemented by the Chemistry Program Effectiveness Inspection, which provides verification of the effectiveness of the program in mitigating the effects of aging.A.1.2.30 Heat Exchangers Inspection The Heat Exchangers Inspection detects and characterizes the surface conditions with respect to fouling of heat exchangers and coolers that are in the scope of the inspection and exposed to indoor air or to water with the chemistry controlled by the BWR Water Chemistry Program or the Closed Cooling Water Chemistry Program. The inspection provides direct evidence as to whether, and to what extent, a reduction of heat transfer due to fouling has occurred on the heat transfer surfaces of heat exchangers and coolers.The Heat Exchangers Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.31 High-Voltage Porcelain Insulators Aging Management Program The High-Voltage Porcelain Insulators Aging Management Program is an existing program that manages the build-up of contamination (hard water residue) on the surfaces of the 115-kV high-voltage insulators. The program provides for periodic cleaning or recoating of insulators and visual inspection of the coating (if present) on thehigh-voltage porcelain insulators between the 115-kV backup transformer and circuit breaker E-CB-TRB located in the station transformer yard.The High-Voltage Porcelain Insulators Aging Management Program is a preventive maintenance program consisting of activities to mitigate potential degradation of the insulation function due to hard water deposits. Uncoated insulators are inspected and cleaned every two years. Coated insulators are visually inspected for damage every two years and are re-coated every 10 years.A.1.2.32 Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program manages the aging of inaccessible medium-voltage cables that are not environmentally qualified and are within the scope of license renewal. The Final Safety Analysis Report Supplement Page A-1 8 January 2010 Columbia Generating Station License Renewal Application

• Technical Information minimized by verifying the quality of new fuel oil before it enters the emergency diesel generator storage tanks and by periodic sampling to ensure that both the emergency diesel generator tanks and fire protection tanks are free of water and particulates.

The Fuel Oil ChemistryProgram is a mitigation program. The Fuel Oil Chemistry Program is supplemented by the Chemistry Program Effectiveness Inspection, which provides verification of the effectiveness of the program in mitigating the effects of aging. A.1.2.30 Heat Exchangers Inspection The Heat Exchangers Inspection detects and characterizes the surface conditions with respect to fouling of heat exchangers and coolers that are in the scope of the inspection and exposed to indoor air or to water with the chemistry controlled by the BWR Water Chemistry Program or the Closed Cooling Water Chemistry Program. The inspection provides direct evidence as to whether, and to what extent, a reduction of heat transfer due to fouling has occurred on the heat transfer surfaces of heat exchangers and coolers. The Heat Exchangers Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted

• within the 1 O-year period prior to the period of extended operation.

A.1.2.31 High-Voltage Porcelain Insulators Aging Management Program The High-Voltage Porcelain Insulators Aging Management Program is an existing program that manages the build-up of contamination (hard water residue) on the surfaces of the 115-kV high-voltage insulators. The program provides for periodic cleaning or recoating of insulators and visual inspection of the coating (if present) on the high-voltage porcelain insulators between the 115-kV backup transformer and circuit breaker E-CB-TRB located in the station transformer yard .. The High-Voltage Porcelain Insulators Aging Management Program is a preventive maintenance program consisting of activities to mitigate potential degradation of the insulation function due to hard water deposits. Uncoated insulators are inspected and cleaned every two years. Coated insulators are visually inspected for damage every two years and are re-coated every 10 years. A.1.2.32 Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program The Inaccessible Medium-Voltage Cables Not Subject* to 10 CFR 50.49 EO Requirements Program manages the aging of inaccessible medium-voltage cables that are not environmentally qualified and are within the scope of license renewal. The Final Safety Analysis Report Supplement Page A-18 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information program provides for testing to identify the conditions of the conductor insulation, and also provides for periodic inspection and drainage (if necessary) of electrical manholes.The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program is a new aging management program that will be implemented prior to the period of extended operation.

The frequency of the cable testing portion of the program will be once every 10 years, with the first test to be performed prior to the period of extended operation. The frequency of the manhole inspections will be at least once every two years, with the first inspections to. be performed prior to the period of extended operation. A.1.2.33 Inservice Inspection (ISI) Program The Inservice Inspection (ISI) Program is an existing condition monitoring program that manages cracking due to SCC/IGA and flaw growth of multiple reactor coolant system pressure boundary components, including the reactor vessel, a limited number of internals components, and the reactor coolant system pressure boundary. The Inservice Inspection (ISI) Program also manages loss of material due to corrosion for reactor, vessel internals components and reduction of fracture toughness due to thermal embrittlement of cast austenitic stainless steel pump casings and valve bodies.The Inservice Inspection (ISI) Program details the requirements for the examination, testing, repair, and replacement of components specified in ASME Section Xl for Class 1, 2, or 3 components. The Inservice Inspection (ISI) Program complies with the ASME Code requirements. The program scope has been augmented to include additional requirements, and components, beyond the ASME requirements. Examples include the augmentation of ISI to expanded reactor vessel feedwater nozzle examinations, examinations of high energy line piping systems that penetrate containment, and examinations per Generic Letter 88-01. Such augmentation is consistent with the IS.I program description in NUREG-1801, Section XI.M1.A.1.2.34 Inservice Inspection (ISI) Program -IWE The Inservice Inspection (ISI) Program -IWE is an existing program that establishes responsibilities and requirements for conducting IWE inspections as required by 10 CFR 50.55a. The Inservice Inspection (ISI) Program -IWE includes visual examination of all accessible surface areas of the steel containment and its integral attachments, and containment pressure-retaining bolting in accordance with the requirements of the ASME Boiler and Pressure Vessel Code, Section Xl, Subsection IWE.The inservice examinations conducted throughout the service life of Columbia will comply with the requirements of the ASME Section Xl Edition and Addenda Final Safety Analysis Report Supplement Page A-19 January 2010 CL*

• Columbia Generating Station License Renewal Application Technical Information program provides for testing to identify the conditions of the conductor insulation, and also provides for periodiC inspection and drainage (if necessary) of electrical manholes.

The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program is anew aging management program that will be implemented prior to the period of extended operation. The frequency of the cable testing portion of the program will be once every 10 years, with the first test to be performed prior to the period of extended operation. The frequency of the manhole inspections will be at least once every two years, with the first inspections to be performed to the period of extended operation. A.1.2.33 Inservice Inspection (151) Program The Inservice Inspection (lSI) Program is an existing condition monitoring program that manages cracking due to SCC/IGA and flaw growth of multiple reactor coolant system pressure boundary components, including the reactor vessel, a limited number of internals components, and the reactor coolant system pressure boundary. The Inservice Inspection (lSI) Program also manages loss of material due to corrosion for reactor vessel internals components and reduction of fracture toughness due to thermal embrittlement of cast austenitic stainless steel pump casings and valve bodies . The Inservice Inspection (lSI) Program details the requirements for the examination, testing, repair, and replacement of components specified in ASME Section XI for Class 1, 2, or 3 components. The Inservice Inspection (lSI) Program complies with the ASME Code requirements. 'The program scope has been augmented to include additional requirements, and components, beyond the ASME requirements. Examples include the augmentation of lSI to expanded reactor vessel feedwater nozzle examinations, examinations of high energy line piping systems that penetrate containment, and examinations per Generic Letter 88-01. Such augmentation is consistent with the lSI program description in NUREG-1801, Section XI.M1. A.1.2.34 Inservice' Inspection (151) Program -IWE The Inservice Inspection (lSI) Program -IWE is an existing program that establishes responsibilities and requirements for conducting IWE inspections as required by 10 CFR 50.55a. The Inservice Inspection (lSI) Program -IWE includes visual examination of all accessible surface areas of the steel containment and its integral attachments, and containment pressure-retaining bolting in accordance with the requirements of the ASME Boiler and, Pressure Vessel Code, Section XI, Subsection IWE. The inservice examinations conducted throughout the, service life of Columbia will

• comply with the reqUirements of the ASME Section XI Edition and Addenda \ Final Safety Analysis Repol1 Supplement Page A-19 January 2010 Columbia Generating StationLicense Renewal Application Technical Information incorporated by reference in 10 CFR 50.55a(b) twelve months prior to the start of the inspection interval, subject to prior approval of the edition and addenda by the NRC.This is consistent with NRC statements of consideration for 10 CFR 54 associated with the adoption of new editions and addenda of the ASME Code in 10 CFR 50.55a.A.1.2.35 Inservice Inspection (ISI) Program -IWF The Inservice Inspection (ISI) Program -IWF is an existing program that establishes responsibilities and requirements for conducting IWF Inspections for ASME Class 1, 2, and 3 component supports as required by 10 CFR 50.55a. The Inservice Inspection (ISI) Program -IWF performs visual examination of supports based on sampling of the total support population.

The sample size varies depending on the ASME Class. The.largest sample size is specified for the most critical supports (ASME Class 1 and thoseother than piping supports (Class 1, 2, 3, and MC)). The sample size decreases for the less critical supports (ASME Class 2 and 3). The primary inspection method employed is visual examination. Degradation that potentially compromises support function or load capacity is identified for evaluation. Supports requiring corrective actions are re-examined during the next inspection period in accordance with the requirements of the ASME Boiler and Pressure Vessel Code, Section Xl, Subsection IWF. -The inservice examinations conducted throughout the service life of Columbia will comply with the requirements of the ASME Section Xl Edition and Addenda incorporated by reference in 10 CFR 50.55a(b) twelve months prior to the start of the inspection interval, subject to prior approval of the edition and addenda by the NRC.This is consistent with NRC statements of consideration for 10 CFR 54 associated with the adoption of new editions and addenda of the ASME Code in 10 CFR 50.55a.A.1.2.36 Lubricating Oil Analysis Program The Lubricating Oil Analysis Program manages loss of material due to corrosion or selective leaching of susceptible materials and reduction of heat transfer due to fouling for plant components that are within the scope of license renewal and exposed to a lubricating oil environment. The Lubricating Oil Analysis Program is a mitigation program.The Lubricating Oil Analysis Program is supplemented by the Lubricating Oil Inspection, which provides verification of the effectiveness of the program in mitigating the effects of aging.The Lubricating Oil Analysis Program is an existing program that requires enhancement prior to the period of extended operation. Final Safety Analysis Report Supplement Page A-20 January2010 Final Safety Analysis Report Supplement Page A-20 January 2010 .Columbia Generating Station License Renewal Application

• Technical Information incorporated by reference in 10 CFR 50.55a(b) twelve months prior to the start of the inspection interval, subject to prior approval of the edition and addenda by the NRC. This is consistent with NRC statements of consideration for 10 CFR 54 associated with the adoption of new editions and addenda of the ASME Code in 10 CFR 50.55a. A.1.2.35 Inservice Inspection (151) Program -IWF \ The Inservice Inspection (lSI) Program':"" IWF is an existing program that establishes responsibilities and requirements for conducting IWF Inspections fqr ASME Class 1, 2, and 3 component supports as required by 10 CFR 50.55a. The Inservice Inspection (lSI) Program -IWF performs visual examination of supports based on sampling of the total support population.

The sample size varies depending on the ASME Class. The largest sample size is specified for the most critical supports (ASME Class 1 and those other than piping supports (Class 1, 2, 3, and MC)). The sample size decreases for the less critical supports (ASME Class 2 and 3). The primary inspection method employed is visual examination. Degradation that potentially compromises support function or load capacity is identified for evaluation. Supports requiring corrective actions are examined during the next inspectiCln period in accordance with *the requirements of the ASME Boiler and Pressure Vessel Code, Section XI, Subsection IWF.* The inservice examinations conducted throughout the service life of Columbia will

• comply with the requirements of the ASME. Section XI Edition and Addenda incorporated by reference in 10 CFR 50.55a(b) twelve months prior to the start of the inspection interval, subject to prior approval of the edition and addenda by the NRC. This. is consistent with NRC statements of consideration for 10 CFR 54 associated with the adoption of new editions and addenda of the ASME Code in 10 CFR 50.55a. A.1.2.36 Lubricating Oil Analysis Program The Lubricating Oil Analysis Program manages loss of ,material due to corrosion or selective leaching of susceptible materials and reduction of heat transfer due to fouling for plant components that are within the scope of license renewal and exposed to a lubricating oil environment.

The Lubricating Oil Analysis Program is a mitigation program. The Lubricating Oil Analysis Program is supplemented by the Lubricating Oil Inspection, which provides verification of the effectiveness of the program in mitigating the effects of aging. The Lubricating Oil Analysis Program is an existing program that requires enhancement prior to the period of extended operation. Final Safety Analysis Report Supplement Page A-20 January 2010 . ** Columbia Generating Station License Renewal Application Technical Information A.1.2.37 Lubricating Oil Inspection The Lubricating Oil Inspection detects and characterizes the condition of materials in systems and components for which the Lubricating Oil Analysis Program is credited with aging management. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion or selective leaching has occurred. The inspection also determines whether a reduction in heat transfer due to fouling has occurred.The Lubricating Oil Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.38 Masonry Wall Inspection The Masonry Wall Inspection consists of inspection activities to detect cracking of masonry walls within the scope of license renewal. Masonry walls that perform a fire barrier intended function are also managed by the Fire Protection Program. The Masonry Wall Inspection is implemented as part of the Structures Monitoring Program.The Masonry Wall Inspection performs visual inspection of external surfaces of masonry walls.The Masonry Wall Inspection is an existing program that requires enhancement prior to the period of extended operation. A.1.2.39 Material Handling System Inspection Program The Material Handling System Inspection Program manages loss of material for cranes (including bridge, trolley, rails, and girders), monorails, and hoists within the scope of license renewal. The Material Handling System Inspection Program is based on guidance contained in ANSI B30.2 for overhead and gantry cranes, ANSI B30.11 for monorail systems and underhung cranes, and ANSI B30.16 for overhead hoists.The Material Handling System Inspection Program is an existing program that requires enhancement prior to the period of extended operation. A.1.2.40 Metal-Enclosed Bus Program The Metal-Enclosed Bus Program is an inspection program that detects degradation ofmetal-enclosed bus within the scope of license renewal. The program provides for the visual inspection of interior sections of bus, and an inspection of the elastomeric sealsat the joints of the duct sections. The program also makes provision for thermographic inspection of bus bolted connections. Final Safety Analysis Report Supplement Page A-21 January 2010,* *

• A.1.2.37 lubricating Oil Inspection Columbia Generating Station License Renewal Application Technical Information The Lubricating Oil Inspection detects and characterizes the condition of materials in systems and components for which the Lubricating Oil Analysis Program is credited with agil')g management.

The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion or selective leaching has occurred. The inspection also determines whether a reduction in heat transfer due to fouling has occurred. The Lubricating Oil Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 1 O-year period prior to the period of extended operation . A.1.2.38 . Masonry Wall Inspection The Masonry Wall Inspection consists of inspection activities to detect cracking of masonry walls within the scope of license renewal. Masonry walls that perform a fire barrier intended function are also managed by the Fire Protection Program. The Masonry Wall Inspection is implemented as part of the Structures Monitoring Program. The Masonry Wall Inspection performs visual inspection of external surfaces of masonry walls . The Masonry Wall Inspection is an existing program that requires enhancement prior to the period of extended operation. A.1.2.39 Material Handling System Inspection*Program The Material Handling System Inspection Program manages loss of material for cranes (including bridge, trolley, rails, and girders), monorails, and hoists within the scope of license renewal. The Material Handling System Inspection Program is based on guidance contained in ANSI 830.2 for overhead and gantry cranes, ANSI 830.11 for monorail systems and underhung cranes, and ANSI 830.16 for overhead hoists. The Material Handling System Inspection Program is an existing program that requires enhancement prior to the period of extended operation. A.1.2.40 Metal-Enclosed Bus Program The Metal-Enclosed 8us Program is an inspection program that detects degradation of metal-enclosed bus within the scope of license renewal. The program provides for the visual inspection of interior sections of bus, and an inspection of the elastomeric seals at the jOints of the duct sections. The program also makes provision for thermographic i*nspection of bus bolted connections . Final Safe,ty Analysis Report Supplement Page A-21 January 2010, Columbia Generating Station License Renewal Application Technical Information The Metal-Enclosed Bus Program is a new aging management program that will be implemented prior to the period of extended operation. The thermography portion of the program will be performed once every 10 years, with the initial inspections to be performed prior to the period of extended operation. The visual inspection portion of the program will also be performed once every 10 years, with the first inspections to be performed prior to the period of extended operation. A.1.2.41 Monitoring and Collection Systems Inspection The Monitoring and Collection Systems Inspection detects and characterizes the condition of materials at the internal surfaces of subject mechanical components that are exposed to equipment or area drainage water and other potential contaminants and fluids. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion or erosion has occurred. The inspection also determines whether cracking due to SCC of susceptible materials has occurred.The Monitoring and Collection Systems Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.42 Open-Cycle Cooling Water Program The Open-Cycle Cooling Water Program manages cracking due to SCC of susceptiblematerials and loss of material due to corrosion and erosion for components located inthe Standby Service Water and Plant Service Water systems, and for components connected to or serviced by those systems. The program manages fouling due to particulates (e.g., corrosion products) and biological material (micro- or macro-organisms) resulting in reduction in heat transfer for heat exchangers (including condensers, coolers, cooling coils, and evaporators) within the scope of the program.The Open-Cycle Cooling Water Program also manages loss of material for components associated with the feed-and-bleed mode for emergency makeup water to the spray pond.The Open-Cycle Cooling, Water Program consists of inspections, surveillances, and testing to detect the presence, and assess the extent of cracking, fouling, and loss of material. The inspection activities are combined with chemical treatments and cleaning activities to minimize the effects of aging. The program is a combination condition monitoring and mitigation program that implements the recommendations of NRC Generic Letter 89-13 for safety-related equipment in the scope of the program. The scope of the program also includes non-safety related components containing either service water or spray pond makeup water.The Open-Cycle Cooling Water Program is -an existing program that requires enhancement prior to the period of extended operation. Final Safety Analysis Report Supplement Page A-22 January 2010. Columbia Generating Station License Renewal Application Technical Information The Metal-Enclosed Bus Program is a new aging management program that will be implemented prior to the period of extended operation. The thermography portion of the program will be performed once every 1 a years, with the initial inspections to be performed prior to the period of extended operation. The visual inspection portion of the program will also be performed once every 1 a years, with the first inspections to be performed prior to the period of extended operation. A.1.2.41 Monitoring and Collection Systems Inspection The Monitoring and Collection Systems Inspection detects and characterizes the condition of materials at the internal surfaces of subject mechanical components that are exposed to equipment or area drainage water and other potential contaminants and fluids. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion or erosion has occurred. The inspection aiso determines whether cracking due to SCC of susceptible materials has occurred. \ The Monitoring and Collection Systems Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 1 a-year period prior to the period of extended operation. A.1.2.42 Open-Cycle Cooling Water Program The Open-Cycle Cooling Water Program manages cracking due to sec of susceptible materials and loss of material due to corrosion and erosion for components located in the Standby Service Water and Plant Service Water systems, and for components connected to or serviced by those systems. The program manages fouling due to particulates (e.g., corrosion products) and biological material (micro-or organisms) resulting in reduction in heat transfer for heat exchangers (including condensers, coolers, cooling coils, and evaporators) within the scope of the program. The Open-Cycle Cooling Water Program also manages loss of material for components associated with the feed-and-bleed mode for emergency makeup water to the spray pond. The Open-Cycle Cooling Water Program consists of inspections, surveillances, and testing to detect the pres'ence, and assess the extent of cracking, fouling, and loss of material. The inspection activities are combined with chemical treatments and cleaning activities to minimize the effects of aging. The program is a combination condition monitoring and mitigation program that implements the recommendations of NRC Generic Letter 89-13 for safety-related equipment in the scope of the program. The scope of the program also includes non-safety related components containing either service water or spray pond makeup water. The Open-Cycle Cooling Water Program is* an existing program that requires enhancement prior to the period of extended operation. Final Safety Analysis Report Supplement Page A-22 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information A.1.2.43 Potable Water Monitoring Program The Potable Water Monitoring Program is a mitigation program that, by means of chemical water treatment, manages loss of material due to corrosion and erosion for components that contain potable water.The Potable Water Monitoring Program is an existing program that requires enhancement prior to the period of extended operation.

At least one inspection will be conducted within the 10-year period prior to the period of extended operation. A.1.2.44 Preventive Maintenance -RCIC Turbine Casing Preventive Maintenance -RCIC Turbine Casing is an existing program that manages loss of material due to corrosion for the reactor core isolation cooling (RCIC) pump turbine casing and associated piping components downstream from the steam admission valve. These components are exposed to steam during RCIC system operation and testing, but are empty during normal plant operating conditions. Preventive Maintenance -RCIC Turbine Casing is a condition monitoring program comprised of periodic inspection and surveillance activities to detect aging and age-related degradation. A.1.2.45 Reactor Head Closure Studs Program The Reactor Head Closure Studs Program is an existing program that manages cracking due to SCC and loss of material due to corrosion for the reactor head closure stud assemblies (studs, nuts, washers, and bushings). The Reactor Head Closure Studs Program examines reactor vessel .stud assemblies in accordance with the examination and inspection, requirements specified in the ASME Boiler and Pressure Vessel Code, Section Xl, Subsection IWB (edition and addenda described in the Inservice Inspection (ISI) Program), Table IWB 2500-1. The Reactor Head Closure Studs Program includes preventive measures in accordance with Regulatory Guide 1.65 to mitigate cracking.The Reactor Head Closure Studs Program credits portions of the Inservice (ISI)-Inspection Program.A.1.2.46 Reactor Vessel Surveillance Program The Reactor Vessel Surveillance Program is an existing condition monitoring program that manages reduction of fracture toughness due to radiation embrittlement for the low, alloy steel reactor vessel shell and welds in the beltline region. The Reactor Vessel:Surveillance Program incorporates the BWRVIP Integrated Surveillance Program (ISP),, as described in reports BWRVIP-86-A and BWRVIP-1 16.Final Safety Analysis Report Supplement Page A-23 January 2010 Final Safety Analysis Repoil Supplement Page A-23 January 2010, -* *

• A.1.2.43 Potable Water Monitoring Prog'ram Columbia Generating Station License Renewal Application Technical Information The Potable Water Monitoring Program is a mitigation program that, by means of chemical water treatment, manages loss of material due to corrosion and erosion for components that contain potable water. The Potable Water Monitoring Program is an existing program that requires enhancement prior to the period of extended operation.

At least one inspection will be cqnducted within the 1 O-year period prior to the period of extended operation. A.1.2.44 Preventive Maintenance -RCIC Turbine Casing Preventive -RCIC Turbine Casing is an existing program that manages loss of material due to corrosion for the reactor core isolation cooling (RCIC) pump turbine casing and associated piping components downstream from the steam admission valve. These components are exposed to steam during RCIC system ' operation and testing, but are empty during' normal plant operating conditions. Preventive Maintenance -RCIC Turbine Casing is a condition monitoring program : comprised of periodic inspection and surveillance activities to detect aging and related degradation . A.1.2.45 Reactor Head Closure Studs Program The Reactor Head Closure Studs Program is an existing program that* manages cracking due to SCC and loss of material due to corrosion for the reactor head closure' stud assemblies (studs, nuts, washers, and bushings). The Reactor Head Closure Studs Program examines reactor vessel. stud assemblies in accordance with the' examination and inspection. requirements specified in the ASME Boiler and Pressure, Vessel Code, Section XI, Subsection IWB (edition and addenda described in the Inservice Inspection (lSI) Program), Table IWB 2500-1.' The Reactor Head Closure Studs Program includes preventive measures in accordance with Regulatory Guide: 1.65 to mitigate cracking. The Reactor Head Closure Studs Program credits portions of the Inservice (lSI)'; Inspection Program. A.1.2.46 Reactor Vessel Surveillance Program The Reactor Vessel Surveillance Program is an existing condition monitoring program that manages reduction of fracture toughness due to radiation embrittlement for the low. alloy steel reactor vessel shell and welds in the beltline region. The Reacto'r Vessel: Surveillance Program incorporates the BWRVIP Integrated Surveillance Program (ISP),. as described in reports BWRVIP-86-A and BWRVIP-116 . Final Safety Analysis Report Supplement Page A-23 January 2010; . Columbia Generating Station License Renewal Application Technical Information Energy Northwest follows the requirements of the BWRVIP ISP and applies the ISP data to Columbia. The NRC has approved the use of the BWRVIP ISP in place of a unique plant program for Columbia.The provisions of 10 CFR 50 Appendix G require Columbia to operate within the currently licensed pressure-temperature (P-T) limit curves, and to update these curves as necessary. The P-T limit curves, as contained in plant technical specifications, will be updated as necessary. through the period of extended operation as part of the Reactor Vessel Surveillance Program. Reactor vessel P-T limits will thus be managed for the period of extended operation. A.1.2.47 Selective Leaching Inspection The Selective Leaching Inspection detects and characterizes the conditions on internal and external surfaces of subject components exposed to raw water, treated water, fuel oil, soil, and moist air (including condensation) environments. The inspection provides direct evidence through a combination of visual examination and hardness testing, or NRC-approved alternative, as to whether, and to what extent, a loss of material due to selective leaching has occurred.The Selective Leaching Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.48 Service Air System Inspection The Service Air System Inspection detects and characterizes the material condition of steel piping and valve bodies exposed to an "air (internal)" (i.e., compressed air)environment within the license renewal boundary of the Service Air System. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion has occurred.The Service Air System Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.49 Small Bore Class 1 Piping Inspection The Small Bore Class 1 Piping Inspection will detect and characterize the conditions on the internal surfaces of small bore Class 1 piping components that are exposed to reactor coolant. The Small Bore Class 1 Piping Inspection will provide physical evidence as to whether, and to what extent, cracking due to SCC or to thermal or mechanical loading has occurred in small bore Class 1 piping components. The Small Bore Class 1 Piping Inspection will also verify, by inspections for cracking, that Final Safety Analysis Report Supplement Page A-24 January 201,0 Columbia Generating Station License Renewal Application

• Techni<;:al Information Energy Northwest follows the requirements of the BWRVIP ISP and applies the ISP data to Columbia.

The NRC has approved the use of the BWRVIP ISP in place of a unique plant program for Columbia. The provisions of 10 CFR 50 Appendix G require Columbia to operate within the currently licensed pressure-temperature (P-T) limit curVes, and to update these curves as necessary. The P-T limit curves, as contained in plant technical specifications, will be updated as necessary* through the period of extended operation as part of the Reactor Vessel Surveillance Program. Reactor vessel P-T limits will thus be managed for the period of extended operation. . A.1.2.47 Selective Leaching Inspection The Selective Leaching Inspection detects and characterizes the conditions on internal and external surfaces of subject components exposed to raw water, treated water, fuel oil, soil, and moist air (including condensation) environments. The inspection provides direct evidence through a combination of visual examination and hardness testing, or NRC-approved alternative, as to whether, and to what extent, a loss of material due to selective leaching has occurred. The Selective Leaching Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be

• conducted within the 1 O-year period prior to the period of extended . A.1.2.48 Service Air System Inspection I The Service Air System Inspection detects and characterizes the material condition of steel piping and valve bodies exposed to an "air (internal)" (i.e., compressed air) environment within the license renewal boundary of the Service Air System. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion has occurred.

The Service Air System Inspection is a new one-time inspection that will be implemented prior to the* period of extended operation. The inspection activities will be conducted within the 1 O-year period prior to the period of extended operation. A.1.2.49 Small Bore Class 1 Piping Inspection The Small Bore Class 1 Piping Inspection will detect and characterize the conditions on the internal surfaces of small bore Class 1 piping components that are exposed to . reactor coolant. The Small Bore Class 1 Piping Inspection will provide physical evidence as to whether, and to what extent, cracking due to SCC or to thermal or mechanical loading has occurred in small bore Class 1 piping* components. The Small Bore Class 1 Piping Inspection will also verify, by inspections for cracking, that Final Safety Analysis Report Supplement Page A-24 January 2010

• Columbia Generating Station License Renewal Application Technical Information reduction of fracture toughness due to thermal embrittlement requires no additional aging management for small bore cast austenitic stainless steel valves.The Small Bore Class 1 Piping Inspection includesvisual and volumetric inspection of a representative sample of small bore Class 1 piping components. .The inspection provides additional assurance that cracking of small bore Class 1 piping is not occurring or is insignificant, such that an aging management program is not warranted during the period of extended operation.

This one-time inspection is appropriate as Columbia has not experienced cracking of small bore Class 1 piping from stress corrosion or thermaland mechanical loading. Should evidence of significant aging be revealed by the one-time inspection or through plant operating experience, periodic inspection will be considered as a plant-specific aging management program.The Small Bore Class 1 Piping Inspection credits portions of the Inservice Inspection (ISI) Program. The Small Bore Class 1 Piping Inspection is credited to verify the effectiveness of the BWR Water Chemistry Program in mitigating cracking of small bore piping and piping components. The Small Bore Class 1 Piping Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the portion of the fourth 10-year ISI interval that occurs prior to the period of extended operation. A.1.2.50 Structures Monitoring Program The Structures Monitoring Program manages age-related degradation of plant structures and structural components within its scope to ensure that each structure or, structural component retains the ability to perform its intended function. Aging effects.are detected by visual inspection of external surfaces prior to the loss of the structure's or component's intended function. The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection and the Masonry Wall.Inspection. This program implements provisions of the Maintenance Rule, 10 CFR 50.65, that relate to structures, masonry walls, and water control structures. Concrete and masonry walls that perform a fire barrier intended function are also managed by the Fire Protection Program.The Structures Monitoring Program is an existing program that requires enhancement, prior to the period of extended operation. A.1.2.51 Supplemental Piping/Tank Inspection The Supplemental Piping/Tank Inspection detects and characterizes the material condition of steel, gray cast iron, and stainless steel components exposed to moist airýenvironments. The inspection provides direct evidence as to whether, and to what, extent, a loss of material due to corrosion has occurred.Final Safety Analysis Report Supplement Page A-25 January2010'

• Columbia Generating Station License Renewal Application Technical Information reduction of fracture toughness due, to thermal embrittlement requires no additional aging management for small bore cast austenitic stainless steel valves. The Small Bore Class 1 Piping Inspection includes visual and volumetric inspection of a representative sample of small bore Class 1 piping components. . The, inspection provides additional assurance that cracking of small bore Class 1 piping is not occurring or is insignificant, such that an aging management program is not warranted during the period of extended operation.

This one-time inspection is appropriate as Columbia has not experienced cracking of small bore Class 1 piping from stress corrosion or thermal and mechanical loading. Should evidence of significant aging be revealed by the time inspection or through plant operating experience, periodic inspection will be considered as a plant-specific aging management program. The Small' Bore Class 1 Piping Inspection credits portions of the Inservice Inspection (lSI) Program. The Small Bore Class 1 Piping Inspection is credited to verify the effectiveness of the BWR Water Chemistry Program in mitigating cracking of small bore piping and piping components. The Small Bore Class 1 Piping Inspection is a new one-time inspection that will be . implemented prior to the period of extended operation. The inspection activities will be conducted within the portion of the fourth 10-year lSI interval that occurs prior to the period of extended operation. A.1.2.S0 Structures Monitoring Program The Structures Monitoring Program manages age-related degradation of plant structures and structural components within its scope to ensure that each structure or ' structural component the ability to perform its intended function. Aging effects: ,are detected by visual inspection of external surfaces prior to the loss of the structure's: or component's intended function. The Structures Monitoring Program encompasses I and implements the Water Control Structures Inspection and the Masonry Wall i Inspection. This program implements provisions of the Maintenance Rule, I 10 CFR 50.65, that relate to structures, masonry walls, and water control structures .. Concrete and masonry walls that perform a fire barrier intended function are also m'anaged by the Fire Protection Program. The Structures Monitoring Program is an existing program that requires enhancement I prior to the period of extended operation. A.1.2.S1 Supplemental Piping/Tank Inspection The Supplemental Piping/Tank Inspection detects' and characterizes the material condition of steel, gray cast iron, and stainless steel components exposed to moist air: environments. The inspection provides direct evidence as to whether, and to what,

• extent, a loss of material due to corrosion has occurred.

Final Safety Analysis Report Supplement Page A-25 January 201 O* Columbia Generating Station License Renewal Application Technical Information The Supplemental Piping/Tank Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted within the 10-year period prior to the period of extended operation. A.1.2.52 Thermal Aging and Neutron Embrittlement of Cast Austenitic Stainless Steel (CASS) ProgramThe Thermal Aging and Neutron Embrittlement of Cast Austenitic Stainless Steel (CASS) Program will manage reduction of fracture toughness due to thermal aging and neutron irradiation embrittlement of CASS reactor vessel internals.The program includes: (a) identification of susceptible components determined to be limiting from the standpoint of thermal aging or neutron irradiation embrittlement (neutron fluence), (b) a component-specific evaluation to determine each identified component's susceptibility to reduction of fracture toughness, and (c) a supplemental examination of any component not eliminated by the component-specific evaluation. The program credits portions of the Inservice Inspection (ISI) Program and the BWR Vessel Internals Program.The Thermal Aging and Neutron Embrittlement of Cast Austenitic Stainless Steel (CASS) Program is a new aging management program that will be implemented prior to the period of extended operation. A.1.2.53 Water Control Structures InspectionThe Water Control Structures Inspection, implemented as part of the Structures Monitoring Program, consists of inspection activities to detect aging and age-related degradation. The Water Control Structures Inspection ensures the structural integrity and operational adequacy of the spray ponds, standby service water pump houses, circulating water pump house (including circulating water basin), makeup water pump house, cooling tower basins, and those structural components within the structures.The Water Control Structures Inspection is an existing program that requires enhancement prior to the period of extended operation. A.1.3 Evaluation of Time-Limited Aging Analyses In accordance with 10 CFR 54.21(c), an application for a renewed operating license requires an evaluation of TLAAs for the period of extended operation. The following TLAAs have been identified and evaluated to meet this requirement. Final Safety Analysis Report Supplement Page A-26 January 2010 Columbia Generating Station License Renewal Application

• Technical Information The Supplemental Piping/Tank Inspection is a new one-time inspection that will be implemented prior to the period of extended operation.

The inspection activities will be conducted within the 1 O-year period prior to the period of extended operation. A.1.2.52 Thermal Aging and Neutron Embrittlement of Cast Austenitic Stainless Steel (CASS) Program The Thermal Aging and Neutron Embrittlement of Cast Austenitic Stainless Steel (CASS) Program will manage reduction of fracture toughness due to thermal aging and neutron irradiation embrittlement of CASS reactor vessel internals. The program includes: (a) identification of susceptible components determined to be limiting from the standpoint of thermal aging or neutron irradiationembrittlement (neutron fluence), (b) a component-specific evaluation to determine each identified component's susceptibility to reduction of fracture toughness, and (c) a supplemental examination of any component not eliminated by the component-specific evaluation. The program credits portions of the Inservice Inspection (lSI) Program and the BWR Vessel Internals Program. The Thermal f.ging and Neutron Embrittlement of Cast Austenitic Stainless Steel (CASS) Program is a new aging management program that will be implemented prior to

• the period of extended operation.

A.1.2.53 Water Control Structures Inspection The Water Control Structures Inspection, implemented as part of the Structl:Jres Monitoring Program, consists of inspection activities to detect aging and age-related degradation. The Water Control Structures Inspection ensures the structural integrity and operational adequacy of the spray ponds, standby service water pump houses, circulating water pump house (including circulating water basin), makeup water pump house, cooling tower basins, and those structural components within the structures. The Water Control Structures Inspection is an existing program that requires enhancement prior to the period of extended operation. A.1.3 Evaluation of Time-Limited Aging Analyses In accordance with 10 CFR 54.21 (c), an application for a renewed operating license requires an evaluation of TLAAs for the period of extended operation. The following TLAAs have been identified and evaluated to meet this requirement. Final Safety Analysis Report Supplement Page A-26 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information A.1.3.1 Reactor Vessel Neutron Embrittlement Neutron embrittlement is the change in mechanical properties of reactor vessel materials resulting from exposure to fast neutron flux (E>1.0. MeV) in the beltline region of the reactor core. The most pronounced material change is a reduction in fracture toughness.

As fracture toughness decreases with cumulative fast neutron exposure,the material's resistance to crack propagation decreases. Fracture toughness is also dependent on temperature. The reference temperature for nil-ductility transition (RTNDT)is the temperature above which the material behaves in a ductile manner and below which the material behaves in a brittle manner. As fluence increases, RTNDT increases, and higher temperatures are required for the material to continue to act in a ductile manner.Requirements associated with fracture toughness, pressure-temperature limits, and material surveillance programs for the reactor coolant pressure boundary are contained in Appendices G and H of 10 CFR 50.The analyses associated with evaluation of the effect of neutron embrittlement on the reactor pressure vessel for 40 years are TLAAs. Neutron fluence, upper shelf energy, adjusted reference temperature (ART), and vessel P-T limits are time dependent parameters associated with fracture toughness (embrittlement) of reactor vessel materials. A.1.3.1.1 Neutron Fluence EFPY Proiection To evaluate the effects of radiation on reactor pressure vessel material embrittlement, the results of analyses were projected to determine neutron fluence out to 54 effective full power years (EFPY). Using actual reactor core power histories through 2007 and conservative estimates of future core designs, extended operation to 60 years was determined to be bounded by 54 EFPY.Fluence Proiection Analyzed fluence values at 51.6 EFPY of reactor operation are addressed in FSAR Section 4.3.2.8 and FSAR Table 4.3-1. These fluence analyses are based on the original licensed thermal power of 3323 mega-watt thermal (MWt) through fuel cycle 10, and the currently licensed thermal power uprated to 3486 MWt from cycle 11 throughthe end of operation. These fluence analyses use NRC-approved methodology based on the guidance of Regulatory Guide 1.190, "Calculational and Dosimetry Methods for Determining Pressure Vessel Neutron Fluence." The fluence analyses were projectedto 54 EFPY for the extended operating period of 60 years.Final Safety Analysis Report Supplement P Page A-27 January 2010* *

• A.1.3.1 Reactor Vessel Neutron Embrittlement Columbia Generating Station License Renewal Application Technical Information Neutron embrittlement is the change in mechanical properties of reactor vessel materials resulting from exposure to fast neutron flux (E>1.0 MeV) in the beltline region of the reactor core. The most pronounced material change is a reduction in fracture toughness.

As fracture! toughness decreases with cumulative fast neutron exposure, the material's resistance to crack propagation decreases. Fracture toughness is also dependent on temperature. The reference temperature for nil-ductility transition (RT NOT) is the temperature above which the material behaves in a ductile manner and below . which the material behaves in a brittle manner. As fluence increases, RT NOT increases; and higher temperatures are required for the material to continue to act in a ductile manner. Requirements associated with fracture toughness, pressure-temperature limits, and ' material surveillance programs for the reactor coolant pressure boundary are contained . in Appendices G and H of 10 CFR 50. The analyses associated with evaluation of the effect of neutron embrittlement on the ' reactor pressure vessel for 40 years are TLAAs. Neutron fluence, upper shelf energy, ' adjusted reference temperature (ART), and vessel P-T limits are time dependent; parameters associated with fracture toughness (embrittlement) of reactor vessel i materials. . , A.1.3.1.1 Neutron Fluence EFPY Projection To evaluate the effects of radiation on reactor pressure vessel material embrittlement, . the results of analyses were projected to determine neutron fluence out to 54 effective full power years (EFPY). Using actual reactor core power histories through 2007 and conservative e.stimates of future core designs, extended operation to 60 years was determined to be bounded by 54 EFPY. Fluence Projection Analyzed fluence values at 51.6 EFPY of reactor operation are addressed in FSAR' Section 4.3.2.8 and FSAR Table 4.3-1. These fluence analyses are based on the original licensed thermal power of 3323 mega-watt thermal (MWt) through fuel cycle 10, and the currently licensed thermal power uprated to 3486 MWt from cycle 11 through* the end of operation. These fluence analyses use NRC-approved methodology based on the guidance of Regulatory Guide 1.190, "Calculational and Dosimetry Methods for Determining Pressure Vessel Neutron Fluence." The fluenceanalyses were projected to 54 EFPY for the extended operating period of 60 years . Final Safety Analysis Report Supplement . Page A-27 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Beltline Evaluation For the extended operating period, ferritic materials for vessel beltline shells, welds, and assembly components are required to be evaluated for neutron irradiation embrittlement if high energy neutron fluence is greater than a threshold value of 1E+17 n/cm 2 (E >1 MeV) at the end of the 60 years. The only vessel assembly items, other than the shells and welds of the beltline region that would experience neutron fluence greater than 1E+17 n/cm 2 during the period of extended operation are instrumentation nozzle N12 and residual heat removal/low pressure coolant injection (RHR/LPCI) nozzle N6.Instrumentation nozzle N12 has a thickness less than 2.5 inches and therefore does not require a fracture toughness evaluation per ASME Code Appendix G, Section G2223.Nozzle N6 is evaluated for ART below. The ART for this nozzle is less than that for the highest weld and plate. Consequently, nozzle N6 is not the limiting material for the vessel, and thus is not a beltline component. However, as nozzle N6 was evaluated for ART it meets the definition of a beltline component per 10 CFR 50, Appendix G.The beltline definition for the period of extended operation includes the lower shell (Course #1 / Ring #21), lower-intermediate.shell (Course #2 / Ring #22), associated vertical (longitudinal) welds, the girth (circumferential) weld that connects the lower and lower-intermediate shells, and nozzle N6.Disposition Neutron fluence is not a TLAA, it is a time-limited assumption used in various neutron embrittlement TLAAs.A.1.3.1.2 Upper Shelf Energy Evaluation 10 CFR 50 Appendix G requires the upper shelf energy (USE) of the vessel beltline materials to remain above 50 ft-lb at all, times during plant operation, including the effects of neutron radiation. If USE cannot be shown to remain above this limit, then an equivalent margin analysis (EMA) must be performed to show that the margins of safety against fracture are equivalent to those required by Appendix G of Section Xl of the ASME Code.The initial (unirradiated) USE is not known for all the Columbia vessel plates and welds.For those plates and welds for which the initial USE is known, USE was projected using Regulatory Guide 1.99, Revision 2 methods. For the vessel plates and welds for which the initial USE is not known, USE equivalent margin analyses were performed using the Boiling Water Reactor Owners Group (BWROG) equivalent margin analysis (EMA)methodology. Results from the testing and analysis of surveillance materials were used in the EMA analyses.Final Safety Analysis Report Supplement Page A-28 January 2010 Final Safety Analysis Report Supplement Page A-28 .January 2010 Columbia Generating Station License Renewal Application

• Technical Information Beltline Evaluation For the extended operating period, ferritic materials for vessel beltline shells, welds, and assembly components are required to be evaluated for neutron irradiation embrittlement if high energy neutron fluence is greater than a threshold value of 1 E+17 n/cm 2 (E >1 MeV) at the end of the 60 years. The only vessel assembly items, other than the shells and welds of the beltline region that would experience neutron fluencegreater than 1E+17 n/cm 2 during the period of extended operation are instrumentation nozzle N12 and residual heat removal/low pressure coolant injection (RHR/LPCI) nozzle N6. Instrumentation nozzle N12 has a thickness less than 2.5 inches and therefore does not require a fracture toughness evaluation per ASME Code Appendix G, Section G2223. Nozzle N6 is evaluated for ART below. The ART for this nozzle is less than that for the highest weld and plate. Consequently, nozzle N6 is not the limiting material for the vessel, and thus is not a beltline component.

However, as nozzle N6 was evaluated for ART it meets the definition of a beltline component per 10 CFR 50, Appendix G. The beltline definition for the period of extended operation includes the lower shell (Course #1 I Ring #21), lower-intermediate .shell (Course #2 I Ring #22), associated vertical (longitudinal) welds, the girth (circumferential) weld that connects the lower and lower-intermediate shells, and nozzle N6. Disposition Neutron fluence is not a TLAA, it is a time-limited assumption used in various neutron embrittlement TLAAs. . A.1.3.1.2 Upper Shelf Energy Evaluation 10 CFR 50 Appendix G requires the upper shelf energy (USE) of the vessel beltline materials to remain above 50 ft-Ib at all'times during plant operation, including the effects of neutron radiation. If USE cannot be shown to remain above this limit, then an equivalent margin analysis (EMA) must be performed

• to show that the margins of safety against fracture are equivalent to those required by Appendix G of Section X.I of the ASME Code. The initial (un irradiated)

USE is not known for all the Columbia vessel plates and welds. For those plates and welds for which the initial USE is known, USE was projected using Regulatory Guide 1.99, Revision 2 methods. For the vessel plates and welds for which the initial USE is not known, USE equivalent margin analyses were performed using the Boiling Water Reactor Owners Group (BWROG) equivalent margin analysis (EMA) methodology. Results from the testing and analysis of surveillance materials were used in the EMA analyses. . . Final Safety Analysis Report Supplement Page A-28

• January 2010 .. *
• Columbia Generating Station License Renewal Application Technical Information All of the projected USE values for the vessel beltline plates and welds for which the initial USE is known remain above 50 ft-lbs through the-end of the period of extended operation (54 EFPY). For the vessel beltline plates and welds for which the initial USE is not known, the maximum decrease in USE was found to be less than the assumed decrease in the associated equivalent margin analyses.

The maximum predicted decreases in USE for 54 EFPY for these beltline plates and welds are bounded by the equivalent margin analyses. Therefore, the projected USE for the vessel beltline plates and welds is acceptable, for the period of extended operation. Disposition Reactor vessel upper shelf energy TLAAs have been projected to the end of the period of extended operation. A.1.3.1.3 Adjusted Reference Temperature Analysis In addition to USE, the other key parameter that characterizes the fracture toughness of a material is the RTNDT. This reference temperature changes as a function of exposure to neutron radiation resulting in an adjusted reference temperature, ART.The initial RTNDT is the reference temperature for the unirradiated material. The change due to neutron radiation is referred to as ARTNDT. The ART is calculated by adding the initial RTNDT, the ARTNDT, and a margin to account for uncertainties as prescribed in Regulatory Guide 1.99, Revision 2.The ART evaluations of record for the vessel beltline plates and welds for the currently licensed period (33.1 EFPY) include power uprate conditions. Based on projected fluence values, the methodology in Regulatory Guide 1.99 was used to project the ART for 54 EFPY. The ART values projected to 54 EFPY are used to develop P-T limit curves. Projected ART values are well below the 200°F end of life ART suggested in Section 3 of Regulatory Guide 1.99 and are, thus, acceptable for the period of extended operation., Disposition Reactor vessel adjusted reference temperature TLAAs have been projected to the end of the period of extended operation. A. 1.3.1.4 Pressure-Temperature Limits To ensure that adequate margins of safety are maintained for various modes of reactor*operation, 10 CFR 50, Appendix G specifies pressure and temperature requirements for'affected materials for the service life of the reactor vessel. The basis for these fracture toughness requirements is ASME Section XI, Appendix G. The ASME Code requires-; P-T limits be established for hydrostatic pressure tests and leak tests; for operation with the core not critical during heatup and cooldown; and for core critical operation. Final Safety Analysis Report Supplement Page A-29 January 2010* *

• Columbia Generating Station I License Renewal Application Technical Information All of the projected USE values for the vessel beltline plates and welds for which the initial USE is known remain above 50 ft-Ibs through the end of the period of extended ' operation (54 EFPY). For the vessel beltline plates and welds for which the initial USE is not known, the maximum decrease in USE was found to be less than the assumed decrease in the associated equivalent margin analyses.

The maximum predicted decreases in USE for 54 EFPY for these beltline plates and welds are bounded by the equivalent margin analyses. Therefore, the projected USE for the vessel beltline plates ! and welds is acceptable' for the period of extended operation. Disposition Reactor vessel upper sl1elf energy TLAAs have been projected to the end of the period of extended operation. . A.1.3.1.3 Adjusted Reference Temperature Analysis In addition to USE, the other key parameter that characterizes the fracture toughness of . a material is the RT NOT. This reference temperature changes as a function of exposure: to neutron radiation resulting in an adjusted reference temperature, ART. . , , The initial RT NOT is the reference temperature for the unirradiated material. The change due to neutron radiation is referred to as* NOT. The ART is calculated by adding the initial RT NOT, the NOT, and a margin to account for uncertainties as prescribed in Regulatory Guide 1.99, Revision 2. I The ART evaluations of record for the vessel beltline plates and welds for the currently i licensed period (33.1 EFPY) include power uprate conditions. Based on projected: fluence values, the methodology in Regulatory Guide 1.99 was used to project the ART; for 54 EFPY. The ART values projected to 54 EFPY are used to develop P-T limit i curves. Projected ART values are well below the 200°F end of life ART suggested in I . .. I Section 3 of Regulatory Guide 1.99 and are, thus, acceptable for the period of extended! operation., ' Disposition Reactor vessel adjusted reference temperature TLAAs have been prOjected to the end I of the period of extended operation. . : A.1.3.1.4 Pressure-Temperature Limits To ensure that adequate margins of safety are maintained for various modes of reactor . operation, 10 CFR 50, Appendix G specifies pressure and temperature requirements for: affected materials for tl1e service life of the reactor vessel. The basis for these fracture: toughness requirements is ASME Section XI, Appendix G. The ASME Code requires' P-T limits be establisheld for hydrostatic pressure tests and leak tests; for operation with: the core not critical during heatup and cooldown; and for core critical operation . Final Safety Analysis Repo/1 Supplement Page A-29 January 2010 Columbia Generating Station License Renewal Application Technical InformationThe Columbia P-T limit curves were revised in 2005 to include the effects of power uprate to 3486 MWt. The P-T limits are valid for 33.1 EFPY through the end of the currently licensed period. P-T limits for the period of extended operation will be calculated using the most accurate fluence projections available at the time of the recalculation. The projections may be adjusted if there are changes in core design or if additional surveillance capsule results show the need for an adjustment. The projected ART for the period of extended operation gives confidence that future P-T curves will provide adequate operating margin.License amendment requests to revise the P-T limits will be submitted to the NRC for approval, when necessary to comply with 10 CFR 50 Appendix G, as part of the Reactor Vessel Surveillance Program.Disposition The TLAA for P-T limits will be adequately managed for the period of extended operation as part of the Reactor Vessel Surveillance Program. A. 1.3.1.5 Reactor Vessel Circumferential Weld Inspection Relief BWRVIP-74-A, "BWR Vessel and Internals Project, BWR Reactor Pressure Vessel Inspection and Flaw Evaluation Guidelines for License Renewal," reiterated the recommendation of BWRVIP-05, "BWR Vessel and Internals Project, BWR Reactor Pressure Vessel Shell Weld Inspection Recommendations," that vessel circumferential welds could be exempted from examination. The NRC safety evaluation report (SER)for BWRVIP-74 agreed, but required that plants apply for this relief request individually. The relief request is required to demonstrate that at the expiration of the current license, the circumferential welds will satisfy the limiting conditional failure probability in the (BWRVIP-05) evaluation. Energy Northwest requested and received permanent relief from vessel shell circumferential (girth) weld volumetric examinations through 33.1 EFPY.The reactor pressure vessel circumferential weld parameters at 54 EFPY have been projected to remain within the 'bounding (64 EFPY) vessel parameters from the BWRVIP-05 SER. As such, the conditional probability of failure for circumferential welds remains below the limits contained in the SER for BWRVIP-05. Disposition The TLAA for reactor vessel circumferential weld examination relief has been projected to the end of the period of extended operation. A. 1.3.1.6 Reactor Vessel Axial Weld Failure Probability The NRC SER for BWRVIP-74-A evaluated the failure frequency of axially oriented welds in BWR reactor vessels, and determined failure frequency acceptance criteria for 40 years of reactor operation. Applicants for license renewal are required to evaluate Final Safety Analysis Report Supplement Page A-30 January 2010 Columbia Generating Station License Renewal Application Technical Information The Columbia P-T limit curves were revised in 200S to include the effects of power uprate to 3486 MWt. The P-T limits are valid for 33.1EFPY through the end of the currently licensed period. P-T limits for the period of extended operation will be calculated using the most accurate fluence projections available at the time of the recalculation. The projections may be adjusted if there are changes in core design or if additional surveillance capsule results show the need for an adjustment. The projected ART for the period of extended operation gives confidence that future P-T curves will provide adequate operating margin. License amendment requests to revise the P-T limits will be submitted to the NRC for approval, when necessary to comply with 10 CFR SO Appendix G, as part of the Reactor Vessel Surveillance Program. Disposition The TLAA for P-T limits will be adequately managed for the _ period of extended operation as part of the Reactor Vessel Surveillance Program. A.1.3.1.S Reactor Vessel Circumferential Weld Inspection Relief

• BWRVIP-74-A, "BWR Vessel and Internals Project, BWR Reactor Pressure Vessel Inspection and Flaw Evaluation Guidelines for License Renewal," reiterated the recommendation of BWRVIP-OS, "BWR Vessel and Internals Project, BWR Reactor
• Pressure Vessel Shell Weld Inspection Recommendations," that vessel circumferential . welds could be exempted from examination.

The NRC safety evaluation report (SER) for BWRVIP-74 agreed, but required that plants apply for this relief request individually. The relief request is required to demonstrate that at the expiration of the current license, the circumferential welds will satisfy the limiting conditional failure probability in the (BWRVIP-OS) evaluation .. Energy Northwest requested and received permanent relief* from vessel shell circumferential (girth) weld volumetric examinations through 33.1 EFPY. The reactor pressure vessel circumferential weld parameters at S4 EFPY have been projected to remain within the \bounding (64 EFPY) vessel parameters from the BWRVIP-OS SER. As such, the conditional probability of failure for circumferential* welds remains below the limits contained in the SER for BWRVIP-OS. Disposition The TLAA for reactor vessel circumferential weld examination relief has been projected to the end of the period of extended operation .. . A.1.3.1.6 Reactor Vessel Axial Weld Failure Probability The NRC SER for BWRVIP-74-Aevaluated the failure frequency of axially oriented welds in BWR reactor vessels, and determined failure frequency acceptance criteria for 40 years of reactor operation. Applicants for license renewal are required to evaluate Final Safety Analysis Report Supplement Page "A-30 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information axially oriented vessel welds to show that their failure frequency remains below the acceptance criteria in the SER for BWRVIP-74.

An acceptable way to do this is to show that the mean RTNDT of the limiting axial beltline weld at the end of the period of extended operation is less than the values specified in the SER.The Columbia limiting axial weld mean RTNDT at 54 EFPY is projected to remain well below the RTNDT from the SER for BWRVIP-74, thus the Columbia axial weld failure frequency meets the acceptable criteria.Disposition The TLAA for the reactor vessel axial weld failure probability has been projected to the end of the period of extended operation. A.1.3.2 Metal Fatigue Fatigue evaluations for mechanical components are identified as TLAAs; therefore, the effects of fatigue must be addressed for license renewal. Fatigue is an age-related degradation mechanism caused by cyclic duty on a component by either mechanical or thermal loads.The ASME Boiler and Pressure Vessel Code requires evaluation of transient thermal and mechanical load cycles for Class 1 components. Cumulative usage factors for Class 1 components are calculated based on normal and upset design transient definitions. The design transients used to generate cumulative usage factors for Class 1 components are contained in FSAR Section 3.9.1.1. Columbia is required to.monitor design transients listed in FSAR Table 3.9-1 to ensure that plant components are maintained within the design limits.Calculation of fatigue usage values is not required for non-Class 1 SSCs. Instead, stress intensification factors and lower stress allowables are used to ensure components are adequately designed for fatigue.The reactor coolant environmental effects of fatigue on plant components were also evaluated.' The design cycles for Columbia are summarized in FSAR Section 3.9 and FSAR Table 3.9-1. Columbia counts all fatigue significant cycles, not only for the design transients listed in FSAR Table 3.9-1 but also for the analysis of other plant components. The events listed in FSAR Table 3.9-1 have been evaluated and in some cases regrouped for easier counting. Faulted conditions listed in the FSAR are not used in the fatigue analyses and are not counted. Additional transients determined to be fatigue significant-after the original design have been added to the counting procedure, while FSAR Table 3.9-1 lists the original design cycles. The projected number of occurrences of design'transients to 60 years determined that some analyzed numbers of transients may be Final Safety Analysis Report Supplement Page A-31 January 2010,* * '. Columbia Generating Station License Renewal Application Technical Information axially oriented vessel welds to show that their failure frequency remains below the acceptance criteria in the SER for BWRVIP-74, An acceptable way to do this is to show that the mean RT of the limiting axial beltline weld at the end of the period of extended operation is less than the values specified in the SER. The Columbia limiting axial weld mean RT NOT at 54 EFPY is projected to remain well below the RT NOT from the SER for BWRVIP-74, thus the Columbia axial weld failure frequency meets the acceptable criteria. Disposition . The TLAA for the reactor vessel axial weld failure probability has been projected to the end of .the period of extended operation, J A.1.3.2 Metal Fatigue Fatigue evaluations for mechanical components are identified as TLAAs; therefore, the effects of fatigue must be addressed for license renewal. Fatigue is an age-related degradation mechanism caused by cyclic duty on a component by either mechanical or thermal loads. The ASME Boiler and Pressure Vessel Code requires evaluation of transient thermal' and mechanical load cycles for Class 1 components, Cumulative usage, factors for Class 1 components are calculated based on normal and upset design transient definitions. The design transients used to generate cumulative usage factors for Class' 1 components are contained in FSAR Section 3,9.1.1. Columbia is required to .monitor ' design transients listed in FSAR Table 3.9-1 to ensure that plant components are: maintained within the design limits. ' . Calculation of fatigue usage values is not required for non-Class 1 SSCs. Instead,; stress intensification factors and lower stress allowables are 'used to ensure;' components are adequately designed for fatigue. i ' The reactor coolant environmental effects of fatigue on plant' components were also! evaluated, , . , The design cycles for Columbia are summarized in FSAR Section 3,9 and FSAR Table 3.9-1. Columbia counts all fatigue significant cycles, not only for the design transients listed in FSAR Table 3.9-1 but also for the analysis of other plant components, The events listed in FSAR Table 3.9-1 have been evaluated and in some cases regrouped for easier counting. Faulted conditions listed in the FSAR are not used in the fatigue analyses and are not counted. Additional transients determined to be fatigue significant' after the original design have been added to the counting procedure, while FSAR Table 3.9-1 lists the original design cycles. The projected number of occurrences of design' transients to 60 years determined that some analyzed numbers of transients may be Final Safety Analysis Repol1 Supplement Page A*31 , January 2010, Columbia Generating Station License Renewal Application Technical Information exceeded. These projections were done using linear extrapolation from the beginning of plant life. Recent operating experience suggests lower projections and as additional operating data is accumulated, subsequent projections will refine the number of cycles expected in 60 years. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached.A.1.3.2.1 Reactor Pressure Vessel Fatigue Analyses The reactor vessel assembly consists of the reactor pressure vessel (RPV), the vessel support skirt, the shroud support, nozzles, penetrations, stub tubes, head closure flanges, head closure studs, refueling bellows support, and stabilizer brackets.Design cumulative usage factors (CUFs) for the limiting RPV assembly locations are contained in design reports and were calculated based on the design transients. Columbia manages fatigue for the RPV assembly components using the Fatigue Monitoring Program to track transient cycles and requires corrective action before any analyzed number of cycles is reached.Disposition The effects of aging on the intended functions of the RPV will be adequately managed for the period of extended operation by the Fatigue Monitoring Program.A.1.3.2.2 Reactor Pressure Vessel Internals Fatigue analyses of the overall RPV internals (including the jet pump assemblies) were performed pre-startup as part of the plant design. Component specific fatigue analyses of the jet pumps were performed more recently to bound actual plant operation. Each of these analyses is discussed below.Reactor Vessel Internals Fatigue Analyses The RPV internals are described in terms of two assemblies: core support structures and reactor internals. Core support structures include the shroud,. shroud support (included as part of the reactor vessel for fatigue), core plate with wedges and hold-down bolts, top guide, fuel supports, and control rod guide tubes. Reactor internals include the jet pump assemblies, jet pump instrumentation, feedwater spargers, vessel head spray nozzle, differential pressure line, incore flux monitor guide tubes, surveillance sample holders, core spray line (in-vessel) and spargers, incore instrument housings, low pressure coolant injection coupling, steam dryer, shroud head and steam separator assembly, guide rods,'and control rod drive thermal sleeves.The normal, test, and upset service load cycles used for the design and fatigue analysis for the core support structures and reactor internals are shown in FSAR Table 3.9-1.Calculation of CUFs for the reactor internals was performed as part of a NSSS design evaluation. Final Safety Analysis Report Supplement Page A-32 January 2010 Columbia Generating Station License Renewal Application Technical Information exceeded. These projections were done using linear extrapolation from the beginning of plant life. Recent operating experience suggests lower projections and as additional operating data is accumulated, subsequent projections will refine the number of cycles expected in 60 years. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached. A.1.3.2.1 Reactor Pressure Vessel Fatigue Analyses The reactor vessel assembly consists of the reactor pressure vessel (RPV), the vessel support skirt, the shroud support, nozzles, penetrations, stub tubes, head closure flanges, head closure studs, refueling bellows support, and stabilizer brackets. Design cumulative usage factors (CUFs) for the limiting RPV locations are contained in design reports and were calculated based on the design transients. Columbia manages fatigue for the. RPV assembly components using the Fatigue Monitoring Program to track transient cycles and requires corrective action before any analyzed number of cycles is reached. Disposition

• The effects of aging on the intended functions of the RPV will be adequately managed for the period of extended by the Fatigue Monitoring Program.
• A.1.3.2.2 Reactor Pressure Vessel Internals Fatigue analyses of the overall RPV internals (including the jet pump assemblies) were performed pre-startup as part of the plant design. Component specific fatigue analyses of the jet pumps were performed more recently to bound actual plant operation.

Each of these analyses is discussed below. Reactor Vessel Internals Fatigue Analyses The RPV internals are described in terms of two assemblies: core support structures and reactor internals. Core support structures include the shroud, shroud support (included as part of the reactor vessel for fatigue), core plate with wedges and down bolts, top guide, fuel supports, and control rod guide tubes. Reactor internals include the jet pump assemblies, jet pump instrumentation, feedwater spargers, vessel head spray nozzle, differential pressure line, incore flux monitor guide tubes, surveillance sample holders, core spray line (in-vessel) and spargers, incore instrument housings, low pressure coolant injection coupling, steam dryer, shroud head and steam separator assembly, guide rods, 'and control rod drive thermal sleeves. . The normal, test, and upset service load cycles used for the design and fatigue analysis for the core support structures and reactor internals are shown in FSAR Table 3.9-1. Calculation of CUFs for the reactor internals was performed as part of a NSSS design evaluation. Final Safety Analysis Report Supplement Page A-32 January 2010 * \ Columbia Generating Station License Renewal Application Technical Information Review of the RPV internals in association with power uprate determined that stresses on the vessel internals remained well below all limits. No recalculation of cumulative usage factors was determined to be required. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached.Disposition The effects of aging on the intended functions of the RPV internals will be adequately managed for the period of extended operation by the Fatigue Monitoring Program.Jet Pump Fatigue Analyses In August 2000, Columbia operated for a period of time with the recirculation pumps in an unbalanced mode (pump speeds different by more than 50 percent). The effect of that flow imbalance on the jet pumps was an additional accumulation of fatigue usage.As a result of inspections during the Spring 2001 outage (R-15), a fatigue analysis of the jet pumps was performed and cumulative usage factors were determined. Jet pump clamps were installed during the 2005 outage (R-17) to minimize flow induced vibration. These clamps greatly reduced the future potential for riser brace fatigue.As a result of evaluations after the 2007 outage the usage factors were extended to 60 years. The maximum CUF of the jet pump risers for 60 years of operation is projected to remain below the fatigue limit. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before anyanalyzed number of cycles is reached. The Fatigue Monitoring Program will also monitor the occurrence of design cycles and will monitor the jet pump gaps, effectively managing the fatigue of the jet pumps through the period of extended operation. Disposition The effects of aging on the intended functions of the jet pumps will be, adequately managed for the period of extended operation by the Fatigue Monitoring Program.A.1.3.2.3 Reactor Coolant Pressure Boundary Piping and Piping ComponentFatigue Analyses The Class 1 boundary encompasses all reactor coolant pressure boundary piping (pipe and fittings) and in-line components subject to ASME Section Xl, Subsection IWB, inspection requirements. Fatigue analyses of Class 1 piping are based on the.transients found in the Columbia piping specifications that are in turn based on the design transients listed in FSAR Section 3.9.Potential high energy line break (HELB) intermediate locations can be eliminated based'on CUFs of less than 0.1 if other stress criteria are also met. The usage factors, as Final Safety Analysis Report Supplement Page A-33 January 2010:* *

• Columbia Generating Station License Renewal Application Technical Information Review of the RPV internals in association with power uprate determined that stresses on the vessel internals remained well below all limits. No recalculation of cumulative usage factors was determined to be required.

Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached. Disposition The effects of aging on the intended functions of the RPV internals will be adequately managed for the period of extended operation by the Fatigue Monitoring Program. Jet Pump Fatigue Analyses In August 2000, Columbia operated for a period of time with the recirculation pumps in an unbalanced mode (pump speeds different by more than 50 percent). The effect of ; that flow imbalance on the jet pumps was an additional accumulation of fatigue usage. As a result of inspections during the Spring 2001 outage (R-15), a fatigue analysis of I the jet pumps was performed and cumulative usage factors were determined. ! " I Jet pump clamps were installed during the 2005 outage (R-17) to minimize flow induced I vibration. These clamps greatly reduced the future potential for riser brace fatigue. . As a result of evaluations after the 2007 outage the usage factors were extended to 60' years. The maximum CUF of the jet pump risers for 60 years of operation is projected to remain below the fatigue limit. Columbia manages fatigue using the Fatigue Monitoring Program to track transient cycles and require corrective action before any analyzed number of cycles is reached. The Fatigue Monitoring Program will also' monitor the occurrence of design cycles and will monitor the jet pump gaps, effectively managing the fatigue of the jet pumps through the period of extended operation. Disposition The effects of aging on the intended functions oJ the jet pumps will be" adequately managed for the period of extended operation by the Fatigue Monitoring Program. A.1.3.2.3 Reactor Coolant Pressure Boundary Piping and Piping Component Fatigue Analyses. The Class 1 boundary encompasses all reactor coolant pressure boundary piping (pipe and fittings) and in-line components subject to ASME Section XI, Subsection" IWB, inspection requirements. Fatigue analyses of Class 1 piping are based oli the. transients found in the Columbia piping specifications that are in turn based on the design transients listed in FSAR Section 3.9. Potential high energy line break (HELB) intermediate locations can be eliminated based on CUFs of less than 0.1 if other stress criteria are also met. The usage factors,' as Final Safety Analysis Report Supplement Page A-33 January 2010 Columbia Generating Station License Renewal Application Technical Information calculated in the design fatigue analyses, account for the design transients assumed for the original 40-year life of the plant. Therefore, the determination of CUFs used in the selection of postulated high energy line intermediate break locations are TLAAs. The Fatigue Monitoring Program will identify when the transients for piping systems are approaching their analyzed number of cycles. Prior to any transient exceeding its analyzed number of cycles for a piping system, the associated analyses will be reviewed to determine whether any additional locations need to be designated as postulated HELB locations. All Class 1 piping was reviewed for the power uprate. The evaluation determined that there was adequate margin in each system to accommodate the power uprate. Design fatigue usage for 40 years of operation and projected fatigue usage for the period of extended operation are established for the limiting reactor coolant pressure boundary components. A review of documentation found several fatigue analyses for Class 1 valve stress reports found fatigue analyses that were TLAAs. The fatigue usage for those valves is based on transients that are tracked by the Fatigue Monitoring Program.Metal fatigue for all Class 1 reactor coolant pressure boundary piping and in-line components is managed by the Fatigue Monitoring Program. The Fatigue Monitoring Program will identify when the transients for piping systems are approaching their analyzed numbers of cycles. Prior to any transient exceeding its analyzed number of cycles for a piping system, the design calculations for that system will be reviewed andappropriate actions will be taken.Disposition The effects of aging on the intended functions of the reactor coolant pressure boundary piping and components will be adequately managed for the period of extended operation by the Fatigue Monitoring Program.A.1.3.3 Non-Class 1 Component Fatigue Analyses The non-Class 1 mechanical components susceptible to fatigue fit into one of two major categories: (1) piping and in-line components (piping, valves, tubing, traps, thermowells,etc.) or (2) non-piping components (vessels, heat exchangers, tanks, pumps, etc.).Non-Class 1-components that are Quality Group B or C are designed and constructed as ASME Section III Code Class 2 and 3, respectively. The design of ASME Class 2 and 3 piping systems incorporates a stress range reduction factor for determining acceptability of piping design with respect to thermal stresses. Non-Class 1 components designated as Quality Class D are designed to ANSI B31.1, which also incorporates stress range reduction factors based upon the number of thermal cycles.In general, a stress range reduction factor of 1.0 in the stress analyses applies for up to Final Safety Analysis Report Supplement Page A-34 January 2010 Columbia Generating Station License Renewal Application Technical Information . calculated in the design fatigue analyses, account for the design transients assumed for the original 40-year life of the plant. Therefore, the determination of CUFs used in the selection of postulated high energy line intermediate break locations are TLAAs. The Fatigue Mqnitoring Program will identify when the transients for piping systems are approaching their analyzed number of cycles. Prior to any transient exceeding its analyzed number of cycles for a piping system, the associated analyses will be reviewed to determine whether any additional locations need to be designated as postulated HELB locations. All Class 1 piping was reviewed for the power uprate. The evaluation determined that there was adequate margin in each system to accommodate the power uprate. Design fatigue usage for 40 years of operation and projected fatigue usage for the period of extended operation are established for the limiting reactor coolant pressure boundary components. A review C?f documentation found several fatigue analyses for Class 1 valve stress reports found fatigue analyses that TLAAs. The fatigue usage for those valves is based on transients that are tracked by the Fatigue Monitoring Program. Metal fatigue for all Class 1 reactor coolant pressure boundary piping and in-line . components is managed by the Fatigue Monitoring Program. The Fatigue' Monitoring Program will identify when the transients for piping systems are approaching their

• analyzed numbers of cycles. Prior to any transient exceeding its analyzed number of cycles for a piping system, the design calculations for that system will be reviewed and appropriate actions will be taken. Disposition The effects of aging on the intended functions of the reactor coolant pressure boundary piping and components will be adequately managed for the period of extended operation by the Fatigue Monitoring Program. A.1.3.3 Non-Class 1 Component Fatigue Analyses The non-Class 1 mechanical components susceptible to fatigue fit into one of two major categories:

(1) piping and in-line components (piping, valves, tubing, traps, thermowells, etc.) or (2) non-piping components (vessels, heat exchangers, tanks, pumps, e,tc.). Non-Class 1* components that are Quality Group B or C are designed and constructed as ASME Section III Code Class 2 and 3, respectively. The design of ASME Class 2 and 3 piping systems incorporates a stress range reduction factor for determining acceptability of piping design with respect to thermal stresses. Non-Class 1 components designated as Quality Class D are designed to ANSI B31.1, which also incorporates stress range reduction factors based upon the number of thermal cycles. In general, a stress range reduction factor of 1.0 in the stress analyses applies for up to Final Safety Analysis Report Supplement Page A-34 January 2010 .' Columbia Generating Station License Renewal Application Technical Information7,000 thermal cycles. The allowable stress range is reduced by the stress range reduction factor if the number of thermal-cycles exceeds 7,000. If fewer than 7,000 cycles are expected through the period of extended operation, then the fatigue analysis (stress range reduction factor) of record will remain valid through the period of extended operation. Because none of the non-Class 1 vessels, heat exchangers, storage tanks, or pumps were designed to ASME Section VIII, Division 2 or ASME Section III, Subsection NC-3200, no fatigue evaluation is required. Therefore, there are no fatigue TLAAs for these components. The fatigue evaluation of non-Class 1 piping and in-line components evaluated the associated operating temperature against the threshold temperature value for fatigue of the material. If the threshold temperature value was exceeded, then the number of transient cycles for the piping or in-line component was projected. In each case, the number of projected cycles for 60 years was found to be less than 7,000 for piping and in-line components whose temperatures exceed threshold values. Therefore, fatigue for non-Class 1 piping and in-line components remains valid for the period of extended operation. Disposition The TLAA for non-Class 1 component fatigue analyses remains valid for the period of extended operation. A.1 .3.4 Effects of Reactor Coolant Environment on Fatigue Life of Components and Piping Applicants for license renewal are required to address the reactor coolant environmental effects on fatigue of. plant components. The minimum set of components for a BWR of'Columbia's vintage is derived from NUREG/CR-6260, "Application of NUREG/CR-5999, Interim Fatigue Curves to Selected Nuclear Power Plant Components," as follows: 1. Reactor vessel shell and lower head 2. Reactor vessel feedwater nozzle 3. Reactor recirculation piping (including inlet and outlet nozzles)4. Core spray line reactor vessel nozzle and associated Class 1 piping 5. Residual heat removal return line Class 1 piping 6. Feedwater line Class 1 piping Columbia has analyzed these locations for the effects of the reactor coolant environment on fatigue in support of license renewal. Original fatigue usage calculations were reviewed, and the transient groupings and load pairs used in those Final Safety Analysis Report Supplement Page A-35 r January 2010'e* e e Columbia Generating Station License Renewal Application Technical Information 7,000 thermal cycles. The allowable stress range is reduced by the stress range reduction factor if the number of thermal cycles exceeds 7,000. If fewer than 7,000 cycles are ex'pected through the period of extended operation, then the fatigue analysis (stress range reduction factor) of record will remain valid through the period of extended operation. Because none of the non-Class 1 vessels, heat exchangers, storage tanks, or pumps were designed to ASME Section VIII, Division 2 or ASME Section III, Subsection NC-, 3200,* no fatigue evaluation is required. Therefore, there are no fatigue TLAAs for these components. The fatigue evaluation of non-Class* 1 piping and in-line components evaluated the associated operating temperature against the threshold temperature value for fatigue of the material. If the threshold temperature value was exceeded, then the number of transient cycles for the piping or in-line component was projected. In each case, the. number of projected cycles for 60 years was found to be less than 7,000 for piping and in-line components whose temperatures exceed threshold values. Therefore, fatigue for non-Class 1 piping and in-line components remains valid for the period of extended operation. . . Disposition The TLAA for non-Class

1. component fatigue analyses remains valid for the period of extended operation.

A.1.3.4 Effects 01f Reactor Coolant Environment on Fatigue Life of Components and Piping Applicants for license renewal are required to address the reactor coolant environmental; effects on fatigue of. plelnt components. The minimum set of components for a BWR: of Columbia's vintage is derived from NUREG/CR-6260, "Application of NUREG/CR-5999

Interim Fatigue Curves to Selected Nuclear Power Plant Components," al? follows: ' 1. Reactor vessel shell and lower head 2. Reactor vessel feedwater nozzle 3. Reactor recirculation piping (including inlet and outlet nozzles) 4. Core spray line reactor vessel nozzle and associated Class 1 piping 5. Residual heat removal return line Class 1 piping 6. Feedwater line Class 1 piping Columbia has analyzed these locations for the effects of the reactor coolant environment on fatigue in support of license renewal. Original fatigue usage. calculations were reviElwed, and the transient groupings and load pairs used in those Final.Safety Analysis Report Supplement Page A-35 January 2010 '

Columbia Generating Station* License Renewal Application Technical Information analyses were carried over to the environmentally-assisted fatigue analyses, withrevised non-environmentally assisted usage factors determined. An effective fatigue life adjustment factor, Fen, that considers a time weighted average of operation with normal water chemistry and hydrogen water chemistry over 60 years of operation, was determined for each load pair analyzed for the components at the NUREG/CR-6260 locations. The fatigue life adjustment factors were applied to the revised component load pair usage factors, and the environmentally-adjusted usage.factors were summed to obtain environmentally-adjusted CUFs to verify acceptability of the components for the period of extended operation. Using fatigue data projected by the Fatigue Monitoring Program and the methodology summarized above, the limiting locations (a total of 14 locations corresponding to the six NUREG/CR-6260 components) were evaluated. None of the 14 locations evaluated have an environmentally adjusted CUF of greater than 1.0 during the period of extended operation. The aging effect of fatigue, including consideration of the environmental effects, will be adequately managed for the period of extended operation using the Fatigue Monitoring Program.Disposition The effects of environmentally-assisted fatigue on the intended functions of the limiting NUREG/CR-6260 locations will be adequately managed for the period of extended operation using the Fatigue Monitoring Program.A.1.3.5 Environmental Qualification of Electrical Equipment Environmental qualification analyses for electrical equipment are identified as TLAAs.NRC regulation 10 CFR 50.49, "Environmental Qualification of Electric Equipment Important to Safety for Nuclear Power Plants," requires licensees to identify electrical equipment covered under this regulation and to maintain a qualification file demonstrating that the equipment is qualified for its application and will perform its safety function up to the end of its qualified life. The EQ Program implements the requirements of 10 CFR 50.49 and will be used to manage the effects of aging on the intended functions of the components associated with environmental qualification TLAAs for the period of extended operation. Disposition The effects of aging on the intended functions of the environmentally qualified components will be adequately. managed for the period of extended operation by the EQ Program.Final Safety Analysis Report Supplement Page A-36 January2010 Columbia Generating Station License Renewal Application Technical Information analyses were carried over to the environmentally-assisted fatigue analyses, with revised non-environmentally assisted usage factors determined. An effective fatigue life adjustment factor, Fen, that considers a time weighted average of operation with normal water chemistry and hydrogen water chemistry over 60 years of operation, was determined for each load pair analyzed for the components at the NUREG/CR-6260 locations. The fatigue life adjustment factors were applied to the revised component load pair usage factors, and the environmentally-adjusted usage factors were summed to obtain environmentally-adjusted CUFs to verify acceptability of the components for the period of extended operation. . Using fatigue data projected by the Fatigue Monitoring Program and the methodology summarized above; the limiting locations (a total of 14 locations corresponding to the six NUREG/CR-6260 components) were evaluated. None of the 14 locations evaluated have an environmentally adjusted CUF of greater than 1.0 during the period of extended operation. The aging effect of fatigue, including consideration of the environmental effects, will be adequately managed for the period of extended operation using the Fatigue Monitoring Program. Disposition The effects of environmentally-assisted fatigue on the intended functions of the limiting NUREG/CR-6260 locations will be adequately managed for the period of extended operation using the Fatigue Monitoring Program. A.1.3.5 Environmental Qualification of Electrical Equipment Environmental qualification analyses for electrical equipment are identified as TLAAs .. NRC regulation 10 CFR 50.49, "Environmental Qualification of Electric Equipment Important to Safety for Nuclear Power Plants," requires licensees to identify electrical equipment covered under this regulation and to maintain a qualification file demonstrating that the equipment is qualified for its application and will perform its safety function up to the end of its qualified life. The EQ Program implements the requirements of 10 CFR 50.49 and will be used to manage the effects of aging on the intended functions of the components associated with environmental qualification TLAAs for the period of extended operation. Disposition The effects of aging on the intended functions of the environmentally qualified components will be adequately. managed for the period of extended operation by the EQ Program. Final Safety Analysis Report Supplement Page A-36 January 201 0 * *

• Columbia Generating StationLicense Renewal Application Technical Information A.1.3.6 Fatigue of Primary Containment, Attached Piping, and Components The Primary Containment and attached piping and components susceptible to fatigue resulting from the effects of plant transients are evaluated below.A.1.3.6.1 Primary Containment The cycles used in the fatigue evaluation of the containment components are provided in FSAR Table 3A.4.1-3.

No operating basis earthquakes have been experienced by Columbia through 2007, and the containment analysis for five operating basis earthquakes remains valid for 60 years of plant operation.. The safe shutdown earthquake and post-loss of coolant accident (LOCA) chugging are once in a lifetime events and are not projected to occur during the extended period of operation. Safety relief valve actuations have been projected through 60 years of operation based on the number of actual events through 2007. The fatigue analyses performed using these events will remain valid for the period of extended operation. As the cycles on which the containment fatigue analysis is based will not be exceeded for 60 years of operation, these analyses will remain valid for the period of extended operation. Disposition The TLAA associated with fatigue of the containment remains valid for the period of extended operation. A.1.3.6.2 ASME Class MC Components Class MC components; include the primary containment vessel shell, large openings (equipment hatch, personnel hatches, and access hatch), penetrations (all except the large openings), and attachments (pipe supports in the wetwell, welding pads in the drywell, supports for the stabilizer truss, seal and shear lugs at the drywell floor, supports for the downcomer bracing system, pipe whip supports, radial beam supports, cap truss supports, catwalks, monorail, and platforms). The Class MC components were analyzed for fatigue using the transients listed in FSAR Table 3A.4.1-3. As these cycles will not be exceeded for 60 years of operation, the Class MC component fatigue analysis will remain valid for the period of extended operation. A specific fatigue analysis was performed for the main steam penetrations using the transients listed in FSAR.Table 3A.4.1-3. This analysis will remain valid for the period of extended operation as these cycles will not be exceeded for 60 years of operation. The effects of power uprate on the containment system response were reviewed and l determined to be negligible. The containment peak pressure values remain virtually! unaffected by the power uprate and extended load line limit. The LOCA containment Final Safety Analysis Report Supplement Page A-37 January 2010.* *

• A.1.3.S Columbia Generating Station License Renewal Application Technical Information Fatigue 'of Primary Containment, Attached Piping, and Components The Primary Containment and attached piping and components susceptible to fatigue resulting from the effects of plant transients are evaluated below. A.1.3.6.1 Primary Containment The cycles used in the fatigue evaluation of the containment components are provided in' FSAR Table 3A.4.1-3.

No operating basis earthquakes have been experienced by Columbia through 2007, and the containment analysis for five operating basis earthquakes remains valid for 60 years of plant operation.. The safe shutdown earthquake and post-loss of coolant accident (LOCA) chugging are ohce in a lifetime : events and are not projected t() occur during the extended' period of operation. Safety relief valve actuations have been projected through 60 years of operation based on the number of actual events through 2007. The fatigue analyses performed using these events will remain valid for the period of extended operation .. As the cycles on which the containment fatigue analysis is based will not be exceeded . for 60 years of operation, these analyses will remain valid for the period of extended operation . Disbosition The TLAA associated with fatigue of the containment remains valid for the period of. extended operation. . A.1.3.6.2 ASME Class MC Components Class MC components include the primary containment vessel shell, large openings (equipment hatch, personnel hatches, and access hatch), penetrations (all except the' large openings), and attachments (pipe supports in the wetwell, welding pads in the drywell, supports for the stabilizer truss, seal and shear lugs at the drywell floor, supports for the downcomer bracing system, pipe whip supports, radial beam supports, cap truss supports, catwalks, monorail, and platforms). The Class MC components I were analyzed for fatigue using the transients listed in FSAR Table 3A.4.1-3. As these: cycles will not be exceeded for 60 years of operation, the Class MC component fatigue, analysis will remain valid for the period of extended operation. A specific fatigue analysis was performed for the main steam penetrations using the. transients listed in FSAR-Table 3AA.1-3. This analysis will remain valid for the period of extended operation as these cycles will not be exceeded for 60 years of operation. The effects of power uprate on the containment system response were reviewed and; determined to be negligible. The containment peak pressure values remain virtually unaffected by the power uprate and extended load line limit. The LOCA containment Final Safety Analysis Report Supplement Page A-37 January 2010, , Columbia Generating Station License Renewal Application Technical Information dynamic loads are not affected by power uprate, and safety relief valve containment loads will remain below their design allowables. (see FSAR Appendix 3A)All events, including safety relief valve actuations, for 60 years of operation are projected to remain below the containment cyclic basis from FSAR Table 3A.4.1-3.Consequently, the analysis of the Class MC containment components remains valid for the period of extended operation. Disposition The TLAAs for fatigue of the ASME Class MC components remain valid through the end of the period of extended operation. A.1.3.6.3 Downcomers Although not an ASME Code requirement, a fatigue evaluation of the downcomers was performed. The fatigue evaluation of the downcomer lines in the wetwell air volume was based on the number of cycles presented in FSAR Table 3A.4.1-3. The maximum fatigue usage factor for the downcomers is provided in FSAR Table 3A.4.2-4 and FSAR Table 3A.4.2-5.All events, including safety relief valve actuations, for 60 years of operation are projected to remain below the containment cyclic basis from FSAR Table 3A.4.1-3.Consequently, the analysis of the downcomers remains valid for the period of extended operation. Disposition The TLAA for fatigue of the downcomers remains valid through the end of the period of extended operation. A.1.3.6.4 Safety Relief Valve Discharge Piping Although not an ASME Code requirement, a fatigue evaluation of the safety relief valve (SRV) discharge piping was performed. The fatigue evaluation used the number of cycles as presented in FSAR Table 3A.4.1-3. The maximum fatigue usage factor for all 18 SRV discharge lines in the wetwell air volume is below the ASME allowable limits per FSAR Section 3A.4.2.4.6. The SRV actuations for 60 years of operation are projected to remain below the containment cyclic basis from FSAR Table 3A.4.1-3. Consequently, the analysis of the SRV discharge piping remains valid for the period of extended operation. Disposition The TLAA for fatigue of the SRV discharge piping remains valid through the end of the period of extended operation. Final Safety Analysis Report Supplement Page A-38 January 2010 I Columbia Generating Station License Renewal Application

• Technical Information dynamic loads are not affected by power uprate, and safety relief valve containment loads will remain below their design allowables. (see FSAR Appendix 3A) All events, including safety relief valve actuations, for 60 years of operation are projected to remain below the containment cyclic basis from FSAR Table 3A.4.1-3.

Consequently, the analysis of the Class MC containment components remains valid for the period of extended operation. Disposition The TLAAs for fatigue of the ASME Class MC components remain valid through the end of the period of extended operation. A.1.3.6.3 Downcomers Although not an ASME Code requirement, a fatigue evaluation of the downcomers was performed. The fatigue evaluation of the downcomer lines in the wetwell air volume was based on the number of cycles presented in FSAR Table 3A.4.1-3. The maximum fatigue usage factor for the downcomers is provided in FSAR Table 3A.4.2-4 and FSAR Table 3A.4.2-5. . All events, including safety relief valve actuations, for 60 years* of operation are projected t6 remain below the containment cyclic basis from FSAR Table 3A.4.1-3.

• Consequently, the analysis of the downcomers remains valid for the period of extended operation.

Disposition The TLAA for fatigue of the downcomers remains valid through the end of the period of extended operation. A.1.3.6.4 Safety Relief Valve Discharge Piping Although not an ASME Code requirement, a fatigue evaluation of the safety relief valve (SRV) discharge piping was performed. The fatigue evaluation used the number of cycles as presented in FSAR Table 3A.4.1-3. The maximum fatigue usage factor for all 18 SRV discharge lines in the wetwell air volume is below the ASME allowable limits per FSAR Section 3A.4.2.4.6. The SRV actuations for 60 years of operation are projected to remain below the containmentcyclic basis from FSAR Table 3A.4.1-3. Consequently, the analysis of the SRV discharge piping remains valid for the period of extended operation. Disposition The TLAA for fatigue of the SRV discharge piping remains valid through the end of the period of extended operation. . Final Safety Analysis Report Supplement Page A-38 January 2010

• Columbia Generating Station License Renewal Application Technical Information A. 1.3.6.5 Diaphragm Floor Seal, The diaphragm floor seal is located at the inside surface of the primary containment vessel periphery.

It provides a flexible, pressure tight seal between the primary containment vessel and the diaphragm floor and is capable of accommodating differential thermal expansion between them.The fatigue evaluation was performed using the cycles in FSAR Table 3A.4.1-3. The maximum cumulative usage factor is less than the fatigue limit per FSAR Table 3A.4.1-5. All events, including SRV actuations, for 60 years of operation are projected to remain below the containment cyclic basis from FSAR Table 3A.4.1-3.Consequently, the analysis of the diaphragm floor seal remains valid for the period of extended operation. Disposition The TLAA for fatigue of the containment diaphragm floor seal remains valid through the end of the period of extended operation. A. 1.3.6.6 ECCS Suction Strainers The original Columbia ECCS suction strainers were replaced with a new strainer design constructed from cold-worked austenitic stainless steel. A linear elastic fracture mechanics analysis was performed to bound all the martensitic material in the suction strainer screens. A crack depth was assumed based on the depth of the Alpha Prime martensite in the strainer screen material.Cyclic stresses were considered in the crack growth analysis of the suction strainers. The fatigue crack evaluation determined that the assumed cracks will not propagate to a critical size for the remaining life of the plant. The maximum computed stress intensity value (K) was less than that required to cause cracking in Alpha martensite formed in austenitic stainless steel.The stress value conservaiively included direct pressure and inertialcomponents from SRV actuation, operating basis earthquake (OBE) loads, and SRV steam chugging.(See FSAR Table 3A.4.1-3.) All events, including safety relief valve actuations, for 60 years of operation are.projected to remain below the containment cyclic basis from FSAR Table 3A.4.1-3.' Consequently, the analysis.of the ECCS suction strainers remains valid for the period of!extended operation. Disposition The TLAA for crack growth of the ECCS suction strainers remains valid through the end of the period of extended operation. Final Safety Analysis Report Supplement Page A-39 January 2010 Final Safety Analysis Repoil Supplement Page A-39 January 2010!* *

• A.1.3.6.S Diaphragm Floor Seal* , Columbia Generating Station License Renewal Application Technical Information The diaphragm floor s*!al is located at the inside surface of the primary containment vessel periphery.

It provides a flexible, pressure tight seal between the primary containment vessel and the diaphragm floor and is capable of accommodating . differential thermal expansion between them. The fatigue evaluation was performed using the cycles in FSAR Table 3A.4.1-3. The maximum cumulative usage factor is less than the fatigue limit per FSAR Table 3A.4.1-S. All events, including SRV actuations, for 60 years of operation are projected to remain below the containment cyclic basis from FSAR Table 3A4.1-3. Consequently, the analysis of the' diaphragm floor seal remains valid for the period of . extended operation. Disposition The TLAA for fatigue of the containment diaphragm floor seal remains valid through the; end of the period of operation . . A.1.3.6.6 ECCS Suction Strainers. The original Columbia ECCS suction strainers were replaced with a new strainer design; constructed from cold-worked austenitic stainless steel. A linear elastic fracture: mechanics analysis was performed to bound. all the martensitic material in the suction i strainer screens. A crack depth was assumed based on the depth of the Alpha Prime i martensite in the screen material. I Cyclic stresses were considered in the crack growth analysis of the suction strainers. I The fatigue crack evaluation determined that the assumed cracks will not propagate to a ; critical size for the remaining life of the plant. The maximum computed stress intensity. value (K) was less than that required to cause cracking in Alpha martensite formed in austenitic stainless steel. The stress value conservatively included direct pressure and inertial' components from SRV actuation, operating basis earthquake (OBE) loads,' and SRV steam chugging.' (See FSAR Table 3A.4.1-3.) All events, including safety relief valve actuations, for 60 years of operation are, projected t6 remain below the containment cyclic basis from FSAR Table 3A.4.1-3. I Consequently, the analysis.of the ECCS suction strainers remains valid for the period o( extended operation. . : ! I Disposition I The TLAA for crack growth of the ECCS suction strainers remains valid through the end I of the period of op'eration. i Final Safety Analysis Repoli Supplement Page A-39 January 201 0 Columbia Generating Station License Renewal Application Technical Information A.1.3.7 Other Plant-Specific Time-Limited Aging Analyses The TLAAs that do not fit into any of the previous major categories are evaluated below.A. 1.3.7.1 Reactor Vessel Shell Indications Two indications in the reactor vessel shell were identified using ultrasonic inspection methods during the 2005 inservice inspections. The indications were present in past inservice inspection examinations, but became rejectable under current ASME Section Xl, IWB-3610 requirements. The rejected indications were evaluated and determined to be acceptable for continued service without repair, as reported to the NRC. The indications were evaluated per the guidelines of ASME Section Xl, IWB-3610, which include acceptance criteria based on the applied stress intensity factors, using'conservative assumptions in the applied stresses to determine the stress intensity factors for comparison to Code allowables. This conservative evaluation calculated a fatigue crack growth at the end of 33.1 EFPY vessel service life that is insignificant in comparison to the bounding initial crack size. It also determined that the applied stress intensity factor is well below the allowable stress intensity factor.The calculation is based on time-limited assumptions of neutron fluence and SRV blowdown cycles for 40 years. While it is not expected that the applied stress intensity factor will exceed the allowable fracture toughness during the period of extended operation, cracking near the subject reactor vessel welds is managed by the Inservice Inspection (ISI) Program.Disposition Cracking of the reactor vessel shell near welds BG and BM will be adequately managed through the period of extended operation by the Inservice Inspection (ISI) Program.A.1.3.7.2 Sacrificial Shield Wall FSAR Section 3.8.3.6 provides a value of neutron fluence for the outside face of the sacrificial shield wall that is based on 40 years of plant operation. Projections done for 60 years of operation, including increase in fluence dueto power uprate, determined that the estimated neutron fluence on the sacrificial shield wall will remain below the threshold for neutron damage of concrete and reinforcing steel. Therefore, the sacrificial shield wall can be expected to perform its radiation shielding function through the period of extended operation. Disposition The TLAA associated with the sacrificial shield wall fluence has been projected to the end of the period of extended operation. Final Safety Analysis Report Supplement Page A-40 January 2010 A.1.3.7 Columbia Generating Station License Renewal Application . Technical Information Other Plant-Specific Time-Limited Aging Analyses The TLAAs that do not fit into any of the previous major categories are evaluated below. A.1.3.7.1 Reactor Vessel Shell Indications Two indications in the reactor vessel shell were identified using ultrasonic inspection methods during the 2005 inservice inspections. The indications were present in past inservice inspection examinations, but became rejectable under current ASME Section XI, IWB-3610 requirements. The rejected indications were evaluated arid determined to be acceptable for continued service without repair, as reported to the NRC. The indications were evaluated per the guidelines of ASME Section XI, IWB-3610, which include acceptance criteria based on the applied stress intensity factors, using "conservative assumptions in the applied stresses to determine the .stress intensity factors for comparison to Code allowables. This conservative evaluation calculated a fatigue crack growth at the end of 33.1 EFPY vessel service life that is insignificant in comparison to the bounding initial crack size. It also determined that the applied stress intensity factor is well below the allowable stress intensity factor.

• The calculation is based on time-limited assumptions of neutron fluence and SRV blowdown cycles for 40 years. While it is not expected that the applied stress intensity
• factor will exceed the allowable fracture toughness during the period of extended operation, cracking near the subject reactor vessel welds is managed by the Inservice Inspection (lSI) Program. Disposition Cracking of the reactor vessel shell near welds BG and BM will be adequately managed through the period of extended operation by the Inservice Inspection (lSI) Program. A.1.3.7.2 Sacrificial Shield Wall FSAR Section 3.8.3.6 provides a value of neutron fluence for the outside face of the sacrificial shield wall that is based on 40 years of plant operation.

Projections done for 60 years of operation, including increase in fluence due to power uprate, determined ( that the estimated neutron fluence on the sacrificial shield wall will remain below the threshold for neutron damage of concrete and reinforcing steel.. Therefore, the sacrificial shield wall can be expected to perform its radiation shielding function through the period of extended operation. Disposition { The TLAA associated with the sacrificial shield wall fluence has been projected to the end of the period of extended operation. ' Final Safety Analysis Report Supplement Page A-40 January 2010 , \

• Columbia Generating Station License Renewal Application Technical Information A.1.3.7.3 Main Steam Flow Restrictor Erosion Analyses The main steam line flow restrictors are designed to limit coolant flow rate from the reactor vessel (before the MSIVs are closed) to less than 200 percent of normal flow in the event of a main steam line break outside the containment.

Erosion of a flow restrictor is a safety concern since it could impair the ability of the flow restrictor to limit vessel blowdown following a main steam line break. Since erosion is a time-related phenomenon, the analysis for the effect it has on the flow restrictors over the life of the plant is a TLAA. Cast stainless steel (SA351, Type CF8) was selected for the steam flow restrictor material because it has excellent resistance to erosion-corrosion from high velocity steam.The erosion of the main steam flow restrictors has been projected for the period of extended operation. The projection concludes that after 60 years of erosion on the main steam flow restrictors, the choked flow will still be less than 200 percent of normal flow. Therefore, the main steam flow restrictors will continue to perform their intended function and the existing accident radiological release analysis will remain valid for the period of extended operation. Disposition The TLAA for erosion of the main steam line flow restrictors has been projected to the end of the period of extended operation. A.1.4 References A. 1.4-1 BWROG Report GE-NE-523-A71-0594-A, Rev 1, "Alternate BWR Feedwater Nozzle Inspection Requirements," May 2000 A.1.4-2 EPRI Report No. 1011838, "Recommendations for An Effective Flow Accelerated Corrosion Program (NSAC-202L-R3)," May 2006 A.1.5 License Renewal Commitment List A listing of commitments identified in association with Columbia license renewal is provided in Table A-1. These commitments will be tracked within the Columbia regulatory commitment management program. Any other actions discussed in the LRA represent intended or planned actions. They are described to the NRC for information and are not regulatory commitments. Final Safety Analysis Report Supplement Page A-41 January 2010 Final Safety Analysis Repoil Supplement Page A-41 January 2010* *

• A.1.3.7.3 Main Steam Flow Restrictor Erosion Analyses Columbia Generating Station License Renewal Application Technical Information The main steam line flow restrictors are designed to limit coolant flow rate from the reactor vessel (before tile MSIVs are closed) to less than 200 percent of normal flow in the event of a main steam line break outside the containment.

Erosion of a flow restrictor is a safety concern since it could impair the ability of the flow restrictor to limit vessel blowdown following a main steam line break. Since erosion is a time-related phenomenon, the analysis for the effect it has on the flow restrictors over the life of the plant is a TLAA. Cast stainless steel (SA351, Type CF8) was selected for the steam flow restrictor material because it has excellent resistance to erosion-corrosion from high velocity steam. The erosion of the main steam flow restrictors has been projected for the period of extended operation. The projection concludes that after 60 years of erosion on the main steam flow restrictors, the choked flow will still be less than 200 percent of normal flow. Therefore, the main steam flow restrictors will continue to perform their intended : function and the existing accident radiological release analysis will remain valid for the : period of extended operation. Disposition The TLAA for erosion of the main steam line flow restrictors has been projected to the end of the period of extended operation. A.1.4 References A.1.4-1 BWROG Report GE-NE-523-A71-0594-A, Rev 1 ,"Alternate BWR Feedwater Nozzle Inspection Requirements," May 2000 A.1.4-2 EPRI Report No.1 011838, "Recommendations for An Effective Flow Accelerated Corrosion Program (NSAC-202L-R3)," May 2006 A.1.5 License Renewal Commitment List A listing of commitments identified in association with Columbia license renewal is provided in Table A-1. These commitments will be tracked within the Columbia regulatory commitment management program. Any other actions discussed in the LRA represent intended or planned actions. They are described to the NRC for information and are not regulatory commitments. . . Final Safety Analysis Report Supplement Page A-41 January 2010 Columbia Generating Station* License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 1) Aboveground The Aboveground Steel Tanks Inspection is a new activity. A.1.2.1 Within the 10-Steel Tanks The Aboveground Steel Tanks Inspection detects and characterizes year period prior Inspection the conditions on the bottom surfaces of the condensate storage to the period of tanks. The inspection provides direct evidence as to whether, and to extended what extent, the relevant effects of aging have occurred in operation. inaccessible areas.2) Air Quality The Air Quality Sampling Program is an existing program that will be A.1.2.2 Ongoing Sampling continued for the period of extended operation. Program 3) Appendix J The Appendix J Program is an existing program that will be continued A.1.2.3 Ongoing Program for the period of extended operation.

4) Bolting Integrity The Bolting Integrity Program is an existing program that will be A.1.2.4 Ongoing Program continued for the period of extended operation.

Final Safety Analysis Report Supplement Page A-42 January 2010 Table A-1 Columbia License Renewal Commitments -Item Number Commitment

1) Aboveground The Aboveground Steel Tanks Inspection is a new activity.

Steel Tanks The Aboveground Steel Tanks Inspection deteCts and characterizes Inspection the conditions on the bottom surfaces of the condensate storage -tanks. The inspection provides direct evidence as to whether; and to what extent, the relevant effects of aging have occurred in . inaccessible areas . 2) Air Quality The Air Quality Sampling Program is an existing program that will be Sampling continued for the period of extended operation . . Program 3) Appendix J The Appendix J Program is an existing program that will be continued Program. for the period of extended operation.

4) Bolting Integrity The Bolting Integrity Program is an existing program that will be Program continued for the period of extended operation.

Final Safety Analysis Report Supplement PageA-42 *

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.1 Within the 10-year period prior to the period of extended operation.

A.1.2.2 Ongoing A.1.2.3 Ongoing A1.2.4 Ongoing January 2010

• Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Supplement or Item Number Commitment Location o n Location Implementation (LRA App. A) Schedule 5) Buried Piping The Buried Piping and Tanks Inspection Program is an existing A.1.2.5 Enhancement and Tanks program that will be continued for the period of extended operation, prior to the period Inspection with the following enhancements:

of extended Program Revise the site program document to include the buried portions operation. of the Radwaste Building Outside Air (WOA) piping. Then ongoing. Require that an inspection of a representative sample of buried piping be performed within the 10-year period prior to entering the period of extended operation (i.e., between year 30 and year 40).Require an additional inspection of a representative sample of buried piping be performed within 10 years after entering the period of extended operation (i.e., between year 40 and year 50).6) BWR The BWR Feedwater Nozzle Program is an existing program that will A.1.2.6 Ongoing Feedwater be continued for the period of extended operation. Nozzle.Program 7) BWR The BWR Penetrations Program is an existing program that will be A. 1.2.7 Ongoing Penetrations continued for the period of extended operation. Program 8) BWR Stress The BWR Stress Corrosion Cracking Program is an existing program A.1.2.8 Ongoing Corrosion that will be continued for the period of extended operation. Cracking Program -FialSfeyAnlyi RprtSppemn Pg A43Jnur 21 Final Safety Analysis Report Supplement Page A-43 January 2010*

• Table A-1 Columbia License Renewal Commitments Item Number Commitment -5) Buried Piping The Buried Piping and Tanks Inspection Program is an existing and Tanks program that will be continued for the period of extended operation, Inspection with the following enhancements:

-Program

• Revise the site program document to include the buried portions of the Radwaste Building Outside Air (WOA) piping.
• Requirethat an inspection of a representative sample of buried piping be performed within the 10-year period prior to entering the period of extended operation (i.e., between year 30 and year 40).
• Require an additional inspection of a representative sample of buried piping be performed within 10 years after entering the period of extended operation (i.e., between year 40 and year 50). 6) BWR The BWR Feedwater Nozzle Program is an existing program that will Feedwater be continued for the period of extended operation.

Nozzle Program 7) BWR The BWR Penetrations Program is an existing program that will be Penetrations continued for the period of extended operation. Program 8) BWR Stress The BWR Stress Corrosion Cracking Program is an existing program Corrosion that will be continued for the period of extended operation. Cracking Program -Final Safety Analysis Report Supplement Page A-43

• Columbia Generating Station -License Renewal Application Technical Information . FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.5 Enhancement prior to the period of extended operation.

Then ongoing .. A.1.2.6 Ongoing A.1.2.7 Ongoing A.1.2.8 Ongoing January 2010 Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 9) BWR Vessel ID The BWR Vessel ID Attachment Welds Program is an existing A.1.2.9 Ongoing Attachment program that will be continued for the period of extended operation. Welds Program 10) BWR Vessel The BWR Vessel Internals Program is an existing program that will A.1.2.10 Ongoing Internals be continued for the period of extended operation. Program 11) BWR Water The BWR Water Chemistry Program is an existing program that will A.1.2.11 Ongoing Chemistry be continued for the period of extended operation. Program 12) Chemistry The Chemistry Program Effectiveness Inspection is a new activity. A.1.2.12 Within the 10-Program The Chemistry Program Effectiveness Inspection detects and year period prior Effectiveness characterizes the condition of materials in representative low flow to the period of Inspection and stagnant areas of systems with water chemistry controlled by the extended BWR Water Chemistry Program or the Closed Cooling Water operation. Chemistry Program, and with fuel oil chemistry controlled by the Fuel Oil Chemistry Program. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred.Final Safety Analysis Report Supplement Page A-44 January 2010 Final Safety Analysis Report Supplement Page A-44 January 2010" Table A-1 Columbia License Renewal Commitments Item Number Commitment

9) BWR VessellD The BWR VessellD Attachment Welds Program is an existing Attachment program that will be c.ontinued for the period of extended operation.

Welds Program 10) BWRVessel The BWR Vessel Internals Program is an existing program thatwill Internals be continued for the period of extended operation. Program 11 ) BWR Water The BWR Water Chemistry Program is an existing program that will Chemistry be continued for the period of extended operation. Program 12) Chemistry The Chemistry Program Effectiveness Inspection is a new activity. Program The Chemistry Program Effectiveness Inspection detects and Effectiveness characterizes the condition of materials in representative low flow Inspection and stagnant areas of systems with water chemistry controlled by the BWR Water Chemistry Program or the Closed Cooling Water Chemistry Program,and with fuel oil chemistry controlled by the Fuel Oil Chemistry Program. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred. Final Safety Analysis Report Supplement PageA-44 *

• Columbia Generating Station License Renewal Application Tectmicallnformation FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.9 Ongoir:1g A.1.2.10 Ongoing A.1.2.11 Ongoing A.1.2.12 Within the 10-year period prior to the period of extended operation. " January 2010
• Columbia Generating StationLicense Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 13) Closed Cooling The Closed Cooling Water Chemistry Program is an existing program A.1.2.13 Enhancement Water that will be continued for the period of extended operation, with the prior to the period Chemistry following enhancement:

of extended Program

• Ensure that at least one additional Reactor Closed Cooling Water operation.

corrosion rate measurement is performed and evaluated prior to Then ongoing.entering the period of extended operation to provide direct information as to the effectiveness of the chemical treatments. If necessary, based on the results, establish a frequency for subsequent measurements.

14) Cooling Units The Cooling Units Inspection is a new activity.

A.1.2.14 Within the 10-Inspection The Cooling Units Inspection detects and characterizes the material year period prior condition of cooling unit components that are exposed to to the period of condensation. The inspection provides direct evidence as to extended whether, and to what extent, the relevant effects of aging have operation. occurred.15) CRDRL Nozzle The CRDRL Nozzle Program is an existing program that will be A.1.2.15 Ongoing Program continued for the period of extended operation. Final Safety Analysis Report Supplement Page A-45 January 2010* Item Number 13) Closed Cooling Water Chemistry Program 14) Cooling Units Inspection

15) CRDRL Nozzle Program

• Table A-1 Columbia License Renewal Commitments Commitment The Closed Cooling Water Chemistry Program is an existing program that will be continued for the period of extended operation, with the following enhancement:
• Ensure that at least one additional Reactor Closed Cooling Water corrosion rate measurement is performed and evaluateq prior to entering the period of extended operation to provide direct information as to the effectiveness of the chemical treatments.

If necessary, based on the results, establish a frequency for subsequent measurements. \ The Cooling Units Inspection is a new The Cooling Units Inspection detects and characterizes the material condition of cooling unit components that are exposed to condensation. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred. The CRDRL Nozzle Program is an existing program that will be continued for the period of extended operation. Final Safety Analysis Report Supplement PageA-45

• Columbia Generating Station License Renewal Application Technical Information FSAR Supplement . Location (LRA App. A) A.1.2.13 A.1.2.14 A.1.2.15 Enhancement or Implementation Schedule Enhancement prior to the period of extended operation.

Then ongoing. Within the 10-*year period prior to the period of extended operation. Ongoing January 2010 Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 16) Diesel Starting The Diesel Starting Air Inspection is a new activity. A.1.2.16 Within the 10-Air Inspection The Diesel Starting Air Inspection detects and characterizes the year period prior condition of materials for the DSA System air dryers and downstream to the period of piping and components (excluding the DSA System air receivers), extended The inspection provides direct evidence as to whether, and to what operation. extent, the relevant effects of aging have occurred.17) Diesel Systems The Diesel Systems Inspection is a new activity. A.1.2.17 Within the 10-Inspection The Diesel Systems Inspection detects and characterizes the year period prior condition of materials for the interior of the exhaust piping for the to the period of Division 1, 2, and 3 diesels in the Diesel Engine Exhaust System, extended including the loop seal-drains from the exhaust piping,'and the drain operation. pans and drain piping associated with air-handling units of the Diesel Building HVAC systems. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred.18) Diesel-Driven The Diesel-Driven Fire Pumps Inspection is a new activity. A.1.2.18 Within the 10-Fire Pumps The Diesel-Driven Fire Pumps Inspection detects and characterizes year period prior Inspection the material condition of the interior of the Fire Protection System to the period of diesel engine exhaust piping, and of Fire Protection System diesel extended heat exchangers exposed to a raw water environment. The operation. inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred.Final Safety Analysis Report Supplement Page A-46 January 2010 Final Safety Analysis Report Supplement Page A-46 January 2010 Table A-1 Columbia License Renewal Commitments Item Number Commitment r -16) Diesel Starting The Diesel Starting Air Inspection is a new activity. Air Inspection The Diesel Starting Air Inspection detects and characterizes the condition of materials for the DSA System air dryers and downstream piping and components (excluding the DSA System air receivers). , The inspection provides direct evidence as to whether, and to what ; extent, the relevant effects of aginghave occyrred .. 17) Diesel Systems The Diesel Systems Inspection is a new activity. Inspection The Diesel Systems Inspection detects and characterizes the condition of materials for the interior of the exhaust piping for the Division 1, 2, and 3 diesels in the Diesel Engine Exhaust System, including the loop seardrains from the exhaust piping,iand the drain pans and drain piping assoCiated with air-handling units of the Diesel Building HVAC systems. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred.

18) Diesel-Driven The Diesel-Driven Fire Pumps Inspection is a new activity.

Fire Pumps The Diesel-Driven Fire Pumps Inspection detects and characterizes Inspection the material condition of the interior of the Fire Protection System diesel engine exhaust piping, and of Fire Protection System diesel heat exchangers exposed to a raw water environment. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred. Final Safety Analysis Report Supplement Page A-46 * * ; Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.16 Within the 10-year period prior to the period of extended operation. A.1.2.17 Within the 10-year period prior to the period of extended operation. A.1.2.18 Within the 10-year period prior to the period of extended operation. January 2010

• Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 19) Electrical The Electrical Cables and Connections Not Subject to 10 CFR 50.49 A.1.2.19 Implementation Cables and EQ Requirements Program is a new program.

prior to the period Connections The Electrical Cables and Connections Not Subject to 10 CFR 50.49 of extended Not Subject to EQ Requirements Program is an inspection program that detects operation. 10 CFR 50.49 degradation of electrical cables and connections that are not Then ongoing.EQ environmentally qualified and are within the scope of license renewal. Requirements The program provides for the periodic visual inspection of accessible, Program non-environmentally qualified cables and connections in order to determine if age-related degradation is occurring, particularly in plant areas with adverse localized environments.

20) Electrical The Electrical Cables and Connections Not Subject to 10 CFR 50.49 A1.2.20 Implementation Cables and EQ Requirements Used in Instrumentation Circuits Program is a new prior to the period Connections program. of extended Not Subject to The Electrical Cables and Connections Not Subject to 10 CFR 50.49 operation.

10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program is a Then ongoing.EQ monitoring program that detects degradation of electrical cables and Requirements connections that are not environmentally qualified and used in Used in circuits with sensitive, low-current applications. The program Instrumentation provides for a review of calibration records for low-current Circuits instruments, in order to detect and identify degradation of the cable Program system insulation resistance. The program retains the option to perform direct cable testing.Final Safety Analysis Report Supplement Page A-47 January 2010*

• Table A-1 Columbia License Renewal Commitments Item Number* Commitment 19) Electrical The Electrical Cables and Connections Not Subject to 10 CFR 50.49 Cables and EO Requirements Program is a new program. Connections The Electrical Cables and Connections Not Subject to 10 CFR 50.49 Not Subject to EO Requirements Program is an inspection program that detects 10 CFR 50.49 degradation of electrical cables and connections that are not EO environmentally qualified and are within the scope of license renewal. Requirements The program provides for the periodic visual inspection of accessible, Program . non-environmentally qualified cables and connections in order to determine if age-related degradation is occurring, particularly in plant areas with adverse localized environments.

20) Electrical The Electrical Cables and Connections Not Subject to 10 CFR 50.49 Cables and EO Requirements Used in Instrumentation Circuits Program is a new . Connections . 'program.

Not Subject to The Electrical Cables and Connections Not Subject to 10 CFR 50.49 10 CFR 50.49 EO Requirements Used in Instrumentation Circuits Program is a EO . monitoring program that detects degradation of electrical cables and Requirements connections that are not environmentally qualified and used in Used in circuits with sensitive, low-current applications. The program Instrumentation provides for a review of calibration records for low-cu'rrent Circuits instruments, in order to detect and identify degradation of the cable Program system insulation resistance. The program retains the option to perform direct cable testing. Final Safety Analysis Report Supplement A-47

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LR.t\ App. A) Schedule A.1.2.19 Implementation prior to the period of extended operation.

Then ongoing. A.1.2.20 Implementation prior to the period of extended operation. Then ongoing. -January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 21) Electrical Cable The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ A.1.2.21 Within the 10-Connections Requirements Inspection is a new activity. year period prior Not Subject to The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ to the period of 10 CFR 50.49 Requirements Inspection detects and characterizes the material extended EQ condition of metallic electrical connections within the scope of license operation. Requirements renewal. The inspection uses thermography (augmented by contact Inspection resistance testing) to detect loose or degraded connections that lead to increased resistance for a representative sample of metallic electrical connections in various plant locations.

22) EQ Program The EQ Program is an existing program that will be continued for the A.1.2.22 Ongoing period of extended operation.

A. 1.3.5 N Final Safety Analysis Report Supplement Page A-48 January 2010 C Table A-1 Columbia License Renewal Commitments Item Number Commitment

21) Electrical Cable The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Connections Requirements Inspection is a new activity.

Not Subject to The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ 10 CFR 50.49 Requirements Inspection detects and characterizes the material EQ condition of metallic electrical connections within the scope of license Requirements renewal. The inspection uses thermography (augmented by contact Inspection resistance testing) to detect loose or degraded connections that lead to increased resistance for a representative sample of metallic electrical connections in various plant locations.

22) EQ Program The EQ Program is an existing program that will be continued for the period of extended operation. , Final Safety Analysis Report Supplement PageA-48 *

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.21 Within the 10-year period prior to the period of extended operation.

A.1.2.22 Ongoing A.1.3.5 January 2010 .

• Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 23) External The External Surfaces Monitoring Program is an existing program A.1.2.23 Enhancement Surfaces that will be continued for the period of extended operation, with the prior to the period Monitoring following enhancements:

of extended Program

• Add aluminum, copper alloy, copper alloy >15 % Zn, gray cast operation.

iron, stainless steel (including CASS), and elastomers to the Then ongoing.scope of the program.* Add cracking as an aging effect for aluminum and stainless steel components.

• Add visual (VT-1 or equivalent) or volumetric examination techniques to detect cracking.* Add hardening and loss of strength as aging effects for elastomer-based mechanical sealants and flexible connections in HVAC systems.* Add physical examination techniques in addition to visual inspection to detect hardening and loss of strength for elastomer-based mechanical sealants and flexible connections in HVAC systems.24) Fatigue The Fatigue Monitoring Program is an existing program that will be A.1.2.24 Enhancement Monitoring continued for the period of extended operation, with the following A. 1.3.2 prior to the period Program enhancements:

A134 of extended operation. Then ongoing.Final Safety Analysis Report Supplement Page A-49 January 2010 Final Safety Analysis Report Supplement Page A-49 January 2010*

• Table A-1 Columbia License Renewal Commitments , Item Number Commitment

23) External The External Surfaces Monitoring Program is an existing program Surfaces that will be continued for the period of extended operation, with the Monitoring following enhancements:

Program

• Add aluminum, copper alloy, copper alloy >15 % Zn, gray' cast iron, stainless steel (including CASS), and elastomers to the f scope of the program.
• Add cracking as an aging effect for aluminum and stainless steel components

.. * ,Add visual (VT-1 or equivalent) or volumetric examination techniques to detect cracking.

• Add hardening and loss of strength as aging effects for elastomer-based mechanical sealants and flexible connections in HVAC systems. ,
• Add physical examination techniques in addition to visual inspection to detect hardening and loss of strength for elastomer-based mechanical sealants and flexible connections in HVAC systems. -, 24) Fatigue TheFatigue Monitoring Program is an existing program that will be Monitoring continued for the period of extended operation, with the following Program . enhancements:

Final Safety Analysis Report Supplement PageA-49

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.23 Enhancement prior to the period of extended . operation.

Then ongoing. A.1.2.24 Enhancement A.1.3.2 prior to the period A.1.3.4 of e?ctended operation. Then ongoing. January 2010 Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 24) Fatigue

• Columbia has analyzed the effects of the reactor coolant Monitoring environment on fatigue for the six locations recommended by Program NUREG\CR-6260.

These analyses are based on the projected (cont'd) cycles for 60 years of operation (plus some conservatism) rather than the original design cycles in FSAR Table 3.9-1. The Fatigue Monitoring Program will be enhanced to ensure that action will be taken when the lowest number of analyzed cycles is approached.

• For each location that may exceed a CUF of 1.0 (due to projected cycles exceeding analyzed, or due to as-yet undiscovered industry issues), the Fatigue Monitoring Program will implement one or more of the following:

(1) Refine the fatigue analyses to determine valid CUFs less than 1.0, (2) Manage the effects of aging due to fatigue at the affected locations by an inspection program that has been reviewed and approved by the NRC, or (3) Repair or replace the affected locations before exceeding a CUF of 1.0.* Correlate information relative to fatigue monitoring and provide more definitive verification that the transients monitored and their limits are consistent with or bound the FSAR and the supporting fatigue analyses, including the environmentally-assisted fatigue analyses.Final Safety Analysis Report Supplement Page A-50 January 2010 Final Safety Analysis Report Supplement Page A-50 January 2010 Table A-1 Columbia License Renewal Commitments Item Number Commitment

24) Fatigue

• Columbia has analyzed the effects of the reactor coolant Monitoring environment on fatigue for the six locations recommended by Program NUREG\CR-6260.

These analyses are based on the projected (cont'd) cycles for 60 years of operation (plus some conservatism) rather than the original design cycles in FSAR Table 3.9-1. The Fatigue Monitoring Program will be enhanced to ensure that action will be taken when the lowest number of analyzed cycles is approached.

• For each location that may exceed a CUF of 1.0 (due to -projected cycles exceeding analyzed, or due to as-yet undiscovered industry issues), the Fatigue Monitoring Program will implement one or more of the following:

(1) Refine the fatigue analyses to determine valid CUFs less than 1.0, (2) Manage the "-effects of aging due to fatigue at the affected locations by an inspection program that has been reviewed and approved by the NRC, or (3) Repair orreplace the affected locations before exceeding a CUF of 1.0.

• Correlate information relative to fatigue monitoring and provide more definitive verification that the transients monitored and their ; limits are consistent with or bound the FSAR and the supporting fatigue analyses, including the environmentally-assisted fatigue analyses.

Final Safety Analysis Report Supplement Page A-50 *

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule ; January 2010
• Columbia Generating StationLicense Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 25) Fire Protection The Fire Protection Program is an existing program that will be A.1.2.25 Ongoing Program continued for the period of extended operation.

26) Fire Water The Fire Water Program is an existing program that will be continued A.1.2.26 Enhancement Program for the period of extended operation, with the following prior to the period enhancements:

of extended* Perform either ultrasonic testing or internal visual inspection of operation. representative portions of above ground fire protection piping that Then ongoing.are exposed to water, but do not normally experience flow, after the issuance of the renewed license, but prior to the end of the current operating term and at reasonable intervals thereafter, based on engineering review of the results.

• Either replace sprinkler heads that have been in place for 50 years or submit.representative samples to a recognized laboratory for field service testing in accordance with NFPA 25 recommendations.

Perform subsequent replacement or fieldservice testing of representative samples at 10-year intervals thereafter or until there are no sprinkler heads installed that will reach 50 years of service life during the period of extended operation.

• Perform hardness testing (or equivalent) of the sprinkler heads as part of their NFPA sampling, to determine whether loss of material due to selective leaching is occurring.

, Final Safety Analysis Report Supplement Page A-51 January 2010* ** Table A-1 Columbia License Renewal Commitments Item Number Commitment

25) Fire Protection The Fire Protection Program is an existing program that will be Program continued for the period of extended operation.

26) Fire Water The Fire Water Program is an existing program that will be continued Program for the of extended operation, with the following

", enhancements:

• Perform either ultrasonic testing or internal visual inspection of .!. representative portions of above ground fire protection piping that are exposed to water, but do not normally experience flow, after the issuance of the renewed license, but prior to the end of the current operating term and at reasonable intervals thereafter, based on engineering review of the results.
• Either replace sprinkler heads that have been in place for 50 years or submitrepresentative samples to a recognized laboratory for field service testing in accordance with NFPA 25 recommendations.

Perform subsequent replacement or field service testing of representative samples at 1 a-year intervals thereafter or until there are no sprinkler heads installed that will reach 50 years of,service life during the period of extended operation.

• Perform hardness testing (or equivalent) of the sprinkler heads as part of their NFPA sampling, to determine whether loss of material due to selective leaching is occurring.

Final Safety Anaiysis Report Supplement Page A-51

• Columbia Generating Station License Renewal Application Technical Information

\ FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.25 Ongoing A.1.2.26 Enhancement prior to the period of extended operation. Then ongoing. January 2010 Columbia Generating-Station License Renewal Application Technical Information Table A-1 Columbia License.Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule27) Flexible The Flexible Connection Inspection is a new activity. A. 1.2.27 Within the 10-Connection The Flexible Connection Inspection detects and characterizes the year period prior-Inspection material condition of elastomer components exposed to treated to the period of water, dried air, gas, and indoor air environments. The inspection extended provides direct evidence as to whether, and to what extent, the operation. relevant effects of aging have occurred.28) Flow-The Flow-Accelerated Corrosion (FAC) Program is an existing A.1.2.28 Enhancement Accelerated program that will be continued for the period of extended operation, prior to the period Corrosion with the following enhancements: of extended (FAC) Program

• Add the Containment Nitrogen System components supplied with operation.

steam from the Auxiliary Steam System to the scope of the Then ongoing.program.* Add gray cast iron as a material identified as susceptible to FAC.29) Fuel Oil The Fuel Oil Chemistry Program is an existing program that will be A.1.2.29 Ongoing Chemistry continued for the period of extended operation. Program Final Safety Analysis Report Supplement Page A-52 January 2010 Final Safety Analysis Report Supplement Page A-52 January 2010Table A-1 -' Columbia License Renewal Commitments Item Number Commitment

27) Flexible The Flexible Connection Inspection is a new activity.

Connection The Flexible Connection Inspection detects and characterizes the Jnspection material condition of elastomer components exposed to treated water, dried air, gas, and indoor air environments. The inspection provides direct evidence as to whether, and to't'hat extent, the relevant effects of aging have occurred.

28) Flow-The Flow-Accelerated Corrosion (FAG) Program is an existing Accelerated program that will be continued for the period of extended operation, Corrosion with the following enhancements: (FAG) Program

• Add the Containment Nitrogen System components supplied with steam from the Auxiliary Steam System to the scope of the program.
• Add gray cast iron as a material identified as susceptible to FAC . 29) Fuel Oil The Fuel Oil Chemistry Program is an program that will be Chemistry continued for the period of extended operation.

Program Final Safety Analysis Report Supplement Page A-52 *

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.27 Within the 10-year period prior to the period of extended operation.

.!' A.1.2.28 , Enhancement

prior to the of extended operation.

Then ongoing. A.1.2.29 Ongoing January 2010

• 0 0 Columbia Generating StationLicense Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or./ Location Implementation ILRA App. A) Schedule 30) Heat The Heat Exchangers Inspection is a new activity.

A.1.2.30 Within the 10-Exchangers The Heat Exchangers Inspection detects and characterizes the year period prior Inspection surface conditions with respect to fouling of heat exchangers and to the period of coolers that are in the scope of the inspection and exposed to treated extended water, closed cooling water, or indoor air. The inspection provides operation. direct evidence as to whether, and to what extent, the relevant effects of aging have occurred.31) High-Voltage The High-Voltage Porcelain Insulators Aging Management Program A.1.2.31 Ongoing Porcelain is an existing program that will be continued for the period of Insulators extended operation. Aging Management Program Final Safety Analysis Report Supplement Page A-53 January 2010*

• Table A-1 Columbia License Renewal Commitments

-Item Number Commitment ) 30) Heat The Heat Exchangers Inspection is a new activity. Exchangers The Heat Exchangers Inspection detects and characterizes the Inspection surface conditions with respect to fouling ofheat exchangers and coolers that are in the scope of the inspection and exposed to treated water, closed cooling water, or indoor air. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred. -31) High-Voltage The High-Voltage Porcelain Insulators Aging Management Program Porcelain is an existing program that will be continued for the period of Insulators extended operation. Aging Management Program -/ Final Safety Analysis Report Supplement Page A-53

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRAApp. A) Schedule A.1.2.30 Within the 10-year period prior to the period of extended operation.

A.1.2.31 Ongoing , January 2010 Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 32) Inaccessible The Inaccessible Medium-Voltage Cables Not Subject to A.1.2.32 Implementation Medium- 10 CFR 50.49 EQ Requirements Program is a new program. prior to the period Voltage Cables The Inaccessible Medium-Voltage Cables Not Subject to of extended Not Subject to 10 CFR 50.49 EQ Requirements Program manages the aging of operation. 10 CFR 50.49 inaccessible medium-voltage cables that are not environmentally Then ongoing.EQ qualified and are within the scope of license renewal. The program Requirements provides for testing to identify the conditions of the conductor Program insulation, and also provides for periodic inspection and drainage (if necessary) of electrical manholes.The frequency of the cable testing portion of the program will be once every 10 years, with the first test to be performed prior to the period of extended operation. The frequency of the manhole inspections will be at least once every two years, with the first inspections to be performed prior to the period of extended operation, 33) Inservice The Inservice Inspection (ISI) Program is an existing program that A.1.2.33 Ongoing Inspection (ISI) will be continued for the period of extended operation. Program 34) Inservice The Inservice Inspection (ISI) Program -IWE is an existing. program A.1.2.34 Ongoing Inspection (ISI) that will be continued for the period of extended operation. Program -IWE 35) Inservice The Inservice Inspection (ISI) Program -IWF is an existing program A.1.2.35 Ongoing Inspection (ISI) that Will be continued for the period of extended operation. Program -IWF Final Safety Analysis Report Supplement Page A-54 January 2010 Final Safety Analysis Report Supplement Page A-54 January 2010 Table A-1 Columbia License Renewal Commitments Item Number Commitment

32) Inaccessible The Inaccessible Medium-Voltage Cables Not Subject to Medium-10 CFR 50.49 EO Requirements Program is a new program. Voltage Cables The Inaccessible Medium-Voltage Cables Not Subject to Not Subject to 10 CFR 50.49 EO Requirements Program manages the aging of 10 CFR 50.49 inaccessible medium-voltage cables that are not environmentally EO qualified and are within the scope of license renewal. The program Requirements provides for testing to identify the condition's of the conductor Program insulation, and also provides for periodic inspection and drainage (if necessary) of electrical manholes, The frequency of the cable testing portion of the program will be once every'10 years, with the first test to be performed prior to the period of extended operation.

The frequency of the manhole inspections will be at least once every two years, with the first inspections to be performed prior to the period of extended operation, 33) Inservice The Inservice Inspection (lSI) Program is an existing program that Inspection (lSI) will be continued for the period of extended operation. Program 34) Inservice The Inservice Inspection (lSI) Program:'" IWE is an existing program Inspection (lSI) that will be continued for the period of extended operation. Program -IWE 35) Inservice The Inservice Inspection (lSI) Program -IWF is an existing program Inspection (lSI) that will be continued for the period of extended operation. Program -IWF Final Safety Analysis Report Supplement Page A-54 *

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRAApp. A) Schedule A.1.2.32 Implementation prior to the period of extended operation.

Then ongoing. A.1.2.33 Ongoing A.1.2.34 Ongoing A.1.2.35 Ongoing January 2010

• Columbia Generating StationLicense Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA Appn A) Schedule 36) Lubricating Oil The Lubricating Oil Analysis Program is an existing program that will A.1.2.36 Enhancement Analysis be continued for the period of extended operation, with the following -prior to the period Program enhancements:

..of extended* Include the following Fire Protection System components that are operation. exposed to lubricating oil within the scope of the program: (1) fire Then ongoing.protection diesel engine heat exchangers (lube oil coolers), (2)fire protection diesel engine lube oil piping, and (3) fire protectiondiesel engine lube oil pump casings.37) Lubricating Oil The Lubricating Oil Inspection is a new activity. A.1.2.37 Within the 10-Inspection The Lubricating Oil Inspection detects and characterizes the year period prior condition of materials in systems and components for which the' to the period of Lubricating Oil Analysis Program is credited with aging management. extended The inspection provides direct evidence as to whether, and to what operation.extent, the relevant effects of aging have occurred.Final Safety Analysis Report Supplement Page A-55 January 2010*

• Table A-1 --Columbia License Renewal Commitments Item Number Commitment

-36) Lubricating Oil . The Lubricating Oil Analysis Program is an existing program that will Analysis be continued for the period of with the following Program enhancements:' '/

• Include the following Fire Protection System components that are exposed to lubricating oil within the scope of the program: (1) fire protection diesel engine heat exchangers (lube oil coolers), (2) fire protection diesel engine lube oil piping, and (3) fire protection diesel engine lube oil pump casings. 37) Lubricating Oil The Lubricating Oil Inspection is a new activity.

Inspection The Lubricating Oil Inspection detects and characterizes the condition of materials in systems and components for which the Lubricating Oil Analysis Program is credited with aging management. The inspection provides direct evidence as to whether, and to what _ extent, the relevant effects of aging have occurred. Final Safety Analysis Report Supplement Page A-55

• Columbia Generating Station License Renewal Application Technical Information , FSAR Enhancement Supplement or Location Implementation (LRA App, A) Schedule A.1.2.36 Enhancement -iprior to the period ,'of extended i, operation. , Then ongoing. i A.1.2.37 Within the 10-year period prior ; to the' period of extended operation. , January 2010 Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A)_j Schedule.38) Masonry Wall The Masonry Wall Inspection is an existing program that will be A.1.2.38 Enhancement Inspection continued for the period of extended operation, with the following prior to the period enhancements:

of extended Specify that for each masonry wall, the extent of observed operation. masonry cracking or degradation of steel edge supports and Then going.bracing are evaluated to ensure that the current evaluation basis is still valid. Corrective action is required if the extent of masonry cracking or steel degradation is sufficient to invalidate the evaluation basis. An option is to develop a new evaluation basis that accounts for the degraded condition of the wall (i.e., acceptance by further evaluation).

39) Material The Material Handling System Inspection Program is an existing A.1.2.39 Enhancement Handling program that will be continued for the period of extended operation, prior to the period System with the following enhancement:

of extended Inspection

• Ensure jib cranes and electrically operated hoists are visually operation.

Program inspected for corrosion. Then ongoing.Final Safety Analysis Report Supplement Page A-56 January 2010 Table A-1 Columbia License Renewal Commitments Item Number Commitment

38) Masonry Wall The Masonry Wall Inspection is an existing program that will be Inspection continued for the period of extended operation, with the following enhancements:

• Specify that for each masonry wall, the extent of observed masonry cracking or degradation of steel edge supports and bracing are evaluated to ensure that the current evaluation basis is still valid. Corrective action is required if the extent of masonry cracking or steel degradation is sufficient to invalidate the evaluation basis .. An option is to develop a new evaluation basis that accounts for the degraded condition of the wall (Le., acceptance by further evaluation).

39) Material The Material Handling $ystem Inspection Program is an existing Handling program that will be continued for the period of extended operation, System with the following enhancement:

Inspection

• Ensure jib cranes and electrically operated hoists are visually Program inspected for corrosion.

Final Safety Analysis Report Supplement Page A-56 *

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement

or Location Implementation (LRA App. A) Schedule A.1.2.38 Enhancement prior to the period of extended operation.

Then going. A.1.2.39 Enhancement

• prior to the period of extended .' operation.

Then ongoing. January 2010

• Columbia Generating StationLicense Renewal Application Technical Information Table A-I Columbia License Renewal Commitments Item Number Commitment FSAR Supplement Location (LIRA App. A)Enhancement or Implementation Schedule__ i ______________________________________________

I ___________ I ____________

40) Metal-Enclosed Bus Program The Metal-Enclosed Bus Program is a new program.The Metal-Enclosed Bus Program is an inspection program that detects degradation of metal-enclosed bus within the scope of license renewal. The program provides for the visual inspection of interior sections of bus, and an inspection of the elastomeric seals at the joints of the duct sections.

The program also makes provision for thermographic inspection of bus bolted connections. The thermography portion of the program will be performed once every 10 years, with the initial inspections to be performed prior.to the period of extended operation. The visual inspection portion of the program will also be performed once every 10 years, with the first inspections to be performed prior to the period of extended operation. A.1.2.40 Implementation prior to the period of extended operation. Then ongoing.41) Monitoring and The Monitoring and Collection Systems Inspection is a new activity. A.1.2.41 Within the 10-Collection The Monitoring and Collection Systems Inspection detects and year period prior Systems characterizes the condition of materials at the internal surfaces of to the period of Inspection subject mechanical components that are exposed to equipment or extended'area drainagewater and other potential contaminants and fluids. operation. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred.Final Safety Analysis Report Supplement Page A-57 January 2010 Final Safety Analysis Report Supplement Page A-57 January 2010 e e ... Table A-1 Columbia License Renewal Commitments Item Number Commitment

40) Metal-Enclosed The Metal-Enclosed Bus Program is a new program. Bus Program The Metal-Enclosed Bus Program is an inspection program that detects degradation of metal-enclosed bus within the scope of license renewal. The program provides for the visual inspection of interior sections of bus, and an inspection of the elastomeric seals at the joints of the duct sections.

The program also makes provision for thermographic inspection of bus bolted connections. The thermography portion of the program will be performed once every 10 years, with the initial inspections to be performed prior to the period of extended operation. The vis,.ual inspection portion of the program will also be performed once every 10 years, with the first inspections to be performed prior to the period of extended operation.

41) Monitoring and The Monitoring and Collection Systems Inspection is a new activity.

Collection The Monitoring and Collection Systems Inspection detects and Systems characterizes the condition of materials at the internal surfaces of Inspection subject mechanical components that are exposed to equipment or area drainage *water and other potential contaminants and fluids. The inspection provides direct evidence as to whOether, and to what . extent, the relevant effects of aging have occurred. Final Safety Analysis Report Supplement PageA-S7 e* Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location 1m plementation (LRA. App. A) Schedule A.1.2.40 Implementation prior to the period of extended operation. , Then A.1.2.41 . Within the 10-year period prior to the period of extended' operation. January 2010 Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Supplement or Item Number Commitment Supplemnt eo Location Implementation (LRA App. A) Schedule 42) Open-Cycle The Open-Cycle Cooling Water Program is an existing program that A.1.2.42 Enhancement Cooling Water will be continued for the period of extended operation, with the prior to the period Program following enhancements: of extended* Address loss of material due to cavitation erosion (for the operation. Standby Service Water (SW), Circulating Water (CW), Plant Then ongoing.Service Water (TSW), and Tower Make-Up (TMU) systems) with activities such as opportunistic inspections of portions of the systems that have had indications of cavitation erosion in the past.* Include the non-safety related components within the license renewal scope in the SW, CW, TSW, and TMU systems, and the non-safety related components served by or connected to the TSW System that are in the Process Sampling, Process Sampling Radioactive, Radwaste Building Mixed Air, Radwaste Building Return Air, Reactor Building Return Air, and Reactor Closed Cooling Water systems.Final Safety Analysis Report Supplement Page A-58 January 2010 Table A-1 Columbia License Renewal Commitments Item Number Commitment

42) Open-Cycle

' The Open-Cycle Cooling Water Program is an existing program that Cooling Water will be continued for theperiod of extended operation, with the Program following enhancements:

• Address loss of material due to cavitation erosion (for the Standby Service Water (SW), Circulating Water (CW), Plant Service Water (TSW), and Tower Make-Up (TMU) systems) with activities such as opportunistic inspections of portions of the systems that have had indications of cavitation erosion in the past.
• Include the non-safety related components within the license renewal scope in the SW, CW, TSW, and TMU systems, and the non-safety related components served by or connected to the TSW System *that are in the Process Sampling, Process Sampling Radioactive, Radwaste Building Mixed Air, Radwaste Building Return Air, Reactor Building Return Air, and Reactor Closed Cooling Water systems. ) Final Safety Analysis Report Supplement Page A-58 *
• 1 Columbia Generating Station License Renewal Application Technical Information I FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.42 Enhancement prior to the period of extended operation.

Then ongoing. January 2010

• Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation S(LPRA App. A)+/- Schedule 43) Potable Water The Potable Water Monitoring Program is an existing program that A.1.2.43 Enhancement Monitoring will be continued for the period of extended operation, with the and inspection Program following enhancements:

within the 10-year* Include periodic inspection activities. Based on operating period prior to theit is necessary that inspections be conducted at least period of once every five years, and include components of the Potable extended Cold Water and Potable Hot Water systems that are located in operation. the Reactor Building, and components associated with the Then ongoing.Reactor Building Outside Air (ROA) air washer (ROA-AW-1), including the air washer housing.At least one inspection will be conducted within the 10-year period prior to the period of extended operation.

44) Preventive The Preventive Maintenance

-RCIC Turbine Casing is an existing A. 1.2.44 Ongoing Maintenance -program that will be continued for the period of extended operation.RCIC Turbine Casing 45) Reactor Head The Reactor Head Closure Studs Program is an existing program A.1.2.45 Ongoing Closure Studs that will be continued for the period of extended operation. Program 46) Reactor Vessel The Reactor Vessel Surveillance Program is an existing program that A.1.2.46 Ongoing Surveillance will be continued for the period of extended operation. Program Final Safety Analysis Report Supplement Page A-59 January 2010* * --Table A-1 Columbia License Renewal Commitments Item Number Commitment

43) Potable Water The Potable Water Monitoring Program is an existing program that Monitoring will be continued for the period of extended operation, with the Program following enhancements:

• Include periodic inspection activities.

Based on operating , experience, it is necessary that inspections be conducted at least once every five years, and include components of the Potable Cold Water and Potable Hot Water systems that are located in the Reactor Building, and components associated with the Reactor Building Outside Air (ROA) air washer(ROA-AW-1), including the air washer housing. At least one inspection will be conducted within the 10-year period prior to the period of extended operation.

44) Preventive The Preventive Maintenance

-RCIC Turbine Casing is an existing Maintenance -program that will be continued for the period of extended operation. RCIC Turbine Casing 45) Reactor Head The Reactor Head Closure Studs Program is an existing program Closure Studs that will be continued for the period of extended operation. \ Program 46) Reactor Vessel The Reactor Vessel Surveillance Program is an existing program that Surveillance . will be continued for the period of extended operation . Program Final Safety Analysis Report Supplement Page A-59

• Columbia Generating Station License Renewal Application Technical Information t FSAR Enhancement Supplement or Location Implementation App. A) Schedule A.1.2.43 Enhancement and inspection within the 10-year period prior to the period of extended operation.

Then ongoing. A.1.2.44 Ongoing A.1.2.45 Ongoing A.1.2.46 Ongoing January 2010 Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule47) Selective The Selective Leaching Inspection is a new activity. A. 1.2.47 Within the 10-Leaching The Selective Leaching Inspection detects and characterizes the year period prior Inspection conditions on internal and external surfaces of subject components to the period of exposed to raw water, treated water, fuel oil, soil, and moist air extended (including condensation) environments. The inspection provides operation. direct evidence through a combination of visual examination and hardness testing, or NRC-approved alternative, as to whether, and to what extent, the relevant effects of aging have occurred.48) Service Air The Service Air System Inspection is a new activity. A.1.2.48 Within the 10-System The Service Air System Inspection detects and characterizes the year period prior Inspection material condition of steel piping and Valve bodies exposed to an "air to the period of (internal)" (i.e., compressed air) environment within the license extended renewal boundary of the Service Air System. The inspection operation. provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred.Final Safety Analysis Report Supplement Page A-60 January 2010 Table A-1 Columbia License Renewal Commitments ". Item Number Commitment

47) Selective The Selective Leaching Inspection is anew activity.

Leaching The Selective Leaching Inspection detects and characterizes the Inspection conditions on internal and external surfaces of subject components exposed to raw water, treated water, fuel oil, soil, and moist air (including condensation) environments. The inspection provides direct evidence through a combination of visual examination and hardness testing, or NRC-approved alternative, as to whether, and to what extent, the relevant effects of aging have occurred.

48) Service Air The Service Air System Inspection is a new activity.

System The Service Air System Inspection detects and characterizes the Inspection material condition of steel piping and valve bodies exposed to an "air (internal)" (Le., compressed air) environment within the license renewal boundary of the Service Air System. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred. Final Safety Analysis Report Supplement PageA-60 *

• FSAR Columbia Generating Station License Renewal Application Technical Information , , Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.47 Within the 10-year period prior to the period extended" operation.

A.1.2.48 Within the 10-year period prior to the period of extended operation. -January 2010

• Columbia Generating StationLicense Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule49) Small Bore The Small Bore Class 1 Piping Inspection is a new activity.

A.1.2.49 Within the portion Class 1 Piping The Small Bore Class 1 Piping Inspection will detect and characterize of the fourth 10-Inspection the conditions on the internal surfaces of small bore Class 1 piping year IS[ interval components that are exposed to reactor coolant. The Small Bore that occurs prior Class 1 Piping Inspection will provide physical evidence as to to the period of whether, and to what extent, the relevant effects of aging have extended occurred. operation. The Small Bore Class 1 Piping Inspection includes visual and volumetric inspection of a representative sample of small bore Class 1 piping components. The inspection provides additional assurance that cracking of small bore Class 1 piping is not occurring or is insignificant, such that an aging management program is not warranted during the period of extended operation. This one-time inspection is appropriate as Columbia has not experienced cracking of small bore Class 1 piping from stress corrosion or thermal and mechanical loading. Should evidence of significant aging be revealed by the one-time inspection or through plant operating experience, periodic inspection will be considered asa plant-specific aging management program.Final Safety Analysis Report Supplement Page A-61 January 2010* Item Number 49) Small Bore Class 1 Piping Inspection

• Table A-1 Columbia License Renewal Commitments Commitment The Small Bore Class 1 Piping Inspection is a new activity.

The Small Bore Class 1 Piping Inspection will detect and characterize the conditions on the internal surfaces of small bore Class 1 piping components that are exposed to reactor. coolant. The Small Bore Class 1 Piping Inspection will provide physical evidence as to whether, . and to what extent, the relevant effects of aging have occurred. The Small Bore Class 1 Piping Inspection includes visual and volumetric inspection of a representative sample of small bore Class 1 piping components. The inspection provides additional assurance that cracking of small bore Class 1 piping is not occurring or is insignificant, such that an aging management program is not warranted during the period of extended operation. This one-time inspection is appropriate as Columbia has not experienced cracking of small bore Class 1 piping from stress corrosion or thermal and mechanical loading. Should evidence of significant aging be revealed by the one-time inspection or through plant operating experience, periodic inspection will be considered as a plant-specific aging management program. Final Safety Analysis Report Supplement PageA-61

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation ILRA ADD. Al ,----I I , Schedule A.1.2.49 Within the portion of the fourth 10-'. , year lSI interval that occurs prior to the period of extended operation. . January 2010 ,

Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 50) Structures The Structures Monitoring Program is an existing program that will be A. 1.2.50 Enhancement Monitoring continued for the period of extended operation, with the following prior to the period Program enhancements: of extended e Include and list the structures within the scope of license renewal operation. that credit the Structures Monitoring Program for aging Then ongoing.management.

• Specify that if a below grade structural wall or structural component becomes accessible through excavation; a follow-up action is initiated for the responsible engineer to inspect the exposed surfaces for age-related degradation prior to backfilling.
• Identify that the term "structural component" for inspection includes component types that credit the Structures Monitoring Program for aging management.

e Include the potential degradation mechanism checklist in the procedural documents. The checklist also requires enhancement to include aging effect terminology (e.g., loss of material, cracking, change in material properties, and loss of form).FialSaey nayisReot upleet ag -6 Jnar 21 Final Sa ty Analysis Report Supplement Page A-62 January 2010 Table A-1 / Columbia License Renewal Commitments Item Number Commitment

50) Structures The Structures Monitoring Program is an existing program that will be Monitoring continued for the period of extended operation, with the following Program enhancements:

• Include and list the structures within the scope of license renewal that credit the Structures Monitoring Program for aging management.
• Specify that if a below grade structural wall or structural component becomes accessible through excavation; a follow-up action is initiated for the responsible engineer to inspect the exposed surfaces for age-related degradation prior to backfilling.
• Identify that the term "structural component" for inspection includes component types that credit the Structures Monitoring Program for aging management.
• Include the potential degradation mechanism checklist in the procedural documents.

The checklist also requires enhancement to include aging effect terminology (e.g., loss of material, cracking, ; change in material properties, and loss of form). , -Final Safety Analysis Report Supplement Page A-62 *

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRAApp. A) Schedule A.1.2.50 Enhancement prior to the period of extended operation.

Then ongoing. January 2010

• Columbia Generating StationLicense Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 50) Structures
• Specify that the responsible engineer shall review site Monitoring groundwater and raw water testing results for pH, chlorides, and Program sulfates prior to inspection to validate that the below-grade or raw (cont'd) water environments remain non-aggressive during the period of extended operation.

Chemistry data shall be obtained from Columbia's chemistry and environmental departments. Groundwater chemistry data shall be collected at least once every four years. The time of data collection shall be staggered from year to year (summer-winter-summer) to account for seasonal variations in the environment.

51) Supplemental The Supplemental Piping/Tank Inspection is a new activity.

A.1.2.51 Within the 10-Piping/Tank The Supplemental Piping/Tank Inspection detects and characterizes year period prior Inspection the material condition of steel, gray cast iron, and stainless steel to the period of components exposed to moist air environments. The inspection extended provides direct evidence as to whether, and to what extent, the operation. relevant effects of aging have occurred.Final Safety Analysis Report Supplement Final Safety Analysis Report Supplement Page A-63 January 2010 Page A-63 January 2010*

• Table A-1 Columbia License Renewal Commitments Item Number Commitment

50) Structures

• Specify that the responsible engineer shall review site Monitoring groundwater and raw water testing results for pH, chlorides, and Program sulfates prior to inspection to validate that the below-grade or raw (cont'd) water environments remain non-aggressive during the period of extended operation.

Chemistry data shall be obtained from Columbia's chemistry and environmental departments. Groundwater chemistry data shall be collected at least once every four years. The time of data collection shall be staggered from year to year (summer-winter-summer) to account for seasonal variations in the environment.

51) Supplemental The Supplemental PipingfTank Inspection is a new activity.

PipingfTank The Supplemental PipingfTank Inspection detects and characterizes Inspection the material condition of steel, gray cast iron, and stainless steel components exposed to moist air environments. The inspection provides direct evidence as to whether, and to what extent, the relevant effects of aging have occurred. Final Safety Analysis Report Supplement PageA-63 i,. Columbia Generating Station License Renewal Application , Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.2.51 Within the 10-year period prior to the period of extended operation. January 2010 Columbia Generating StationLicense Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR [ Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A)' Schedule52) Thermal Aging The Thermal Aging and Neutron Embrittlement of Cast Austenitic A.1.2.52 Implementation and Neutron Stainless Steel (CASS) Program is a new program. prior to the period Embrittlement The Thermal Aging and Neutron Embrittlement of Cast Austenitic of extended of Cast Stainless Steel (CASS) Program will manage loss of fracture operation. Austenitic toughness due to thermal aging and neutron irradiation embrittlement Then ongoing.Stainless Steel of CASS reactor vessel internals.(CASS) The program includes: (a) identification of susceptible components Program determined to be limiting from the standpoint of thermal aging or neutron irradiation embrittlement (neutron fluence), (b) a component-specific evaluation to determine each identified component's susceptibility to loss of fracture toughness, and (c) a supplemental examination of any component not eliminated by the component-specific evaluation. 1-inal ~atety Analysis Report Supplement Page A-64 January 2010 Final Safety Analysis Report Supplement Page A-64 January 2010 Table A-1 Columbia License Renewal Commitments Item Number Commitment

52) Thermal Aging The Thermal Aging and Neutron Embrittlement of Cast Austenitic and Neutron Stainless Steel (CASS) Program is a new program. Embrittlement The Thermal Aging and Neutron Embrittlement of Cast Austenitic of Cast Stainless Steel (CASS) Program will manage loss of fracture Austenitic toughness due to thermal aging and neutron irradiation embrittlement Stainless Steel of CASS reactor vessel internals. (CASS) The program includes: (a) identification of susceptible components Program determined to be limiting from the standpoint of thermal aging or neutron irradiation embrittlement (neutron fluence), (b) a component-specific evaluation to determine each identified component's susceptibility to loss of fracture toughness, and (c) a supplemental examination of any component not eliminated by the component-specific evaluation.

Final Safety Analysis Report Supplement Page A:-64 *

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) .

A.1.2.52 Implementation prior to the period of eXtended operation. Then ongoing. I January 2010

• 0 Columbia Generating Station,License Renewal Application Technical Information Table-A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA Apo. A) Schedule 53) Water Control The Water Control Structures Inspection is an existing program that A. 1.2.53 Enhancement Structures will be continued for the period of extended operation, with the prior to the period Inspection following enhancements:

of extended* Include and list the water control structures within the scope of operation. license renewal. Include the RG 1.127 Revision 1 inspection Then ongoing.elements for the water control structures, including submerged surfaces. Ensure descriptions of concrete conditions conform with the appendix to the American Concrete Institute (ACI) publication, ACI 201, "Guide for Making a Condition Survey of Concrete in Service." Add a recommendation to use photographs for comparison of. previous and present conditions. Add a requirement for the documentation of new or progressive problems as a part of the inspection program. Final Safety Analysis Report Supplement Page A-65 January 2010* Item Number 53) Water Control Structures Inspection

• Table-A-1 Columbia License Renewal Commitments Commitment The Water Control Structures Inspection is an existing program that will be continued for the period of extended operation, with the following enhancements:

-* Include and list the water control structures within the scope of license renewal. Include the RG 1.127 Revision 1 inspection elements for the water control structures, including submerged surfaces. Ensure descriptions of concrete conditions conform with the appendix to the American Concrete Institute (ACI) publication, ACI 201, "Guide for Making a Condition Survey of Concrete in Service." Add a recommendation to use photographs for comparison of _ previous and present conditions. Add a requirement for the documentation of new or progressive problems as a part of the inspection program. Final Safety Analysis Report Supplement PageA-65

• Columbia Station License Renewal Application Technical Information FSAR Supplement Location (LRA App. A) A.1.2.53 Enhancement or 1m plementation Schedule Enhancement prior to the period of extended operation . Then ongoing. January 2010 Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 54) Pressure-The Columbia P-T limit curves were revised in 2005 to include the A. 1.3.1.4 Ongoing Temperature effects of power uprate to 3486 MWt. The P-T limits are valid for Limits 33.1 EFPY through the end of the currently licensed period. P-T limits for the period of extended operation will be calculated using the most accurate fluence projections available at the time of the recalculation.

The projections may be adjusted if there are changes in core design or if additional surveillance capsule results show the need for an adjustment. The projected ART for the period of extended operation gives confidence that future P-T curves will provide adequate operating margin.License amendment requests to revise the P-T limits will be submitted to the NRC for approval, when necessary to comply with 10 CFR 50 Appendix G, as part of the Reactor Vessel Surveillance Program.55) Incorporate Energy Northwest will incorporate the FSAR SUpplement into the A.1 Following FSAR Columbia FSAR as required by 10 CFR 54.21 (d). A. 1.1 issuance of the Supplement renewed operating license.56) Operational The elements of corrective actions, confirmation process, and A.1.2 Prior to the period Quality administrative controls in the OQAPD will be applied to required of extended Assurance aging mnanagement programs for both safety-related and non-safety operation. Program related structures and components determined to require aging Description management during the period of extended operation. Final Safety Analysis Report Supplement Page A-66 January ý01 0 Table A-1 Columbia License Renewal Commitments Item Number Commitment

54) Pressure-The Columbia P-T limit curves were revised in 2005 to include the . Temperature effects of power uprate to 3486 MWt. The P-T limits are valid for Limits 33.1 EFPY through the end of the currently licensed period. P-T limits for the period of extended operation will be calculated using the most accurate f1uence projections available at the time of the recalculation.

The projections may be adjusted if there are changes in core design or if additional surveillance capsule results show the , need for an adjustment. The projected ART for the period of -;-extended operation gives confidence that future P-T curves will provide adequate operating margin. License amendment requests to revise the P-T limits will be submitted to the NRC for approval, when necessary to comply with 10 CFR 50 Appendix G, as part of the Reactor Vessel Surveillance Program. 55) Incorporate Energy Northwest will incorporate the FSAR Supplement into the FSAR Columbia FSAR as required by 10 CFR 54.21(d). Supplement

56) Operational The elements of corrective actions, confirmation process, and Quality administrative controls in the OQAPD will be applied to required Assurance aging management programs for both safety-related and non-safety Program related structures and components determined to require aging Description management during the period of extended operation:

Final Safety Analysis Report Supplement PageA-66 *

• Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule . A.1.3.1.4 Ongoing A.1 Following A.1.1 issuance of the renewed operating license. ) A.1.2 Prior to the period of extended operation.

January 2010

• Columbia Generating StationLicense Renewal Application Technical Information Table A-1Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 57) License The commitments identified in association with Columbia license A.1.5 Upon submittal of Renewal renewal will be tracked within the Columbia regulatory commitment the license Commitment management program. renewal List application to the NRC.58) BWRVIP-42-A, In accordance with the BWR Vessel Internals Program, Columbia will LRA Based on NRC AAI#5 implement the additional inspection requirements of BWRVIP-42-A Appendix C schedule.once those requirements are approved by the NRC staff.59) BWRVIP- 116 Energy Northwest will submit a licensing basis change request to LRA Two years prior to implement the BWRVIP ISP(E) at least two years prior to the period Appendix C the period of of extended operation.

Columbia will implement the ISP(E) as extended amended by the BWRVIP letter of January 11, 2005, including the operation. new capsule test schedule in Table 1 of that letter.Final Safety Analysis Report Supplement Page A-67 January 2010* * -Table A-1 -) Columbia License Renewal Commitments --Item Number Commitment

57) License The commitments identified in association with Columbia license Renewal renewal will be tracked within the Columbia regulatory commitment Commitment management program. List 58) BWRVIP-42-A, In accordance with the BWR Vessel Internals Program, Columbia will AAI#5 implement the additional inspection requirements of BWRVIP-42-A once those requirements are approved by the NRC staff. 59) BWRVI P-116 Energy Northwest will submit a licensing basis change request to implement the BWRVIP ISP(E) at least two years prior to the period of extended operation.

Columbia will implement the ISP(E) as amended by the BWRVIP letter of January 11, 2005, including the -new capsule test schedule in Table 1 of that letter. Final Safety Analysis Report Supplement PageA-67 * . Columbia Generating Station License Renewal Application Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule A.1.5 Upon submittal of the license -renewal, application to the NRC. LRA Based on NRC Appendix C schedule. LRA Two years prior to Appendix C the period of extended operation. January 2010 Columbia Generating Station License Renewal Application Technical Information Table A-1 Columbia License Renewal Commitments FSAR Enhancement Item Number Commitment Supplement or Location Implementation (LRA App. A) Schedule 60) BWRVIP-116 Implementation of the BWRVIP ISP(E) for Columbia will include the LRA On-going following details in support of the contingency plan: Appendix C(1) Energy Northwest will include the requirement to keep all testedmaterial (irradiated or unirradiated) for possible future reconstitution and testing.(2) The-Columbia site procedure, as modified, will continue torequire any capsules removed from the reactor vessel to be stored in a manner that would support future re-insertion of these capsules in the reactor vessel.(3) Energy Northwest will notify the BWRVIP prior to any change in the storage of on-site materials. NRC approval will be obtained prior to any change in the storage of surveillance materials that would affect the potential use of the materials under the contingency plan.Final Safety Analysis Report Supplement Page A-68 January 2010 Table Columbia License Renewal Commitments Item Number Commitment

60) BWRVIP-116 Implementation of the BWRVIP ISP(E) for Columbia will include the following details in support of the contingency plan: (1 ) Energy Northwest will include the requirement to keep all tested material (irradiated or unirradiated) for possible future reconstitution and testing .. (2) The 'Columbia site procedure, as modified, will continue to require any capsules removed from the reactor vessel to be / stored in a manner that would support future re-insertion of these capsules in the reactor vessel. (3) Energy Northwest will notify the BWRVIPprior to any change in the storage of on-site materials.

NRC approval will be obtained prior to any change in the storage of surveillance materials that would affect the potential use of the materials under the contingency plan. Final Safety Analysis Report Supplement PageA-68 *

• Columbia Generating Station License Renewal Application . Technical Information FSAR Enhancement Supplement or Location Implementation (LRA App. A) Schedule LRA On-going Appendix C* J January 2010
• Columbia Generating -Station License Renewal Application Technical Information APPENDIX BAGING MANAGEMENT PROGRAMS Aging Management Programs Page B-1 January 2010* * * / APPENDIX B Columbia Generating Station License Renewal Application Technical Information AGING MANAGEMENT PROGRAMS \ Aging Management Prograrns Page 8-1 January 2010 Columbia Generating Station License Renewal Application Technical Information

[This page intentionally blank]Aging Management Programs Page B-2 January 2010" [This page intentionally blank] / Aging Management Programs Page B-2 Columbia Generating Station License Renewal Application Technical Information January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information APPENDIX B TABLE OF CONTENTS B .0 A ging M anagem ent Program s .....................................

....................................... 7 B .1 Intro d uctio n ....................................................................................................... .....7 B .1.1 O verview ..... .......................................................................................... ..7'3.1.2 Method of Discussion .............. .......................... 7 B.1.3 Quality Assurance Program and Administrative Controls .................................. 8 B.1.4 .O perating Experience ...................................................................................... ..9 B.1.5 Aging M anagem ent Program s ....................................................................... .10 B.2 Aging Management Programs.... ........................... .. 11 B.2.1 Aboveground Steel Tanks Inspection ..................................................... .... 26 B.2.2 Air Q uality Sam pling Program ............................ ................................. 30 B'2.3 A ppendix J P rogram ........................................................................................ 34 B.2.4 Bolting Integrity Program .................................. ... 37 B.2.5 Buried Piping and Tanks Inspection Program ........... .............................. 39 B.2.6 BW R Feedwater Nozzle Program .................................................................. 41 B.2.7 BWR Penetrations Program ................................... 44 B.2.8 BWR Stress Corrosion Cracking Program ...........

• .........................................

47 B.2.9 BWR Vessel ID Attachment Welds Program .................................................... 51 B.2.10 BW R Vessel Internals Program ..................................................................... 54 B.2.1 1 BW R W ater Chem istry Program ..................................................................... 57 B.2.12 Chemistry Program Effectiveness Inspection................... ....................... 60 B.2.13 Closed Cooling Water Chemistry Program ................ .......... 63 B .2.14 C ooling U nits Inspection ................................................................................. 66 B.2.15 C RD R L Nozzle Program ................................................................................ 70 B.2.16 Diesel Starting A ir Inspection ......................................................................... 73 B.2.17 D iesel System s Inspection .............................................................................. 77 B.2.18 Diesel-Driven Fire Pum ps Inspection .............................................................. 81 B.2.19 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ R equirem ents P rogram ................................................................................... 85 Aging Management Programs Page B-3 January 2010* *

• APPENDIX B TABLE OF CONTENTS Columbia Generating Station License Renewal Application Technical Information B.O Aging Management Programs ..........................................................................................

7 B.1 Introduction .................................................................................................................... 7 B.1.1 Overview ........................................ -....................................................................... 7 'B.1.2 Method of Discussion ..........................

.................................................................

7 B.1.3 Quality Assurance Program and Administrative Controls ...................................... 8 B.1.4 _ Operating Experience ....................... , .................................................................... 9 B.1.5 . Aging Management Programs ............................................................................. 10 B.2 Aging Management Programs .....................

...............................................................

11 B.2.1 Aboveground Steel Tanks Inspection .................................................................. 26 B.2.2 Air Quality Sampling Program ............................................................................. 30 B'.2.3 Appendix "I Program .................................. ' .......................................................... 34 B.2.4 Bolting IntE!grity Program ........................................

............................................

37 B.2.5 Buried Piping and Tanks Inspection Program .... : ................................................ 39 B.2.6 BWR Feedwater Nozzle Program ....................................................................... 41 B.2.7 BWR Penetrations Program ...................

............................................................

44 B.2.8 BWR Stress Corrosion Cracking Program ..........

...............................................

47 8.2.9 BWR VessellD Attachment Welds Program ....................................................... 51 B.2.10 BWR Vessel Internals Program ........................................................................... 54 B.2.11 BWR Water Chemistry Program .......................................................................... 57 B.2.12 Chemistry Effectiveness Inspection ........................... .......................... 60 B.2.13 Closed Cooling Water Chemistry Program ..........................................

...............

63 B.2.14 Cooling Units Inspection ...................................................................................... 66 B.2.15 CRDRL Nozzle Program ..................................................................................... 70 B.2.16 Diesel Starting Air Inspection .............................................................................. 73 B.2.17 Diesel Systems Inspection .................................................................................. 77 B.2.18 Diesel-Driven Fire.Pumps Inspection .................................................................. 81 , B.2.19 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program ....................................................................................... 85 Aging Management Programs Page B-3 January 2010 Columbia Generating Station License Renewal Application Technical Information APPENDIX B TABLE OF CONTENTS'B.2.20 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program .............................. 89 B.2.21 Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements In s p e ctio n ...................................................................................................... ..94 B .2 .22 E Q P rogram ................................................................................................. ..98 B.2.23 External Surfaces Monitoring Program .................................................. ............ 101 B.2.24 Fatigue Monitoring Program ............................ .................................. 104 B.2.25 Fire Protection Program ..................................... 108 B .2 .26 F ire W ater P rogram ........................................................................................... 111 B.2.27 Flexible Connection Inspection ..................................... 115 B.2.28 Flow-Accelerated Corrosion (FAC) Program ................................................... 119B .2.29 Fuel O il C hem istry P rogram ......................................... .................................. 121 B.2.30 Heat Exchangers Inspection ............................. .....124 B.2.31 High-Voltage Porcelain Insulators Aging Management Program ...................... 128 B.2.32 Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ R equirem ents P rogram ..................................................................................... 132 B.2.33 Inservice Inspection (ISI) Program .................................................................... 136 B.2.34 Inservice Inspection (ISI) Program -IWE ......................................................... 139 B.2.35 Inservice Inspection (ISI) Program -7 IWF .......................................................... 142 8.2.36 Lubricating Oil Analysis Program ...................................................................... 145 B .2.37 Lubricating O il Inspection .................................................................................. 147 B .2.38 M asonry W all Inspection .................................

.................................................

151 B.2.39 Material Handling System Inspection Program ............................................. 153 B.2.40 Metal-Enclosed Bus Program ............................................................................ 155 B.2.41 Monitoring and Collection Systems Inspection .................................................. 159 B.2.42 Open-Cycle Cooling Water Program ................................................................ 163 B.2.43 Potable Water Monitoring Program ................................................................... 166 B.2.44 Preventive Maintenance -RCIC Turbine Casing .............................................. 169 B.2.45 Reactor Head Closure Studs Program .............................................................. 172 B.2.46 Reactor Vessel Surveillance Program ............................................................... 175 B.2.47 Selective Leaching Inspection ............................................. .... 178 Aging Management Programs Page B-4 January 2010 B.2.20 B.2.21 B.2.22 B.2.23 B.2.24 B.2.25 B.2.26 B.2.27 B.2.28 B.2.29 B.2.30 B.2.31 B.2.32 B.2.33 B.2.34 B.2.35 B.2.36 B.2.37 B.2.38 B.2.39 B.2.40 B.2.41 B.2.42 B.2.43 B.2.44 B.2.45 B.2.46 Columbia Generating Station License Renewal Application

• Technical Information . APPENDIX B TABLE OF CONTENTS . Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Used in Instrumentation Circuits Program ...................................

89 Electrical Cable Connections Not Subject to 10 CFR 50.49 EO Requirements Inspection ... , ........................................................................................................ 94 .',' EO Program ........................................................................................................ 98 External Surfaces Monitoring Program .............................................................. 101 Fatigue Monitoring Program .............................................................................. 104 Fire Protection Program ..................................................................................... 108 Fire Water Program ........................................................................................... 111 Flexible Connection Inspection ....................................................... , ................. 115 Flow-Accelerated Corrosion (FAC) Program ..................................................... 119 Fuel Oil Chemistry Program ........ ..................................................................... 121 Heat Exchangers Inspection .............................................................................. 124 High-Voltage Porcelain Insulators Aging Management Program ...................... 128 Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EO Requirements Program ........................ ,' ............................................................ 132 Inservice Inspection (lSI) Program .................................................................... 136 Inservice Inspection (lSI) Program -IWE ......................................................... 139 Inservice Inspection (lSI) Program -:-*IWF .......................................................... 142 Lubricating Oil Analysis Program ...................................................................... 145 Lubricating Oil Inspection .................................................................................. 147 Masonry Wall Inspection .................................

.................................................

151 Material Handling System Inspection Program ................................................. 153 Metal-Enclosed Bus Program ............................................................................ 155 Monitoring and Collection Systems Inspection .................................................. 159 Open-Cycle Cooling Water Program ................................................................. 163 Potable Water Monitoring Program ................................................................... 166 Preventive Maintenance -RCIC Turbine Casing .............................................. 169 Reactor Head Closure Studs Program ......................................

.......................

172 Reactor Vessel Surveillance Program ............................................................... 175

• B.2.47 Selective Leaching Inspection

........................................................................... 178

• Aging Management Programs Page 8-4 January 2010 Columbia Generating Station License Renewal Application Technical Information APPENDIX B TABLE OF CONTENTS B.2.48 Service A ir System Inspection

........................................................................... 183 B.2.49 Sm all Bore C lass 1 Piping Inspection ............................................................... 187 B.2.50 Structures M onitoring Program .......................................................................... 192 B.2.51 Supplemental Piping/Tank Inspection ........................... 197 B.2.52 Thermal Aging and Neutron Embrittlement of Cast Austenitic Stainless Steel (C A S S ) P ro g ra m ............................................................................................. 2 0 1 B.2.53 W ater Control Structures Inspection .................................................................. 206 Aging Management Programs Page B-5 January 2010* *

• APPENDIX B TABLE OF CONTENTS Columbia Generating Station License Renewal Application Technical Information B.2.48 Service Air System Inspection

........................................................................... 183 B.2.49 Small Bore Class 1 Piping Inspection ............................................................... 187 B.2.50 Structures Monitoring Program .......................................................................... 192 B.2.51 Supplemental PipinglTank Inspection ............................................................... 197 B.2.52 Thermal AUing and Neutron Embrittlement of Cast Austenitic Stainless Steel (CASS) Program ................................................................................................ 201 B.2.53 Water Control Structures Inspection .................................................................. 206 Aging Management Programs Page 8-5 January 2010 Columbia Generating Station License Renewal Application Technical Information [This page intentionally blank]Aging Management Programs Page 6-6 January 2010 Aging Management Programs 1 Page B-6 January 2010 Columbia Generating Station License Renewal Application

• Technical Information r A [This page intentionally blank] *
• Aging Management Programs , Page 8-6 January 2010 Columbia Generating StationLicense Renewal Application Technical Information B.0 AGING MANAGEMENT PROGRAMS B.1 INTRODUCTION B.1.1 Overview License renewal aging rnanagement program descriptions are provided in this appendix for each program credited for managing aging effects based upon the aging management review results provided in Sections 3.1 through 3.6 of this Application.

Each aging management program described in this appendix is evaluated on the basis of 10 program elements in accordance with the guidance in Appendix A.1, Section A.1.2.3 of NUREG-1800, the Standard Review Plan for License Renewal (SRP-LR).B.1.2 Method of Discussion For those existing AMPs that are comparable to the programs described in Sections X and Xl of NUREG-1801, the 'Generic Aging Lessons Learned (GALL) Report," the program evaluation is presented in the following summary format:* Program Description -An abstract of the overall program is provided.* NUREG-1801 Consistency -A statement is~rmade regarding consistency between the Columbia program and the corresponding NUREG-1801 program.* Exceptions to NUREG-1801 -Exceptions to NUREG-1801 programs are identified when elements of the Columbia program are different from the NUREG-1 801 program elements or when elements of the NUREG-1 801 program are not applicable to Columbia. Each exception is listed along with the affected element. A justification is provided for each exception.

• Required Enhancements

-Enhancements to existing programs necessary to ensure consistency with NUREG-1801 or to expand the scope of the program for license renewal are identified. Each enhancement is listed along with theaffected program element and a proposed schedule for completion of the enhancement." Operating Experience -Discussion of operating experience information specific to the program is provided." Conclusion -A conclusion section provides. a statement of reasonable assurance that the program is effective, or will be effective, once enhanced or developed. For those programs that are either new or plant-specific, the above format is followed along with the additional provision of a discussion of each of the 10 elements associated with the program.Aging Management Programs Page B-7 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information B.O AGING MANAGEMENT PROGRAMS B.1 INTRODUCTION

8.1.1 Overview

License renewal aging program descriptions are provided in this appendix for each program crE!dited for managing aging effects based upon the aging management review results provided in Sections 3.1 through 3.6 of this Application. Each aging management program described in this appendix is evaluated on the basis of 10 program elements in accordance with the guidance in Appendix A.1, Section A.1.2.3 of NUREG-1800, the Standard Review Plan for License Renewal (SRP-LR). B.1.2 Method of Discussion For those existing AMPs that are comparable to the programs described in Sections X and XI of NUREG-1801, the "Generic Aging Lessons 'Learned (GALL) Report," the program evaluation is presented in the following summary format:

• Program Description

-An abstract of the overall program is provided .

• NUREG-1801 Consistency -A statement is'made regarding consistency between the Columbia program and the corresponding NUREG-1801 program.
• Exceptions to NUREG-1801

-Exceptions to NUREG-1801 programs are identified when elements of the Columbia program are different from the NUREG-1801 program elements or when elements of the NUREG-1801 program are not to Columbia. Each exception is listed along with the affected element. A justification is provided for each exception. I

• Required Enhancements

-Enhancements to existing programs necessary to ensure consistency with NUREG-1801 or to expand the scope of the program for license renewal are identified. Each enhancement is listed along with the affected program element and a proposed schedule for completion of' the enhancement.

• Operating Expe!rience

-Discussion of operating experience information specific to the program is provided.

• Conclusion -A conclusion section provides*

a statement of reasonable assurance that the program is effective, or will be effective,once enhanced or developed. For those programs that are either new or plant-specific, the above format is followed along with the additional provision of a discussion of each of the 1 0 elements associated with the program. Aging Management Programs Page 8-7 January 2010 Columbia Generating Station License Renewal Application Technical Information B.1.3 Quality Assurance Program and Administrative Controls Three elements of an effective aging management program that are common to each of the aging management programs are corrective actions, confirmation process, and administrative controls. These elements are included in the Operational Quality.Assurance Program Description (OQAPD) for Columbia, which implements the requirements of 10 CFR 50 Appendix B. The OQAPD is described in FSAR ,Sections 3.1.2.1.1, 13.4, and 17.2.Prior to the period of extended operation, the elements of corrective actions, confirmation process, and administrative controls in the OQAPD will be applied to required aging management programs for both safety-related and NSR structures and components determined to require aging management during the period of extended operation. The corrective actions, confirmation process, and administrative controls in the OQAPD, to be applied to the credited aging management programs and activities for the structures and components determined to require aging management, are consistent with the related discussions in the Appendix on Quality Assurance for Aging Management Programs in NUREG-1801, Volume 2.The elements of corrective actions, confirmation process, and administrative controls of the OQAPD are described in the sections below, including a general comparison to theassociated elements of the corresponding NUREG-1801 aging management programs (AMPs), which indicate that the "staff finds the requirements of 10CFR Part 50, Appendix B acceptable to address the corrective actions (and confirmation process)." Corrective Actions: Corrective actions are implemented through the site corrective action program, which includes the initiation, processing, and evaluation of condition reports, that satisfies the requirements of 10 CFR 50, Appendix B, Criterion XVI. Conditions adverse to quality, an all inclusive term used in reference to failures, malfunctions, deficiencies, defective items, and non-conformances are identified, reported to management, and corrected. In. the case of significant conditions adverse to quality, measures are implemented to ensure that the root cause is determined and that corrective actions are taken to preclude recurrence.The corrective action program is the subjectlof periodic NRC examination and Columbia self-assessment and audit. In general, problems are effectively identified, evaluated and prioritized, and effective corrective actions implemented for conditions adverse to quality. Some program shortfalls have been identified, but corresponding process improvement plans have been developed and implemented. The current program is, therefore, adequate for aging management considerations. Aging Management Programs Page 8-8 January 2010 Aging Management Programs Page B-8 January 2010 Columbia Generating Station License Renewal Application Technical Information

8.1.3 Quality

Assurance Program and Administrative Controls --Three elements of an effective aging management program that are common to each of the aging management programs are corrective actions, confirmation process,* and administrative controls. These elements are included in the Operational Quality Assurance Program Description (OQAPD) for Columbia, which implements the requirements of 10 CFR 50 Appendix B. The OQAPD is described in FSAR ,Sections 3.1.2.1.1,13.4, and 17.2. Prior to the period of extended operation, the elements of corrective actions, confirmation process, and administrative controls in the OQAPD will be applied to required aging management programs for both safety-related and NSR structures and components determined to require aging management during the period of extended . . operation. The corrective actions, confirmation process, and administrative controls in the OQAPD, to be applied to the credited aging management programs and activities for the structures and components determined to require aging management, are consistent with the related discussions in the Appendix on Quality Assurance for Aging Management Programs in NUREG-1801, Volume 2.

• The elements of corrective actions, confirmation process, and administrative controls of the OQAPD are described in the sections below, including a general comparison to the associated elements of the corresponding NUREG-1801 aging management programs * (AMPs), which indicate that the "staff finds the requirements of 10 CFR Part 50, Appendix B acceptable to address the corrective actions (and confirmation process)." Corrective Actions: Corrective actions are implemented through the site corrective action program, which includes the initiation, processing, and evaluation of condition reports, that satisfies the requirements of 10 CFR 50, Appendix B, Criterion XVI. Conditions' adverse to quality, an all inclusive term used in reference to failures, malfunctions, deficiencies, defective items, and non-conformances are identified, reported to management, and corrected.

In. the case of Significant conditions adverse to quality, measures are implemented to ensure that the root cause is deterry1ined and that corrective actions are taken to preclude recurrence. The corrective action program is the subject of periodic NRC examination and Columbia self-assessment and audit. In general, problems are effectively identified, evaluated and prioritized, and effective corrective actions implemented for conditions adverse to quality. Some program shortfalls have been. identified, but corresponding process improvement plans* have been developed and implemented. The current program is, therefore, adequate for aging management considerations. Aging Management Programs Page 8-8 January 2010

• Columbia Generating Station* License Renewal Application Technical Information Confirmation Process: The focus of the confirmation process is on the follow-up actions taken to verify effective implementation

'of corrective actions and preclude repetition of significant conditions adverse to quality. The corrective action- program includes the requirement that measures be taken to preclude repetition of significant conditions adverse to quality.These measures include actions to verify effective implementation of proposed corrective actions. The confirmation process is part of the corrective action program and, for significant conditions adverse to quality, includes:* reviews to assure proposed actions are adequate,* tracking and reporting of open corrective actions," Root Cause and Apparent-Common Cause evaluations, and" reviews of corrective action effectiveness. Effectiveness reviews are conducted as part of the corrective action process to ensure that all corrective actions have been completed and to identify any repetition of the event. The corrective action process is also monitored for potentially adverse trends.The existence of an adverse trend due to recurring or repetitive adverse conditions will result in the initiation of a follow-up condition report.Administrative Controls: Administrative controls that govern aging management activities are established within the document control procedures that implement: (1) industry standards related to administrative controls and quality assurance for the operational phase of nuclear power plants, and (2) the requirements of 10 CFR 50, Appendix B, Criterion VI.Plant policies, directives, and procedures are written and controlled to specify and manage various activities, particularly those related to compliance with 10CFR 50, Appendix B. The phrase "administrative control" refers to the adherence to the policies, directives, and procedures, and includes the formal review and approval process that the plant policies, directives, and procedures undergo as they are issued (and subsequently revised). The individual documents (i.e., the plant policies, directives, and procedures), in conjunction with the plant's quality assurance program documents, provide the overall administrative framework to ensure regulatory requirements are met.B.1.4 Operating Experience Operating experience for existing Columbia plant programs and activities was reviewed as an input to the aging management program evaluations. The operating experience review demonstrates the effectiveness of the plant programs and activities that are credited with aging management for the period of extended operation. Aging Management Programs Page B-9 January 2010* .' Confirmation Process: Generating Station License Renewal Application Technical Information The focus of the confirmation process is on the follow-up actions taken to verify effective* implementation 'of corrective actions and preclude repetition of significant conditions adverse to quality. The corrective action-program includes the requirement that measures be taken to preclude repetition of significant conditions adverse to quality. These measures include actions to verify effective implementation of proposed corrective actions. The confirmation process is part of the corrective action program and, for significant conditions adverse to quality, includes:

• reviews to assure proposed actions are adequate,
• tracking and reporting of open corrective actions, .
• Root Cause and Apparent-Common Cause evaluations, and
• reviews of corrective action effectiveness.

Effectiveness reviews are conducted as part of the corrective action process to ensure that all corrective actions have been completed and to identify any repetition of the event. The corrective action process is also monitored for potentially adverse trends. The existence of an adverse trend due to recurring or repetitive adverse conditions will result in the initiation of a follow-up condition report. Administrative Controls: Administrative controls that govern aging management activities are established within the document control procedures that implement: (1) industry. standards related to administrative controls and quality assurance for the operational phase of nuclear power plants, and (2) the requirements of 10 CFR 50, Appendix B, Criterion VI. Plant policies, directives, and procedures are written and controlled to specify and. manage various activities, particularly those related to compliance with 10'CFR 50, Appendix B. The phrase "adll)inistrative control" refers to the adherence to the policies, directives, and procedures, and includes the formal review and approval process that the plant policies, directives, and procedures undergo as they are issued (and subsequently revised). The individual documents (i.e., the plant policies, directives, and procedures), in conjunction with the plant's quality assurance program documents, provide the overall administrative framework to ensure regulatory requirements are met. B.1.4 Operating Experie,:",ce Operating experience for existing Columbia plant programs and activities was reviewed as an input to the aging management program evaluations. The operating experience review demonstrates the effectiveness of the plant programs and activities that are credited with aging management for the period of extended operation. Aging Management Programs Page 8-9 January 2010 Columbia Generating Station License Renewal Application Technical Information Plant procedures require that the discovery of conditions adverse to quality be documented in accordance with the corrective action program. A review of plant records for the most recent seven-year period (January 2001 through July 2008) was performed in order to identify age-related issues of degradation related to current plantoperation. The scope of the review included reports generated under the corrective action program and licensee event reports. These records provide documentation ofsituations where systems, structures, and components exhibit conditions adverse to quality, including age-related degradation. Keywords related to aging and degradation were used to search the records. The operating experience review provides the basis for the determination that existing programs are either effective or require enhancement; that one-time inspections are appropriate to verify that either aging is not occurring or that aging is being effectively managed by an existing program; or that a new program is required to be established to manage the effects of aging.The operating experience review included consideration of the results of programmatic assessments performed by Columbia and of those performed by outside agencies, including the NRC. Past corrective actions resulting in program enhancements are included in the evaluation of program effectiveness. Industry operating experience was considered specifically for new programs with no plant-specific operating experience or when industry events were significant for existing programs. The operating experience review provides objective evidence that the effects of aging will be managed for the period of extended operation. B.1.5 Aging Management Programs Table B-1 provides a listing of the NUREG-1801 aging management programs and the corresponding aging management programs for Columbia. Table B-2 provides a summary of the aging management programs for Columbia with respect to consistency with NUREG-1801 aging management programs. Table B-2 also provides information on whether programs are existing or new, whether enhancements are required, and whether the programs are plant-specific. Each aging management program credited for license renewal is addressed in Section B.2.Aging Management Programs Page B-1 0 January 2010. Columbia Generating Station License Renewal Application Technical Information Plant procedures require that the discovery of conditions adverse to quality be documented in accordance with the corrective action program. A review of plant records for the most recent seven-year period (January 2001 through July 2008) was performed in order to identify age-related issues of degradation related to current plant* operation. The scope of the review included reports generated under the corrective action program and licensee event reports. These records provide documentation of situations where systems, structures, and components exhibit conditions adverse to quality,* including age-related degradation .. Keywords related to aging and degradation were used to search the records. The operating experience review provides the for the determination that existing programs are either effective or require enhancement; that one-time inspections are appropriate to verify that either aging is not occurring or that aging is being effectively managed by an existing program; or that a new program is required to be established to manage the effects of aging.

• The operating experience review included consideration of the results of programmatic assessments performed by Columbia and of those performed by outside agencies, including the NRC. Past corrective actions resulting in program enhancements are included in the evaluation of program effectiveness

.. Industry operating experience was considered specifically for new programs with no plant-specific operating experience or when industry events were significant for existing programs. The operating experience

• . review provides objective evidence that the effects of aging will be managed for the period of extended operation.

B.1.5 Aging Management Programs Table 8-1 provides a listing of the NUREG-1801 aging management programs and the corresponding aging management programs for Columbia. Table 8-2 provides a summary of the aging management programs for Columbia with respect to consistency with NUREG-1801 aging management programs. Table 8-2 also provides information on whether programs are existing or new, whether enhancements are required, and whether the programs are plant-specific. Each aging management program credited for license renewal is addressed in Section 8.2. Aging Management Programs Page 8-10 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information B.2 AGING MANAGEMENT PROGRAMSThe correlation between NUREG-1801 programs and Columbia aging management programs is shown in the'following table. The table is organized by the NUREG-1801 program number, first for Chapter X1, then for Chapter X, and finally for plant-specific programs.Table B-1 Correlation of NUREG-1801 and Columbia-Aging Management Programs Number NUREG-1801 Program Corresponding Columbia AMP NUREG-1 801 Chapter Xl XI.M1 ASME Section Xl Inservice Inservice Inspection (ISI) Program Inspection, Subsections See Section B.2.33.IWB, IWC, and IWD XI.M2 Water Chemistry BWR Water Chemistry Program See Section B.2.11.XI.M3 Reactor Head Closure Studs Reactor Head Closure Studs Program See Section B.2.45.XI.M4 BWR Vessel ID Attachment BWR Vessel ID Attachment Welds Program Welds See Section B.2.9.XI.M5 BWR Feedwater Nozzle BWR Feedwater Nozzle Program See Section B.2.6.XI.M6 BWR Control Rod Drive CRDRL Nozzle Program Return Line Nozzle See Section B.2.15.XIM7 BWR Stress Corrosion BWR Stress Corrosion Cracking Program Cracking See Section B.2.8.XI.M8 BWR Penetrations BWR Penetrations Program See Section B.2.7.XI.M9 BWR Vessel Internals BWR Vessel Internals Program See Section B.2.10.Aging Management Programs Page B-1 1 January.2010
• * * ./ Columbia Generating Station License Renewal Application Technical Information

8.2 AGING

MANAGEMENT PROGRAMS The correlation between .NUREG-1B01 programs and Columbia aging management programs is shown in the 'following table. The table is organized by the NUREG-1B01 . program number, first for Chapter XI, then for Chapter X, and finally for plant-specific programs. Table 8-1 Correlation of NUREG-1801 and Columbia Aging Management Programs Number NUREG-1 a:01 Program Corresponding Columbia AMP NUREG-1801 Chapter XI XLM1 ASME Section XI Inservice Inservice Inspection (lSI) Program Inspection, Subsections See Section B.2.33. IWB, IWC, and IWD XLM2 Water Chemistry BWR Water Chemistry Program I See Section B.2.11. XLM3 Reactor Head Closure Studs Reactor Head Closure Studs Program See Section B.2.45. XI.M4 BWR VessellD Attachment BWR VessellD Attachment Welds Program Welds See Section B.2.9. XI.M5 BWR Feedwater Nozzle BWR Feedwater Nozzle Program See Section 8.2.6. XLM6 BWRControl Rod Drive CRDRL Nozzle Program Return Line Nozzle See Section B.2.15. XLM7 BWR Stress Corrosion BWR Stress Corrosion Cracking Program Cracking See Section B.2.8. XLM8 BWR Penetrations BWR Penetrations Program See Section B.2.7. XLM9 BWR Vessel Internals BWR Vessel Internals Program See SeCtion B.2.10 . Aging Management Programs Page 8-11 January 2010 Columbia Generating Station License Renewal Application Technical Information Table B-1 Correlation of NUREG-1801 and Columbia Aging Management Programs_ _ _(continued) Number NUREG-1 801 Program Corresponding Columbia AMP XI.M1O Boric Acid Corrosion Not Applicable. Columbia is a BWR and-does not use boric acid in any systems. The Standby Liquid Control System uses a sodium pentaborate solution (a mixture of boric acid and borax) that is not aggressive to metals.XI.M11A Nickel-Alloy Penetration Not Applicable. This program is applicable to PWR Nozzles Welded to the plants, Columbia is a BWR.Upper Reactor Vessel Closure Heads of Pressurized Water Reactors XI.M12 Thermal Aging Not credited for aging management. The Inservice Embrittlement of Cast Inspection (ISI) Program (See Section B.2.33) or Austenitic Stainless Steel the Small Bore Class 1 Piping Inspection (See (CASS) Section B.2.49) is credited for pump casings and valve bodies.XI.M13 Thermal Aging and Neutron Thermal Aging and Neutron Embrittlement of Cast Irradiation Embrittlement of Austenitic Stainless Steel (CASS) Program Cast Austenitic Stainless See Section B.2.52.Steel (CASS)XI.M14 Loose Parts Monitoring Not credited for aging management. The Columbia loose parts detection system has been deactivated and spared in-place, as described in FSAR Section 7.7.1.12.XI.M15 Neutron Noise Monitoring Not Applicable. This program is applicable to PWR plants, Columbia is a BWR.XI.M16 PWR Vessel Internals Not Applicable. This program is applicable to PWR plants, Columbia is a BWR.XI.M17 Flow-Accelerated Corrosion Flow-Accelerated Corrosion (FAC) Program See Section B.2.28.XI.M18 Bolting Integrity Bolting Integrity Program See Section B.2.4.XI.M19 Steam Generator Tube Not Applicable. Columbia is a BWR design that Integrity does not utilize steam generators. Aging Management Programs Page,1B-12 January 2010, Table 8-1 Columbia Generating Station License Renewal Application Technical Information Correlation of NUREG-1801 and Columbia Aging Management Programs (continued) Number NUREG-1801 Program Corresponding Columbia AMP XI.M10 Boric Acid Corrosion Not Applicable. Columbia is a BWR and does not use boric acid in any systems. The Standby Liquid Control System uses a sodium pentaborate solution (a mixture of boric acid and borax) that is not aggressive to metals. XI.M11A Nickel-Alloy Penetration Not Applicable. This program is applicable to PWR Nozzles Welded to the plants, Columbia is a BWR. Upper Reactor Vessel Closure Heads of Pressurized Water Reactors XI.M12 Thermal Aging Not credited for aging management. The Inservice Embrittlement of Cast Inspection (lSI) Program (See Section B.2.33) or Austenitic Stainless Steel the Small Bore Class 1 Piping Inspection (See , (CASS) Section B.2.49) is credited for pump casings and valve bodies. XI.M13 Thermal Aging and Neutron Thermal Aging and Neutron Embrittlement of Cast Irradiation Embrittlement of Austenitic Stainless Steel. (CASS) Program Cast Austenitic Stainless See Section B.2.52. Steel (CASS) I XI.M14 Loose Parts Monitoring Not credited for aging management. The Columbia loose parts detection system has been deactivated and spared in-place, as described in FSAR Section 7.7.1.12. XI.M15 Neutron Noise Monitoring Not Applicable. This program is applicable to PWR plants, Columbia is a BWR. XI.M16 PWR Vessel Internals Not Applicable. This program is applicable to PWR plants, Columbia is a BWR. I XI.M17 Flow-Accelerated Corrosion Flow-Accelerated Corrosion (FAC) Program See Section B.2.28. XI.M18 Bolting Integrity Bolting Integrity Program See Section B.2.4. XI.M19 Steam Generator Tube Not Applicable. Columbia is a BWR design that Integrity does not utilize steam generators. Aging Management Programs January 2010, * * ., ...... Columbia Generating Station License Renewal Application Technical Information Table B-1 Correlation of NUREG-1801 and Columbia Aging Management Programs (continued) Number NUREG-1801 Program Corresponding Columbia AMP XI.M20 Open-Cycle Cooling Water Open-Cycle Cooling Water Program System See Section B.2.42.XI.M21 Closed-Cycle Cooling Water Closed Cooling Water Chemistry Program System See Section B.2.13.XI.M22 Boraflex Monitoring Not Applicable. Spent fuel racks at Columbia use Boron Carbide plates as the neutron absorber (rather than Boraflex), as described in FSAR Section 9.1.2.2.1. XI.M23 Inspection of Overhead Material Handling System Inspection Program Heavy Load and Light Load See Section B.2.39.(Related to Refueling) Handling Systems XI.M24 Compressed Air Monitoring Not credited for aging management. Operatingexperience shows that the air and gas is dry for most systems except in certain locations for which the plant-specific Air Quality Sampling Program is credited (See Section B.2.2).XI.M25 BWR Reactor Water Not credited for aging management. Cracking of Cleanup System the stainless steel RWCU piping components within the augmented ISI boundary is managed by the BWR Stress Corrosion Cracking Program (See Section B.2.8).XI.M26 Fire Protection Fire Protection Program See Section B.2,25.XI.M27 Fire Water System Fire Water Program See Section B.2.26.XI.M28 Buried Piping and Tanks Not credited for aging management. The alternate Surveillance XI.M34 option is credited for aging management. See Section B.2.5 for the alternate Buried Piping and Tanks Inspection Program.XI.M29 Aboveground Steel Tanks Aboveground Steel Tanks Inspection See Section B.2.1.XI.M30 Fuel Oil Chemistry Fuel Oil Chemistry Program See Section B.2.29.Aging Management Programs Page B-13 January,2010

• Table 8-1 Columbia Generating Station License Renewal Application Technical Information Correlation of NUREG-1801 and Columbia Aging Management Programs ) (continued)

Number NUREG-1801 Program Corresponding Columbia AMP XLM20 Open-Cycle Cooling Water Open-Cycle Cooling Water Program System See Section B.2.42. XLM21 Closed-Cycle Cooling Water Closed Cooling Water Chemistry Program System See Section B.2.13. XLM22 Boraflex Monitoring Not Applicable. Spent fuel racks at Columbia use Boron Carbide plates as the neutron absorber (rather than Boraflex), as described in FSAR Section 9.1.2.2.1. XLM23 Inspection of Overhead Material Handling System Inspection Program Heavy Load and Light Load See Section B.2.39. (Related to Refueling) Handling Systems XLM24 Compressed Air Monitoring Not credited foraging management. Operating experience shows that the air and gas is dry for most systems except in certain Jocations forwhich the plant-specific Air Quality Sampling Program is credited (See Section B.2.2). XLM25 BWR Reactor Water Not credited for aging management. Cracking of , Cleanup System the stainless steel RWCU piping components within the augmented lSI boundary is managed by the BWR Stress Corrosion Cracking Program (See Section B.2.8). XLM26 Fire Protection Fire Protection Program See Section B.2.25 .. XLM27 Fire Water System Fire Water Program See Section B.2.26. XLM28 Buried Piping and Tanks Not credited for aging management. The alternate Surveillance XLM34 option is credited for aging management. See Section B.2.5 for the alternate Buried Piping and Tanks Inspection Program. XLM29 Aboveground Steel Tanks Aboveground Steel Tanks Inspection See Section B.2.1. XLM30 Fuel Oil Chemistry Fuel Oil Chemistry Program See Section B.2.29. Aging Management Programs Page 8-13 January 2010 Columbia Generating Station License Renewal Application Technical Information Table B-I Correlation of NUREG-1801 and Columbia Aging Management Programs (continued) Number NUREG-1801 Program Corresponding Columbia AMP XIM31 Reactor Vessel Surveillance Reactor Vessel Surveillance Program See Section B.2.46.XI.M32 One-Time Inspection Chemistry Program Effectiveness Inspection See Section B.2.12.Cooling Units Inspection See Section B.2.14.Diesel-Driven Fire Pumps Inspection See Section B.2.18.Diesel Starting Air Inspection See Section B.2.16.Diesel Systems Inspection See Section B.2.17.Flexible Connection Inspection See Section B.2.27.Heat Exchangers Inspection See Section B.2.30.Lubricating Oil Inspection See Section B.2.37.Monitoring and Collection Systems Inspection See Section B.2.41.Service Air System Inspection See Section B.2.48.Supplemental Piping/Tank Inspection See Section B.2.51.XI.M33 Selective Leaching of Selective Leaching Inspection Materials See Section B.2.47.XI.M34 Buried Piping and Tanks Buried Piping and Tanks Inspection Program Inspection See Section B.2.5.XI.M35 One-time Inspection of Small Bore Class 1 Piping Inspection ASME Code Class 1 Small- See Section B.2.49.Bore Piping XI.M36 External Surfaces Monitoring External Surfaces Monitoring Program See Sectioh B.2.23.Aging Management Programs Page B-14 January 2010 Table B-1' Columbia Generating Station License Renewal Application Technical Information Correlation of NUREG-1801 and Columbia Aging Management Programs, (continued) Number NUREG-1801 Program Corresponding Colu'mbia AMP XI.M31 Reactor Vessel Surveillance Reactor Vessel Surveillance Program See Section B.2.46. XI,M32 One-Time Inspection Chemistry Program Effectiveness Inspection See Section B.2.12. Cooling Units Inspection See Section B.2.14. Diesel-Driven Fire Pumps Inspection See Section B.2.18. Diesel Starting Air Inspection '. See Section B.2.16. Diesel Systems Inspection See Section B.2.17. Flexible Connection Inspection See Section B.2.27. Heat Exchangers Inspection See Section B.2.30. Lubricating Oil Inspection See Section B.2.37. Monitoring and Collection Systems Inspection See Section B.2.41. Service Air System Inspection See Section B.2.48. Supplemental PipinglTank Inspection See Section B.2.51. I XI,M33 Selective Leaching of Selective Leaching Inspection Materials See Section B.2.47. XI,M34 Buried Piping and Tanks Buried Piping and Tanks Inspection Program Inspection See Section B.2.5. XI,M35 One-time Inspection of Small Bore Class 1 Piping Inspection ASME Code Class 1 Small-See Section B.2.49. Bore Piping XI.M36 External Surfaces Monitoring External Surfaces Monitoring Program See Section B.2.23. Aging Management Programs Page 8-14 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information Table B-1 Correlation of NUREG-1801 and Columbia Aging Management Programs (continued)

Number NUREG-1801 Program Corresponding Columbia AMP XI.M37 Flux Thimble Tube Not Applicable. Columbia is a BWR design that I Inspection does not utilize flux thimbles.XI.M38 Inspection of Internal Not credited for aging management. The External Surfaces in Miscellaneous Surfaces Monitoring Program (See Section B.2.23)Piping and Ducting and Preventive Maintenance -RCIC Turbine Components Casing (See Section B.2.44) are credited instead for aging management of internal surfaces.Confirmation that aging is not occurring on internal surfaces is provided by the Cooling Units Inspection (See Section B.2.14), the Monitoring and Collection Systems Inspection (See Section 8.2.41), and the Supplemental Piping/Tank Inspection (See Section B.2.51).XI.M39 Lubricating Oil Analysis Lubricating Oil Analysis Program See Section B.2.36.XI.S1 ASME Section XI, Inservice Inspection (ISI) Program -IWE Subsection IWE See Section B.2.34.XI.S2 ASME Section XI, Not Applicable. Columbia has a General Electric Subsection IWL Mark II steel containment, as described in FSAR Section 3.8.2.1.XI.S3 ASME Section XI, Inservice Inspection (ISI) Program -IWF Subsection IWF See Section B.2.35.XI.S4 10 CFR Part 50, Appendix J Appendix J Program See Section B.2.3.XI.S5 Masonry Wall Program Masonry Wall Inspection See Section B.2.38.XI.S6 Structures Monitoring Structures Monitoring Program Program See Section B.2.50.XI.S.7 RG 1.127, Inspection of Water Control Structures Inspection Water-Control Structures See Section B.2.53.Associated with NuclearPower Plants Aging Management Programs Page B-15.January 2010* *

• Table 8-1 Columbia Generating Station License Renewal Application Technical Information Correlation of NUREG-1801 and Columbia Aging Management Programs (continued)

Number NUREG-1801 Program Corresponding Columbia AMP XI,M37 Flux Thimble Tube Not Applicable. Columbia is a BWR design that , Inspection does not utilize flux thimbles. XI,M38 Inspection of Internal Not credited foraging management. The External Surfaces in Miscellaneous Surfaces Monitoring Program (See Section B.2.23) Piping and Ducting and Preventive Maintenance -RCIC Turbine Components Casing (See Section B.2.44) are credited instead for aging management of internal surfaces. Confirmation that aging is not occurring on internal surfaces is provided by the Cooling Units Inspection (See Section B.2.14), the Monitoring and Collection Systems Inspection (See Section 8.2.41), and the Supplemental PipinglTank Inspection (See Section 8.2.51). XI,M39 Lubricating Oil Analysis lubricating Oil Analysis Program See Section 8.2.36 . , XI.S1 ASME Section XI, Inservice Inspection (lSI) Program -IWE SubsectionlWE , See Section B.2.34. XI.S2 ASME Section XI, Not Applicable. Columbia has a General Electric Subsection IWL Mark II steel containment, as described in FSAR Section 3.8.2.1. XI.S3 ASME Section XI, Inservice Inspection (lSI) Program -IWF Subsection IWF See Section B.2.35. XI.S4 10 CFR Part 50, Appendix J Appendix J Program See Section B.2.3. XI.S5 Masonry Wall Program Masonry Wall Inspection See Section 8.2.38. XI.S6 Structures Monitoring Structures Monitoring Program Program See Section B.2.50. XI.$7 RG 1.127, Inspection of Water Control Structures Inspection Water-Control Structures See Section B.2.53. Associated with Nuclear Power Plants Aging Management Programs Page 8-15, January 2010 Columbia Generating Station License Renewal Application Technical Information Table B-1 Correlation of NUREG-1801 and Columbia Aging Management Programs (continued) Number NUREG-1801 Program__J Corresponding Columbia AMP XI.$8 Protective Coating Not credited for aging management. Columbia Monitoring and Maintenance does not credit coatings inside the containment to Program manage the effects of aging for structures and components or to ensure that the intended functions of coated structures and components are maintained. Therefore, these coatings do not have an intended function and do not require aging management for license renewal.XI.E1 Electrical Cables and Electrical Cables and Connections Not Subject to Connections Not Subject to 10 CFR 50.49 EQ Requirements Program 10 CFR 50.49 Environmental See Section B.2.19.Qualification Requirements XI.E2 Electrical Cables Not Subject Electrical Cables and Connections Not Subject to to 10 CFR 50.49 10 CFR 50.49 EQ Requirements Used in Environmental Qualification Instrumentation Circuits Program Requirements Used in See Section B.2.20.Instrumentation Circuits XI.E3 Inaccessible Medium- Inaccessible Medium-Voltage Cables Not Subject Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program to 10 CFR 50.49 See Section B.2.32.Environmental Qualification Requirements XI.E4 Metal-Enclosed Bus Metal-Enclosed Bus Program See Section B.2.40.Agin Maagemnt rogams age8-1 Janary201 Aging Management Programs Page B-16 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Table B-1 Correlation of NUREG-1801 and Columbia Aging Management Programs (continued)

Number NUREG-1801 Program Corresponding Columbia AMP XI,S8 Protective Coating Not credited for aging management. Columbia Monitoring and Maintenance does not credit coatings inside the containment to Program manage the effects of aging for structures and components or to ensure that the intended functions of coated structures and components are maintained. Therefore, these coatings do not have an intended function and do not require aging , management for license renewal. XI.E1 Electrical Cables and Electrical Cables and Connections Not Subject to Connections Not Subject to 10 CFR 50.49 EQ Requirements Program 10 CFR 50.49 Environmental See Section B.2: 19. Qualification Requirements XI.E2 Electrical Cables Not Subject Electrical Cables and Connections Not Subject to to 10 CFR 50.49 10CFR 50.4.9 EQ Requirements Used in Environmental Qualification Instrumentation Circuits Program Requirements Used in See Section B.2.20. Instrumentation Circuits

• XI.E3 Inaccessible Medium-Inaccessible Medium-Voltage Cables Not Subject Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program to 10 CFR 50.49 See Section B.2.32. Environmental Qualification Requirements XI,E4 Metal-Enclosed Bus Metal-Enclosed Bus Program See Section B.2.40.
• Aging Management Programs Page 8-16 January 2010 Columbia Generating Station License Renewal Application Technical Information Table B-1 Correlation of NUREG-1801 and Columbia Aging Management Programs (continued)

Number NUREG-1801 Program Corresponding Columbia AMP XI.E5 Fuse Holders Not credited for aging management. There are no in-scope fuse holders that contain fuses which are routinely manipulated. The fuse boxes are not exposed to weather conditions or chemical contamination, and due to the Columbia location in rural central Washington, they are not exposed to industrial pollution or salt deposition. An inspection of a sample of the passive fuse boxes showed that they are clean and dry, with no evidence of corrosion. Similarly, ohmic heating, thermal cycling, electrical transients, and vibration do not apply to the passive fuse boxes at Columbia because the fuses are not heavily loaded and do not experience frequent electrical and thermal cycling. Vibration is an induced aging mechanism, and is not applicable because the electrical boxes are securely mounted on walls.XI.E6 Electrical Cable Connections Electrical Cable Connections Not Subject to Not Subject to 10 CFR 50.49 10 CFR 50.49 EQ Requirements Inspection Environmental Qualification See Section B.2.21.Requirements NUREG- 801 Chapter X X.Mi Metal Fatigue of Reactor Fatigue Monitoring Program Coolant Pressure Boundary See Section B.2.24.X.S1 Concrete Containment Not Applicable. Columbia has a General Electric Tendon Prestress Mark II steel containment and this structure does not contain pre-stressed tendons, as described in FSAR Section 3.8.2.1.X.E1 Environmental Qualification EQ Program (EQ) of Electrical See Section B.2.22.Components Columbia Plant-Specific Programs N/A Plant-Specific Program Air Quality Sampling Program See Section B.2.2.Aging Management Programs Page B-17 January 2010* *

• Table 8-1 _ Columbia Generating Station License Renewal Application Technical Information Correlation of NUREG-1801 and Columbia Aging Management Programs (continued) . Number NUREG-18:01 Program Corresponding Columbia AMP XI.E5 Fuse Holders Not credited for aging management.

There are no in-scope fuse holders that contain fuses which are routinely manipulated. The fuse boxes are not exposed to weather conditions or chemical contamination, and due to the Columbia location in rural central Washington, they are not exposed to industrial pollution or salt deposition. An inspection ota sample of the passive fuse boxes showed that they are clean and dry, with no evidence of corrosion. Similarly, ohmic heating, thermal cycling, electrical transients, and vibration do not apply to the passive fuse boxes at Columbia because the fuses are not heavily loaded and do , not experience frequent electrical and thermal cycling. Vibration is an induced aging mechanism, and is not applicable because the electrical boxes are securely mounted on walls. XI.E6 Electrical Cable Connections Electrical Cable Connections Not Subject to Not Subject to 10 CFR 50.49 10 CFR 50.49 EO Requirements Inspection Environmental Qualification See Section B.2.21. Requirements NUREG-1801 Chapter X X.M1 FatiguE! of Reactor Fatigue Monitoring Program Coolant Pressure Boundary See Section B.2.24. X.S1 Concrete Containment Not Applicable. Columbia has a General Electric Tendon Prestress Mark" steel containment and this structure does \ not contain pre-stressed tendons, as described in FSAR Section 3.8.2.1. X.E1 Environmental Qualification EQ Program (EQ) of Electrical See Section B.2.22. Components Columbia Plant-Specific Programs N/A Plant-Specific Program Air Quality Sampling Program See Section B.2.2 . Aging Management Programs Page 8-17 January 2010 Columbia Generating Station License Renewal Application Technical Information Table B-1 Correlation of NUREG-1801 and Columbia Aging Management Programs (continued) Number NUREG-1801 Program Corresponding Columbia AMP N/A Plant-Specific Program High-Voltage Porcelain Insulators Aging Management Program See Section B.2.31.N/A Plant-Specific Program Potable Water Monitoring Program See Section B.2.43.N/A Plant-Specific Program Preventive Maintenance -RCIC Turbine Casing See Section B.2.44.Aging Management Programs Page B-1 8 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Table 8-1 Correlation of NUREG-1801 and Columbia Aging Management Programs , (continued)

Number NUREG-1801. Program Corresponding Columbia AMP N/A Plant-Specific Program High-Voltage Porcelain Insulators Aging , .. Management Program See Section B.2.31. N/A Plant-Specific Program Potable Water Monitoring Program See Section B.2.43. N/A Plant-Specific Program Preventive Maintenance -RCIC Turbine Casing See Section B.2.44. *

• Aging Management Programs Page 8-18 January 2010 Columbia Generating Station License Renewal Application Technical Information Table B-2 Consistency of Columbia Aging Management Programs with NUREG-1801 Consistent New / Consistent with P Plant- Enhancement Program Name Existing with NUREG- NUREG-Specific Required 1801 1801 with Exceptions Aboveground Steel Tanks Inspection New Yes --Section B.2.1 Air Quality Sampling Program Existing Yes Section B.2.2 Appendix J Program Existing Yes Section B.2.3 Bolting Integrity Program Existing Yes Section B.2.4Buried Piping and Tanks Inspection Existing Yes Yes Program Section B.2.5 BWR Feedwater Nozzle Program Existing Yes \Section B.2.6 BWR Penetrations Program Existing Yes Section B.2.7 BWR Stress Corrosion Cracking Existing Yes Program Section B.2.8 BWR Vessel ID Attachment Welds Existing Yes Program Section B.2.9 Aging Management Programs Page B-19 January 2010* *
• Table 8-2 Columbia Generating Station License Renewal Application Technical Information Consistency of Columbia Aging Management Programs with NUREG-1801 Consistent Newl Consistent with Plant-Enhancement Program Name Existing with NUREG-NUREG--. Specific Required' 1801 1801 with Exceptions Aboveground Steel Tanks Inspection New --Yes ----Section B.2.1 , , Air Quality Sampling Program Existing ----Yes --Section B.2.2 Appendix J Program Existing Yes ------Section B.2.3 Bolting Integrity Program Existing --Yes ----Section B.2.4 Buried Piping and -Ta-nks Inspection Existing Yes ----Yes Program Section B.2.5 BWR Feedwater Nozzle Program i::xisting Yes \ ------Section B.2.6 BWR Penetrations Program Existing.

Yes ------Section B.2.7 BWR Stress Corrosion Cracking Existing Yes ------Program Section B.2.8 BWR VessellD Attachment Welds Existing Yes Program ------Section B.2.9 Aging Management Programs Page 8-19 January 2010 Columbia Generating Station License Renewal Application Technical Information Table B-2 Consistency of Columbia Aging Management Programs with NUREG-1801 (continued) Consistent New Consistent with Plant- Enhancement Program Name Existing with NUREG- NUREG-1801 1801 with Specific Required Exceptions BWR Vessel Internals Program Existing Yes Section B.2.10 BWR Water Chemistry Program Existing Yes Section B.2.11 Chemistry Program Effectiveness Inspection Section B.2.12 Closed Cooling Water Chemistry Existing Yes Yes Program Section B.2.13 Cooling Units Inspection New Yes --Section B.2.14 CRDRL Nozzle Program Existing Yes --Section B.2.15 Diesel Starting Air Inspection New Yes Section B.2.16 Diesel Systems Inspection New Yes Section B.2.17 Diesel-Driven Fire Pumps Inspection New Yes Section B.2.18 I Aging Management Programs Page B-20 January 2010 Table 8-2 Columbia Generating Station License Renewal Application Technical Information Consistency of Columbia Aging Management Programs with NUREG-1801 (continued) Consistent Newl Consistent with Plant-Enhancement Program Name Existing with NUREG-NUREG-Specific Required 1801 1801 with Exceptions BWR Vessel Internals Program Existing Yes ------Section B.2.1 0 BWR Water Chemistry Program Existing Yes ------Section B.2.11 Chemistry Program Effectiveness New Yes Inspection

---

Section B.2.12 Closed Cooling Water Chemistry Existing --Yes --Yes Program Section B.2.13 Cooling Units Inspection New Yes ------Section B.2.14 CRDRL Nozzle Program Existing Yes ------Section B.2.15 Diesel Starting Air Inspection New Yes ------Section B.2.16 Diesel Systems Inspection New Yes ------Section B.2.17 Diesel-Driven Fire Pumps Inspection New Yes ------Section B.2.18 ( Aging Management Programs Page 8-20 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Table B-2 Consistency of Columbia Aging Management Programs with NUREG-1801 (continued)

Consistent New / Consistent with Plant- Enhancement Program Name ne with NUREG- NUREG-plant- enhneen Existing 1801 1801 with Specific Required Exceptions Electrical Cablesand Connections Not Subject to 10 CFR 50.49 EQ New Yes Requirements Program Section B.2.19 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program Section B.2.20 Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ New

• Yes --Requirements Inspection Section B.2.21 EQ Program Section B.2.22 Existing Yes External Surfaces Monitoring Program Existing Yes Yes Section B.2.23 Fatigue Monitoring Program Existing Yes Yes Section B.2.24 Fire Protection Program Existing Yes Section B.2.25 Aging Management Programs Page B-21.January 2010* *
• Table 8-2 Columbia Generating Station License Renewal Application Technical Information Consistency of Columbia Aging Management Programs with NUREG-1801 (continued)

Consistent Newl Consistent with Plant-Enhancement Program Name Existing with NUREG-NUREG-Specific Required 1801 1801 with Exceptions Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ New Yes ------Requirements Program Section B.2.19 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ New Yes Requirements Used ------in Instrumentation , Circuits Program Section B.2.20 Electrical Cable Connections Not' Subject to 10 CFR 50.49 EQ New --Yes ----ReqLiirements Inspection Section B.2.21 EQ Program Existing Yes ------Section B.2.22 External Surfaces Monitoring Program Existing Yes ----Yes Section B.2.23 Fatigue Monitoring Program Existing Yes ----Yes Section B.2.24 -Fire Protection Program Existing --Yes ----Section Aging Management Programs Page 8-21 January 2010 Columbia Generating Station License Renewal Application Technical Information Table B-2 Consistency of Columbia Aging Management Programs with NUREG-1801 (continued) Consistent Consistent withNew Cosset wt Plant- Enhancement Program Name with NUREG- NUREG-Existing 1801 1801 with Specific Required Exceptions Fire Water Program Existing Yes Yes Section B.2.26 Flexible Connection Inspection New Yes Section B.2.27 Flow-Accelerated Corrosion (FAC) Existing Yes Yes Program Section B.2.28 Fuel Oil Chemistry Program Existing Yes Section B.2.29 Heat Exchangers Inspection New Yes Section B.2.30 High-Voltage Porcelain Insulators Aging Management Existing Yes Program Section B.2.31 Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 New Yes EQ Requirements Program Section B.2.32 Inservice Inspection (ISI) Program Existing Yes Section B.2.33 Inservice Inspection (ISI) Program -IWE Existing Yes --Section B.2.34 Aging Management Programs Page B-22 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Table B*2 Consistency of Columbia Aging Management with NUREG*1801 (continued)

Consistent Newl Consistent with Plant* Enhancement Program Name Existing with NUREG* NUREG* Specific Required 1801 1801 with Exceptions Fire Water Program Existing Yes ----Yes Section 8.2.26 Flexible Connection Inspection New --Yes ----Section 8.2.27 Flow-Accelerated Corrosion (FAC) Existing Yes ----Yes Program Section 8.2.28 Fuel Oil Chemistry Program Existing --Yes ----Section 8.2.29

• Heat Exchangers Inspection . New Yes ------Section 8.2.30 High-Voltage Porcelain Insulators Aging Management Existing ----Yes --Program Section 8.2.31 Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 New Yes ------EQ Requirements Program Section 8.2.32 Inservice Inspection (lSI) Program Existing Yes ------Section 8.2.33 Inservice Inspection (lSI) Program -IWE Existing Yes ------Section 8.2.34 (
• Aging Management Programs Page 8-22 January 2010 Columbia Generating Station License Renewal Application Technical Information Table B-2 Consistency of Columbia Aging Management Programs with NUREG-1801 (continued)

Consistent Consistent withNew Cosset wt Plant- Enhancement Program Name with NUREG- NUREG-Existing 1801 1801 with Specific Required ExceptionsInservice Inspection (ISI) Program -IWF Existing Yes --Section B.2.35 Lubricating Oil Analysis Program Existing Yes Yes Section B.2.36 Lubricating Oil Inspection New Yes Section 8.2.37 Masonry Wall Inspection Existing Yes Yes Section B.2.38 Material Handling System Inspection Existing Yes Yes Program Section B.2.39 Metal-Enclosed Bus Program New Yes Section B.2.40 Monitoring and Collection Systems New Yes --Inspection Section B.2.41 Open-Cycle Cooling Water Program Existing -- Yes -Yes Section B.2.42 Potable Water Monitoring Program Existing Yes Yes Section B.2.43 Aging Management Programs Page B-23 January 2010* *

• Table 8-2 Columbia Generating Station License Renewal Application Technical Information Consistency of Columbia Aging Management Programs with NUREG-1801 (continued)

Consistent Newl Consistent with Plant-Enhancement Program Name Existing with NUREG-NUREG-Specific Required 1801 1801 with Exceptions Inservice Inspection (lSI) Program -IWF Existing *Yes ------Section 8.2.35 Lubricating Oil Analysis Program Existing Yes ----Yes Section 8.2.36 Lubricating Oil , New Yes ------Section 8.2.37 Masonry Wall Inspection Existing Yes ----Yes Section 8.2.38 , Material Handling System Inspection Existing Yes ----Yes Program Section 8.2.39 " Metal-Enclosed 8us Program New --Yes ----Section 8.2.40 Monitoring and Collection Systems New Yes ------Inspection Section 8.2.41 , Open-Cycle Cooling Yes Water Program Existing --Yes --Section 8.2.42 Potable Water Monitoring Program Existing ----Yes Yes Section 8.2.43 Aging Management Programs Page 8-23 January 2910 Columbia Generating Station License Renewal Application Technical Information Table B-2 Consistency of Columbia Aging Management Programs with NUREG-1801 (continued) Consistent New / Consistent with Plant- Enhancement Program Name Existing with NUREG- NUREG- Specific Required 1801 1801 with Exceptions Preventive Maintenance -RCIC Turbine Existing Yes Casing Section B.2.44 Reactor Head Closure Studs Existing Yes Program Section B.2.45 Reactor Vessel Surveillance Existing Yes Program Section B.2.46 Selective Leaching Inspection New Yes Section B.2.47 Service Air System Inspection New Yes Section B.2.48 Small Bore Class 1 Piping Inspection New Yes ---..Section B.2.49 Structures Monitoring Program Existing Yes Yes Section B.2.50 Supplemental Piping/Tank New Yes Inspection Section B.2.51 dj Aging Management Programs Page B-24 ,January 2010 Columbia Generating Station License Renewal Application

• . Technical Information Table 8-2 Consistency of Columbia Aging Management Programs with NUREG-1801 (continued)

Consistent Newl Consistent with Plant-Enhancement Program Name Existing with NUREG-NUREG-Specific Required 1801 1801 with Exceptions Preventive Maintenance -RCIC Turbine Existing ----Yes --Casing Section B.2.44 Reactor Head Closure Studs Existing Yes Program ------Section B.2.45 Reactor Vessel Surveillance Existing Yes Program ------Section B.2.46

• Selective Leaching Inspection New Yes ------Section B.2.47 Service Air System Inspection New Yes ------Section B.2.48 / Small Bore Class 1 Piping Inspection New Yes ------Section B.2.49 \ Structures Monitoring Program Existing Yes ----Yes Section B.2.50 Supplemental Piping/Tank New Yes ------Inspection Section B.2.51 d
• Aging Management Programs Page 8-24 January 2010 Columbia Generating Station License Renewal Application Technical Information Table B-2 Consistency of Columbia Aging Management Programs with NUREG-1801 (continued)

Consistent New / Consistent with Program Name e with NUREG- NUREG- Plant- Enhancement Existing 1801 1801 with Specific Required'Exceptions Thermal Aging and Neutron Embrittlement of Cast Austenitic New YesStainless Steel (CASS) Program Section B.2.52 Water Control Structures Inspection Existing Yes Yes Section B.2.53 Aging Management Programs Page B-25-January 2010* * * , Table 8-2 Columbia Generating Station License Renewal Application Technical Information Consistency of Columbia Aging Management Programs with NUREG-1801 (continued) Consistent Newl Consistent with Plant-Enhancement Program Name Existing with NUREG-NUREG-Specific Required' 1801 1801 with Exceptions Thermal Aging and Neutron Embrittlement of Cast Austenitic New Yes ------Stainless Steel (CASS) Program Section 8.2.52 Water Control Structures Existing Yes Yes Inspection

---

Section 8.2.53 Aging Management Programs Page 8-25 January 2010 Columbia Generating StationLicense Renewal Application Technical Information B.2.1 Aboveground Steel Tanks InspectionProgram Description The Aboveground Steel Tanks Inspection is a new one-time inspection that will detect and characterize the conditions on the bottom surfaces of the carbon steel condensate storage tanks. The inspection provides direct evidence through volumetric examination as to whether, and to what extent, a loss of material due to crevice, general, or pitting corrosion has occurred or is likely to.occur in inaccessible areas (i.e., tank base and bottom surface) that could result in a loss of intended function.Implementation of the Aboveground Steel Tanks Inspection, in conjunction with the External Surfaces Monitoring Program, will provide added assurance that the pressure boundary integrity of the condensate storage tanks is maintained consistent with the current licensing basis during the period of extended operation.

NUREG-1801 Consistency The Aboveground Steel Tanks Inspection is a new one-time inspection for.Columbia that, in conjunction with the External Surfaces Monitoring Program, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M29, "Aboveground Steel Tanks," with exceptions.Exceptions to NUREG-1801 Program Elements Affected:* Preventive Actions There is no sealant or caulking at the interface edge between the condensate storage tanks and the concrete foundation. Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The scope of the Aboveground Steel Tanks Inspection includes the base (bottom surface and foundation pad interface) of the condensate storage tanks (COND-TK-1A and COND-TK-1 B).Volumetric examinations will be conducted on sample locations at the tank base to detect evidence of a loss of material due to crevice, general, or pitting corrosion or to confirm a lack thereof.Aging Management Programs Page B-26 January 2010 Columbia Generating Station License Renewal Application Technical Information

8.2.1. Aboveground

Steel Tanks Inspection Program Description The Aboveground Steel Tanks Inspection is a new one-time inspection that will detect and characterize the conditions on the bottom surfaces of the carbon steel condensate storage tanks. The inspection provides direct evidence through volumetric examination as to whether, and to what extent, a loss of material due to crevice, general, or pitting . corrosion has occurred or is likely to-occur in inaccessible areas (i.e., tank base and bottom surface) that could result in a loss of intended function. Implementation of the Aboveground Steel Tanks Inspection, in conjunction with the External Surfaces Monitoring Program, will provide added assurance that the pressure boundary integrity of the condensate storage tanks is maintained consistent with the current licer:lsing basis during the period of extended operation. NUREG-1801 Consistency The Aboveground Steel Tanks Inspection is a new one-time inspection for Columbia that, in conjunction with the External Surfaces Monitoring Program, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M29, "Aboveground Steel Tanks," with exceptions. , Exceptions to NUREG-1801 Program Elements Affected:

• Preventive Actions There is no sealant or caulking at the interface edge between the condensate storage tanks and the concrete foundation. . Aging Management Program Elements The results of an evaluation of each program element are provided below.
• Scope of Program The scope of the Steel Tanks Inspection includes the base (bottom surface and foundation pad interface) of the condensate storage tanks TK-1A and COND-TK-1B).

Volumetric examinations will be conducted on sample locations at the tank base to detect evidence of a loss of material due to crevice, general, or pitting corrosion or to confirm a lack thereof. Aging Management Programs Page 8-26 January 2010 ** *

• Columbia Generating Station License Renewal Application Technical Information-., Periodic inspection of the external surfaces of the tanks (including protective coatings), other than the tank bottoms, is included in the scope of the External Surfaces Monitoring Program.* Preventive Actions The external surfaces of the condensate storage tanks have protective coatings that are consistent with industry practice.

However, there is no sealant or caulking at the interface edge between the tanks and concrete foundation. No other actions are taken as part of the Aboveground Steel Tanks Inspection or the External Surfaces Monitoring Program to prevent aging effects or to mitigate aging degradation.

• Parameters Monitored or Inspected The Aboveground Steel Tanks Inspection will determine wall thickness as a measure of loss of material for the tank bottom.The related parameters inspected by the External Surfaces Monitoring Program include visual evidence of a loss of material or other degradation.
• Detection of Aging Effects The Aboveground Steel Tanks Inspection will use established volumetric examination techniques performed by qualified personnel to inspect locations on the bottom surface of a condensate storage tank to determine whether, and to what extent, a loss of material has occurred or is likely to occur during the period of extended operation.

The Aboveground Steel Tanks Inspection will be conducted after the issuance of therenewed license and prior to the end of the current operating license for Columbia, with sufficient time to implement programmatic oversight for the period of extended operation. The activities will be conducted no earlier than 10 years prior to the end of the current operating license, so that conditions are more representative of the conditions expected during the period of extended operation. The results of this inspection will supplement the existing inspection of accessible external surfaces conducted by the External Surfaces Monitoring Program.Monitoring and Trending No actions are taken as part of the Aboveground Steel Tanks Inspection to monitor or trend inspection results. This is a one-time inspection activity that will use volumetric examination techniques to determine if, and to what extent, further actions, including monitoring and trending, may be required.Aging Management Programs Page B-27 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information , Periodic inspection of the external surfaces of the tanks (including protective coatings), other than the tank bottoms, is included in the scope of the External < Surfaces Monitoring Program.
• Preventive Actions The external surfaces of the condensate storage tanks have protective coatings that are consistent with industry prattice.

However, there is no sealant or caulking at the interface edge between ,the tanks and concrete foundation. No other actions are taken as part of the Aboveground Steel Tanks Inspection or the External Surfaces Program to prevent aging effects or to mitigate aging degradation. '

• Parameters Monitored or Inspected The Aboveground Steel Tanks Inspection will determine wall thickness as a measure of loss of material for the tank bottom.

The related parameters inspected by the External Surfaces Monitoring Program include visual evidence of a loss of material or other degradation.

• Detection of Aging Effects' The Aboveground Steel Tanks Inspection will use established volumetric examination techniques performed by qualified personnel to inspect locations on the bottom surface' of Cl condensate storage tank to determine whether, and to what extent" a loss of material has occurred or is likely to occur during the period of extended operation.

The Aboveground Steel Tanks Inspection will be conducted after the issuance of the renewed license and prior to the end of the current operating license for Columbia, with sufficient time to implement programmatic oversight for the period of extended operation. The activities will be conducted no earlier than 1 0 years prior to the end of the current operating license, so that conditions are more, representative of the conditions expected during the period of extended operation. The results of this inspection will supplement the existing inspection of accessible external surfaces conducted by the External Surfaces Monitoring Program.

• Monitoring and Trending No actions are taken as part of the Aboveground Steel Tanks Inspection to monitor or trend inspection results. This is a one-time inspection activity that will use volumetric examination techniques to determine if, and to what extent, further actions, incltiding monitoring and trending, may be required . Aging Management Programs Page B-27 January 2010 Columbia Generating Station License Renewal Application Technical Information The examination techniques for accessible external surfaces, including the condensate storage tanks, are described in the External Surfaces Monitoring Program.Acceptance Criteria Indications or relevant conditions of degradation detected during the inspections will be compared to pre-determined acceptance criteria, i.e., minimum wall thickness.

If the acceptance criteria are not met, then the indications and conditions will beevaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation. Acceptance criteria for degradation of external surfaces, including the coatings for the condensate storage tanks, are described in the External Surfaces Monitoring Program.* Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3." Operating Experience The Aboveground Steel Tanks Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effect. The inspection provides for confirmation of material conditions near the period of extended operation. The elements comprising the inspection activity are to be consistent with industry practice.No instances of degradation of condensate storage tanks were identified in a review of condition reports. However, to provide added assurance that the component intended function will be maintained during the period of extended operation, inspection of the bottom surface is conservatively warranted. Aging Management Programs Page B-28 January 2010 Columbia Generating Station License Renewal Application Technical Information The examination techniques for accessible external surfaces, including the condensate storage tanks, are described in the External Surfaces Monitoring Program.

• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspections will be compared to pre-determined acceptance criteria, i.e., minimum wall thickness.

If the acceptance criteria are not met, then the indications and conditions will be . evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation. Acceptance criteria for degradation of external surfaces, including the coatings for the condensate storage tanks, are described in the External Surfaces Monitoring Program.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extendedoperatiqn and is discussed in Section B.1.3. *
• Confirmation process. This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience The Aboveground Steel Tanks Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effect. The inspection provides for confirmation of material conditions near the period of extended operation.

The elements comprising the inspection activity are to be consistent with industry practice. No instances of degradation of condensate storage tanks were identified in a review of condition reports. However, to provide added assurance that the component intended function will be maintained during the period of extended, operation, inspection of the bottom surface is conservatively warranted. Aging Management Programs Page 8-28 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information The operating experience associated with the existing External Surfaces Monitoring Program, which includes the accessible portions of the condensate storage tanks, is addressed under the External Surfaces Monitoring Program evaluation.

Required Enhancements Not applicable, this is a new activity.Conclusion Implementation of the Aboveground Steel Tanks Inspection (in conjunction with the External Surfaces Monitoring Program) will verify that there are no aging effects requiring management for the bottom surfaces of the condensate storage tanks or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the condensate storage tank intended function will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page B-29 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information The operating experience associated with the existing External Surfaces Monitoring Program, which includes the accessible portions of the condensate storage tanks, is addressed under the External Surfaces Monitoring Program evaluation

.. Required Not applicable, this is a new activity. Conclusion Implementation of the Aboveground Steel Tanks Inspection (in conjunction with the External Surfaces Monitoring Program) will verify that there are no aging effects requiring management for the bottom surfaces of the condensate storage tanks or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the condensate storage tank intended function will be maintained consistent with the current licensing basis during the period of extended operation . Aging Management Programs Page 8-29 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.2 Air Quality Sampling Program Program Description The Air Quality Sampling Program will mitigate degradation due to loss of material for carbon steel components in the Diesel Starting Air (DSA) System that contain compressed air and are within the scope of license renewal, to ensure that the integrity of piping and components is maintained. The Air Quality Sampling Program also ensures that the Control Air System (CAS) remains dry and free of contaminants, thereby validating the aging management review conclusion that there are no aging effects that require management. The Air Quality Sampling Program is a combination prevention and condition monitoring program. The program is based on existing commitments to NRC Generic Letter 88-14 and comprises periodic air quality sampling and corresponding actions to remove moisture and particulates from the CAS and DSA systems. The program also performs periodic UT inspections of DSA System air receivers to ensure the pressure boundary integrity is maintained. Prior to the period of extended operation, the Air Quality Sampling Program will be supplemented by a separate one-time inspection of the piping and components downstream of the DSA System dryers (excluding the DSA System air receivers), based on plant-specific operating experience. The Diesel Starting Air Inspection will detect and characterize the extent to which degradation has occurred in the DSASystem dryers and the downstream piping and components (excluding the DSA System air receivers) and provide confirmation that the integrity of the piping and components will be maintained for the period of extended operation. NUREG-1801 Consistency The Air Quality Sampling Program is an existing Columbia program that is plant-specific. NUREG-1801 includes a Compressed Air Monitoring Program (XI.M24). Both the NUREG-1801 and Columbia programs are based on the results of responses to Generic Letter (GL) 88-14. However, as described in the Energy Northwest responses to GL 88-14 and subsequent NRC acceptance, the Columbia program is comprised of periodic sampling for air quality: Therefore, the other portions of the NUREG-1801, XI.M24 program are not applicable to Columbia.Aging Management Program Elements The results of an evaluation of each program element are provided below. Scope of Program The Air Quality Sampling Program is credited with managing loss of material for subject components in the DSA System. The scope of the Air Quality Sampling Program includes periodic sampling of the DSA System air quality and corresponding actions, if unacceptable moisture or contaminants are detected, to Aging Management Programs Page B-30 January 2010 8.2.2 Air Quality Sampling Program Program Description Columbia Generating Station License Renewal Application Technical Information The Air Quality Sampling Program will mitigate degradation due to loss of material for carbon steel components in the Diesel Starting Air (DSA) System that contain compressed air and are within the scope of license renewal, to ensure that the integrity of piping and components is maintained. The Air Quality Sampling Program also ensures that the Control Air System (CAS) remains dry and free of contaminants, thereby validating the (lging management review conclusion that there are no aging effects that require management. The Air Quality Sampling Program is a combination prevention and condition monitoring program. The program is based on existing* commitments to NRC Generic Letter 88-14 and comprises periodic air quality sampling and corresponding actions to remove moisture and particulates from the CAS and DSA systems. The program also performs periodic UT inspections of DSA System air receivers to ensure the pressure boundary integrity is maintained. Prior to the period of extended operation,. the Air Quality Sampling Program will be supplemented by a separate one-time inspection of the piping and components downstream of the DSA System dryers (excluding the DSA System air receivers),

• based on plant-specific operating experience.

The Diesel Starting Air Inspection will

• detect and characterize the extent to which degradation has occLirred in the DSA System dryers and the downstream piping and components (excluding the DSA System air receivers) and provide confirmation that the integrity of the piping and components will be maintained for the period of extended operation.

NUREG-1801 Consistency The Air Quality Sampling Program is an existing Columbia program that is specific. NUREG-1801 includes a Air Monitoring Program (XI.M24). Both the NUREG-1801 and Columbia programs are based on the results of responses to Generic Letter (GL) 88-14. However, as described in the Energy Northwest responses to GL 88-14 and subsequent NRC acceptance, the Columbia program is comprised of periodic sampling for air quality.' Therefore, the other portions of the NUREG-1801, XI.M24 program are not applicable to Columbia. Aging Management Program Elements The results of an evaluation of each program element are provided below.

• Scope of Program The Air Quality Sampling Program is credited with managing loss of material for subject components in the DSA System. The scope of the Air Quality Sampling Program includes periodic sampling of the DSA System air quality and corresponding actions, if unacceptable moisture or contaminants are detected, to Aging Management Programs Page 8-30 January 2010
• Columbia Generating Station License Renewal Application Technical Information mitigate loss of material for steel portions of the system. The scope of the program also includes the performance of biennial UT inspections of the DSA System air receivers to ensure that their pressure boundary integrity will be maintained.

In addition, the scope of the Air Quality Sampling Program includes periodic sampling of the air quality in the CAS to ensure that the compressed air environment remains dry and free of contaminants, thereby ensuring that no aging effects require management for the system." Preventive Actions The Air Quality Sampling Program includes periodic air sampling (for particulates, hydrocarbons, and dewpoint) of the CAS and DSA systems, to ensure acceptable air quality and corresponding actions, such as dewpoint reduction, if the results are outside acceptable limits. In addition, based on site operating experience, the program ihvolves-desiccant inspection and replenishment, air receiver dewpoint reduction, and air receiver blowdown activities, which are conducted as necessary to minimize the accumulation of moisture in the DSA System and any resulting corrosion to system components." Parameters Monitored or Inspected As described for Preventive Actions above, the Air Quality Sampling Program periodically samples the CAS and DSA systems for hydrocarbons, dewpoint, and particulates to verify proper air quality and ensure that the intended function of the systems is maintained. The Air Quality Sampling Program also conducts UT inspections of the DSA System air receivers to determine wall thickness. Inspections are performed by qualified personnel using established nondestructive examination (NDE) techniques for the components being inspected (i.e., ultrasonic examination). Visual inspection of tank internals for evidence of corrosion and corrosion products may be performed. In addition, the Air Quality Sampling Program is supplemented by the separate one-time Diesel Starting Air Inspection for the DSA System dryers and downstream piping and components (excluding the DSA System air receivers) to characterize conditions and provide additional confirmation that the intended function will be maintained through the period of extended operation." Detection of Aging Effects.The Air Quality Sampling Program does not directly inspect for or detect the effects of aging in the CAS. Rather, as described for the Preventive Actions element above, the presence of an environmental stressor (moisture), which could lead to corrosion of system components, is detected and moisture, if any, is removed to ensure air quality is maintained. To detect loss of material prior to a loss of component intended-function, the Air Quality Sampling Program performs UT inspections to measure the wall thickness of the DSA System air receivers. Aging Management Programs Page B-31 January 2010*

• Columbia Generating Station License Renewal Application Technical Information mitigate loss of mate!rial for steel portions of the system. The scope of the program also includes the performance of biennial UT inspections of the DSA System air receivers to ensure that their pressure boundary integrity will be maintained.

In addition, the scope cif the Air Quality Sampling Program includes periodic sampling of the air quality in the CAS to ensure that the compressed air environment remains dry and freE! of contaminants, thereby ensuring that no aging effects require management for the system.

• Preventive Actions The Air Quality Sampling Program includes periodic air sampling (for particulates, hydrocarbons, and dewpoint) of the CAS and DSA systems, to ensure acceptable air quality and corresponding actions, such as dewpoint reduction, if the results are. outside acceptable limits. In' addition, based on site operating experience,'

the program irwolves' desiccant inspection and replenishment, air receiver dewpoint reduction, and air receiver blowdown activities, which are conducted as necessary to minimize the accumulation of moisture in the DSA System and any resulting corrosion to system components.

• Parameters Monitored or Inspected As described for Preventive Actions above, the Air Quality Sampling Program periodically samples the CAS and DSA systems for hydrocarbons, dewpoint, and particulates to verify proper air quality and ensure that the intended function of the systems is maintained.

The Air Quality Sampling Program also conducts UT inspections of the DSA System air receivers. to determine wall thickness. Inspections are performed by qualified personnel using established nondestructive examination (NDE) techniques for the components being inspected (i.e., ultrasonic examination). Visual inspection of tank internals for evidence of corrosion and corrosion products may be performed. In addition, the Air Quality Sampling Program is supplemented by the' separate one-time Diesel Starting Air Inspection for the DSA System dryers and downstream piping and components (excluding the DSA System air receivers) to characterize conditions and provide additional confirmation that the intended function will be mainta,ined through the period of extended operation. * . Detection of Aging Effects The Air Quality Sampling Program does not directly inspect for or detect the effects of aging in the CAS. Rather, as described for the Preventive Actions element above, the presence of an environmental stressor (moisture), which could lead to corrosion of system compommts, is detected and moisture, if any, is removed to ensure air quality is maintained. To detect loss of material prior to a loss of component intended* function, the Air Quality Sampling Program performs UT inspections to measure the wall thickness of the DSA System air receivers . Aging Management Programs Page 8-31 January 2010 Columbia Generating Station License Renewal Application Technical Information Refer to the Operating Experience discussion below for information on the effectiveness of the Air Quality Sampling Program in minimizing the conditions that could result in the effects of aging (corrosion) in the DSA System. See also the one-time Diesel Starting Air Inspection, which is evaluated separately. Monitoring and Trending Air quality sampling of the CAS and DSA systems is performed periodically, depending on the results of previous testing. The UT inspection of the DSA System air receivers is performed on a biennial basis. Results are kept in permanent plant files and are available for trending analysis as necessary. Recurring instances of DSA System air quality outside acceptable limits and decreases in wall thickness of the DSA System air receivers have been trended and evaluated through the corrective action program.Acceptance Criteria Acceptance criteria for the CAS and DSA compressed air are specified for particulates, hydrocarbons, and dewpoint in the surveillance procedures. If the CAS acceptance criteria are not met, the procedure directs entering the failure into the corrective action program which drives actions to reduce the dew point. If the DSA System acceptance criteria are not met, then the procedure directs entering the failure into the corrective action program and directs procedural actions to reduce the dew point.Indications or relevant conditions of degradation detected, during the inspections of the DSA System air receivers will be compared to pre-determined acceptance criteria (i.e., minimum wall thickness). If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function.Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Aging Management Programs Page B-32 January 2010 Aging Management Programs Page B-32 January 2010 Columbia Generating Station License Renewal Application Technical Information Refer to the Operating Experience discussion below for information on the effectiveness of the Air Quality Sampling Program in minimizing the conditions that could result in the effects of aging (corrosion) in the DSA System. See also the time Diesel Starting Air Inspection, which is evaluated separately.

• Monitoring and Trending Air quality sampling of the CAS and DSA systems is performed periodically, depending on the results of previous testing. The UT inspection of the DSA System air receivers is performed on a biennial basis. Results are kept in permanent plant . files and are available for trending analysis as necessary.

Recurring instances of DSA System air quality outside acceptable limits and decreases in wall thickness of the DSA System air receivers have been trended and evaluated through the corrective action program.

• Acceptance Criteria Acceptance criteria for the CAS and DSA compressed air are specified for . particulates, hydrocarbons, and dewpoint in the surveillance procedures

.. If the CAS acceptance criteria are not met, the procedure directs entering the failure into the corrective action program which drives actions to reduce the dew point. If the DSA System acceptance criteria are not met, then the procedure directs entering the

• failure into the corrective action program and directs procedural actions to reduce
• the dew pOint. Indications or relevant conditions of degradation detected, during the inspections of the DSA System air receivers will be compared to pre-determined acceptance criteria (i.e., minimum wall thickness).

If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function.

• Corrective Actions This element is common to Columbia programs and, activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of. extended operation and is discussed in Section B.1.3. Aging Management Programs Page 8-32 January 2010
• Columbia Generating Station License Renewal Application Technical Information Operating Experience As described in the Energy Northwest responses to GL 88-14, and confirmed by subsequent site operating experience, air quality testing continues to show that the compressed air is essentially dry and contaminant free. With the exception of the DSA System, there have been no failures or significant degradation of components in compressed air systems, such as the CAS and the Service Air System.Industry operating experience is also included.

Experience from Beaver Valley was reviewed and confirmed that erosion and corrosion issues should not be expected in the CAS and SA systems at Columbia.. Work requests were initiated to perform inspections, which further confirmed that loss of material is not a concern in the CAS and SA systems.Recurring dewpoint problems have been experienced with the DSA System, which is more noticeable during the summer months, when ambient humidity is higher.Dewpoint, or moisture content, in the DSA System is a concern for the long-term effects of corrosion and corrosion products on DSA System components. The most critical point in the DSA System for moisture control is at the air receivers and the high-pressure portion of the system upstream of the pressure control valves.Degradation has been identified in the DSA System (e.g., due to excessive moisture content), where the dewpoint has been shown to average +5 0 C. This degradation has been evaluated by the corrective action process.The quarterly sampling of CAS has been effective at maintaining dry, contaminant-free air, thereby minimizing the conditions for degradation. For the DSA System, additional actions to reduce dewpoint, replenish desiccant, and blow down the air receivers are necessary to ensure dry air and to effectively maintain the DSA System air quality.Required Enhancements None.Conclusion The Air Quality Sampling Program will manage loss of material for susceptible DSA System components exposed to compressed air through its monitoring activities. The Air Quality Sampling Program also will ensure that the CAS environment remains dry and free of contaminants, thereby ensuring that no aging effects require management for the system. The Air Quality Sampling Program, supplemented by the one-time Diesel Starting Air Inspection prior to entering the period of extended operation, provides reasonable assurance that the aging effects will be managed such that DSA components subject to aging management review will continue to perform' their intended functions consistent with the current licensing basis for the period of extended operation..Aging Management Programs Page B-33 January 2010* * *

• Operating Experience Columbia Generating Station License Renewal Application Technical Information As described in the Energy Northwest responses to GL 88-14, and confirmed by subsequent site operating experience, air quality testing continues to show that the compressed air is essentially dry and contaminant free. With the exception of the DSA System, there have been no failures or significant degradation of components in compressed air systems, such as the CAS and the Service Air System. Industry operating experience is also included.

Experience from Beaver Valley was reviewed and confirmed that erosion and corrosion issues' should not be e'xpected in the CAS and SA systems at Columbia .. Work requests were initiated to perform inspections, which further confirmed thatJoss of material is not a concern in the CAS and SA systems. Recurring dewpoint problems have been experienced with the DSA System, which is more noticeable during the summer months, when ambient humidity is higher. Dewpoint, or moisture content, . in the DSA System is a concern for the long-term effects of corrosion and corrosion products on DSA System components .. The most critical point in the DSA System for moisture control is at the air receivers and the high-pressure portion* of the system upstream of the pressure control valves. Degradation has been identified in the DSA System (e.g., due to excessive moisture content), where the dewpoint has been shown to average +5°C. This degradation has been evaluated by the corrective action process. The quarterly sampling of CAS has been effective at maintaining

dry, free air, thereby minimizing the conditions for degradation.

For the DSA System, additional actions to reduce dewpoint, replenish desiccant, and blow down the air receivers are necessary to ensure dry air and to effectively maintain the DSA System air quality. Required Enhancements None. Conclusion The Air Quality Sampling Program will manage loss of material for susceptible DSA. System components exposed to compressed air through its monitoring activities. The Air Quality Sampling Program* also will ensure that the CAS environment remains dry and free of contaminants, thereby ensuring that no aging effects require management for the system. The Air Quality Sampling Program, supplemented by the one-time Diesel Starting Air Inspection .. prior to entering the period of extended operation, provides reasonable assurance that. the aging effects will be managed such that DSA components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operati.on. . Aging Management Programs Page 8-33 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.3 Appendix J ProgramProgram Description The Appendix J Program is a monitoring program that detects degradation of the Primary Containment and systems penetrating the Primary Containment. The Appendix J Program provides assurance that leakage from the Primary Containment will not exceed maximum values for containment leakage. The regulatory basis for the Appendix J Program includes 10 CFR 50 Appendix J Option B, Regulatory Guide 1.163 (Performance-Based Containment Leak-Test Program), and NEI .94-10 (Industry Guideline for Implementing Performance Based Option of 10 CFR Part 50, Appendix J).The Appendix J Program provides reasonable assurance that the effects of aging are adequately managed to ensure that leakage through the Primary Containment and systems and components penetrating the Primary Containment does not exceed allowable values specified in technical specifications and that their intended function is performed consistent with the current licensing basis for the period of extended operation. NUREG-1801 ConsistencyThe Appendix J Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.S4, "10 CFR Part 50, Appendix J." Exceptions to NUREG-1801 None.Required Enhancements None.Operating Experience For Columbia, the integrated'leakage rates for Type A tests, and the sum of Type B and Type C leakage rate tests, have been less than the maximum allowable leakage ratesspecified in the Technical Specifications. Inservice inspections conducted during Refueling Outage 18 (R18) did not identify any significant age-related degradation of the containment and its penetrations. Twodeficiencies were found during the SI-I WE inspection and were reported in the R18 ISI summary report. Both found items dealt with replacement of individual bolts and were not related to containment integrity."

• 0 Aging Management Programs Page B-34 January 2010 Columbia Generating Station License Renewal Application
• Technical Information

8.2.3 Appendix

J Program Program Description The Appendix J Program is a monitoring program that detects degradation of the Primary Containment and systems penetrating the Primary Containment. The Appendix J Program provides assurance that leakage from the Primary Containment will not exceed maximum values for containment leakage. The regulatory basis for the Appendix J Program includes 10 CFR 50 Appendix J Option B, Regulatory Guide 1.163 (Performance-Based Containment Leak-Test Program), and NE194-1 0 (Industry Guideline for Implementing Performance Based Option of 10 CFR Part 50, Appendix J). The Appendix J Program provides reasonable assurance that the effects of aging are adequately managed to ensure that leakage through the Primary Containment and systems and components penetrating the Primary Containment does not exceed allowable values specified in technical specifications and that their intended function is performed consistent with the current licensing basis for the period of extended operation. NUREG-1801 Consistency The Appendix J Program is an existing Columbia program that is consistent with the 10

• elements of an effective aging management program as described in NUREG-1801, Section XI,S4, "10 CFR Part 50, Appendix J." Exceptions to NUREG-1801 None. Required Enhancements None. Operating Experience For Columbia, the integrated'ieakage rates for Type A tests, and the sum of Type Band Type C leakage rate tests, have been less than the maximum allowable leakage rates specified in the Technical Specifications.

Inservice inspections conducted during Refueling Outage 18 (R 18) did not identify any significant age-related degradation of the containment and its penetrations.* Two deficiencies were found during the ISI-IWE inspection and were reported in the R18 lSI summary report. Both found items dealt with replacement of .individual bolts and were not related to containment integrity. . Aging Management Programs Page 8-34 January 2010

• Columbia Generating Station License Renewal Application Technical Information Type B and C leakage rate test results from the 2007 Refueling Outage (R18) are summarized in the.local leak rate test post outage report. The R18 local leak rate test involved ninety-one Type B and C air tests. Twenty-five Type B tests were conducted,.including the personnel airlock barrel test. All Type B as found leak rates were below their administrative limits with the exception of the containment-side flange (CEP-V-2A), which had a leak rate exceeding its administrative limit. This flange was checked using a soap solution with test pressure applied and showed no external leakage. This visual inspection confirmed that the leakage recorded was into the system rather than a breach of the containment penetration.

Sixty-six Type C tests were.conducted. All but eight valves had as found leak rates below their administrative limits. The valves with leak rates in excess of their administrative limit required corrective actions to reduce their leak rates. Of the eight valves with as found leak rates in excess of their administrative limits, five required disassembly and rework, and one valve wasreplaced. The remaining two valves were successfully flushed and as-left tested without disassembly. The total as found leakage at the beginning of Refueling Outage 19 (R19) was 19,712 standard cubic centimeters per minute (sccm). This equates to. 16.2 percent of the total allowable containment leakage (La) of 121,536 sccm. The values from previous refueling outages (R18) and (R17) were 13,683 sccm and 20,879 sccm respectively. The total as left leakage at the end of R19 was 13,098 sccm. This equates to 10.8 percent of the total allowable containment leakage (La) of 121,536 sccm and well below the maximum allowable! startup containment leakage rate of 0.6La. The values from the previous refueling. outages (R18) and (R17) were 14,051 sccm and 17,423 sccm, respectively. The results of previous Type A tests are shown below. No Type A tests have failed to meet their acceptance criteria at Columbia.Total Leakage Acceptance Limit (percent) (percent)02/16/1984' 0.2758 0.50 06/17/1987 0.3241 0.50 06/09/1991 0.319 0.50 07/20/1994 0.330 0.50 06/14/2009 0.3418 0.50 The health of the Appendix J Program is reported periodically in terms of performance indicators. The program health reports for 2007 and 2008 indicated no age-related concerns for systems and components within the scope of the Appendix J Program.Aging Management Programs Page B-35 January 2010* Columbia Generating Station License Renewal Application Technical Information Type 8 and C leakage rate test results from the 2007 Refueling Outage (R18) are summarized in the local leak rate test post outage report. The R18 local leak rate test involved ninety-one Type 8 and C air tests. Twenty-five Type 8 tests were conducted, . including the personnel airlock barrel test. All Type 8 as found leak rates were below their administrative limits with the exception of the containment-side flange (CEP-V-2A), which had a leak rate exceeding its administrative limit. This flange was checked using a soap solution with test pressure applied and showed no external leakage. This visual inspection confirmed that the leakage recorded was into the system rather than a breach of the containment penetration. Sixty-six Type C tests were. conducted. All but eight valves had as found leak rates below their administrative limits. The valves with leak rates in excess of their administrative limit required corrective actions to reduce leak rates. Of the eight valves with as found leak rates in excess of their administrative limits, five required disassembly and rework, and one valve was replaced. The remain"ing two valves were successfully flushed and as-left tested without disassembly. The total as found leakage at the beginning of Refueling Outage 19 (R 19) was 19,712 standard cubic centimeters per mihute (sccm). This equates to 16.2 percent of the total allowable containment leakage (La) of 121,536 sccm. The values from previous refueling outages (R18) and (R17) were 13,683 sccm and 20,879 sccm respectively.

• The total as left leakage at the end of.R19 was 13,098 sccm. This equates to 10.8 percent of the total allowable containment leakage (La) of 121,536 sccm and well below the maximum allowable!

startup containment leakage rate of 0.6La. The values from the previous refueling outages (R18) and (R17) were 14,051 sccm and 17,423 sccm, respectively. '

• The results of previous Type A tests are shown below. No Type A tests have failed to meet their acceptance criteria at Columbia.

Test Date Total Leakage Acceptance Limit (percent) . (percent) 02/16/1984 ' 0.2758 0.50 06/17/1987 0.3241 0.50 06/09/1991 0.319 0.50 07/20/1994 0.330 0.50 06/14/200H 0.3418 0.50 . The health of the Appendix J Program ,is reported periodically in terms of performance indicators. The program health reports for 2007 and 2008 indicated no age-related concerns for systems and components within the scope of the Appendix J Program . Aging Management Programs Page 8-35 January 2010 Columbia Generating Station License Renewal Application Technical Information The Appendix J Program has been effective in managing the identified aging effects.The site corrective action program and ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects.Conclusion The Appendix J Program will be capable of detecting and managing aging effects for the Primary Containment and systems and components penetrating the Primary Containment. The 'continued implementation of the Appendix J Program provides reasonable assurance that the aging effects will be managed such that the Primary Containment will continue to perform its intended function consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-36 January 2010 Aging Management Programs Page B-36 January 2010 Columbia Generating Station License Renewal Application

• Technical Information The Appendix J Program has been effective in managing the identified aging effects. The site corrective action program and ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects. . Conclusion The Appendix J Program will be capable of detecting and managing aging effects for the Primary Containment and systems and components penetrating the Primary Containment.

The *continued implementation of the Appendix J Program provides reasonable assurance that the aging effects will be managed such that the Primary Containment will continue to perform its intended function consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-36 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information B.2.4 Bolting Integrity ProgramProgram Description The Bolting Integrity Program is a condition monitoring program that consists of existing Columbia activities that, in conjunction with other credited programs (identified in discussions below), address the management of aging for the bolting of subject mechanical components and structural connections within the scope of license renewal.The Bolting Integrity Program relies on manufacturer and vendor information and industry recommendations (in EPRI NP-5067, "Good Bolting Practices")

for the proper selection, assembly, and maintenance of bolting for pressure-retaining closures and structural connections. The Bolting Integrity Program consists of the periodic inspection of bolting for indications of degradation such as leakage, loss of material due to corrosion, loss of pre-load, and cracking due to SCC and fatigue.NUREG-1801 Consistency The Bolting Integrity Program is a combination of existing activities that are consistent with the 10 elements of an effective aging management program as described in NUREG-1801 Section XI.M18, "Bolting Integrity," with exceptions. Exceptions to NUREG-1801 Program Elements Affected:* Preventive Actions (and Scope of Program)The Bolting Integrity Program does not explicitly address the guidelines outlined in EPRI NP-5769, or as delineated in NUREG-1339. However, the Bolting Integrity Program does rely on the recommendations of the manufacturer and vendor and the industry, contained in related EPRI document NP-5067, including proper material selection, preload, and assembly.Monitoring and Trending Periodic inspection of bolting, other than of the Class 1, 2, 3, and MC bolting performed by the Inservice Inspection (ISI) Program and Inservice Inspection (ISI) Program -- IWF, is performed through the External Surfaces Monitoring Program or Structures Monitoring Program, including follow-up inspections if leakage or degradation is detected. The frequency of follow-up inspections is established by engineering evaluation. of the identified problem.Aging Management Programs Page B-37 January 2010** B.2.4 Bolting Integrity Program Program Description Columbia Generating Station License Renewal Application Technical Information The Bolting Integrity Program is a condition monitoring program that consists of existing Columbia activities that, in conjunction with other credited programs (identified in discussions below), address the management of aging for the bolting of subject mechanical components and structural connections within the scope of license renewal.. The Bolting Integrity Program relies on manufacturer and .vendor information and industry recommendations (in ERRI NP-5067, "Good Bolting Practices") for the proper selection, and. maintenance of bolting for pressure-retaining closures and structural connections. The Bolting Integrity Program consists of the periodic inspection of bolting for indications of degradation such as leakage, loss of material due to corrosion, loss of pre-load; and cracking due to SCC and fatigue. NUREG-1801 Consistency The Bolting Integrity Program is a combination of existing activities that are consistent with the 10 elements of an effective aging management program as described in NUREG-1801 Section XI.M18, "Bolting Integrity," with exceptions.

• Exceptions to NUREG*1801 Program Elements Affected:
• Preventive Actions (and Scope of Program) The Program does not explicitly address the guidelines outlined in EPRI NP-57f39, or as delineated in NUREG-1339.

However, the Bolting Integrity Program does rely on the recommendations of the manufacturer and vendor and the industry, contained in related EPRI document NP-5067, including proper material selection, preload, and assembly.

• Monitoring and Trending*

Periodic inspection of bolting, other than of the Class 1, 2, 3, and MC bolting performed by thelnservice Inspection (lSI) Program and Inservice Inspection (lSI) Program --IWF, is performed through the External Surfaces Monitoring Program or Structures Monitoring Program, including follow-up inspections if leakage or degradation is detected. The frequency of follow-up inspections is established by engineering evaluation of the identified problem .. Aging Management Programs Page 8-37 January 2010 . .. Columbia Generating StationLicense Renewal Application Technical Information Acceptance Criteria The Bolting Integrity Program does not specify acceptance criteria for bolting.However, the Inservice Inspection (ISI) Program, Inservice Inspection (ISI)Program -IWF, Structures Monitoring Program, and External Surfaces Monitoring Program, through which the periodic visual inspections of mechanical and structural components within the scope of license renewal are performed,do, or will prior to the period of extended operation, include acceptance criteria for evidence of degradation of components, including the bolting.Required Enhancements None.Operating Experience Review of operating experience shows that the Bolting Integrity Program, following the guidance of EPRI NP-5067, has been effective in managing aging effects.No instances of cracking have been identified for bolting or fasteners, although some corroded bolting and facing surfaces (e.g., from general corrosion or as a result of leakage) have been identified at Columbia and corrected. For example, corrosion has been identified for some pump column-to-bowl bolting, and on some valve body-to-bonnet bolting. Corroded bolting has been replaced, and leaking bolted joints and closures have been repaired. There have also been instances of system leaks that may have been due to loss of preload that have been identified and corrected by existing activities in the Bolting Integrity Program.Conclusion The Bolting Integrity Program will manage loss of material, loss of pre-load, and cracking for the bolting of pressure-retaining mechanical components and structural connections. The Bolting Integrity Program provides reasonable assurance that the aging effects will be managed such that bolting will continue to perform its intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-38 January 2010 Columbia Generating Station License Renewal Application

• Technical Information
• Acceptance Criteria The Bolting Integrity Program does not specify acceptance criteria for bolting. However, the Inservice Inspection (lSI) Program, Inservice Inspection (lSI) Program -IWF, Structures Monitoring Program, and. External*

Surfaces Monitoring Program, through which the periodic visual inspections of mechanical and structural components within the scope of license renewal are performed, do, or will prior to the period of extended operation, include acceptance criteria for evidence of degradation of components, including the bolting. Required Enhancements \ None. Operating Experience Review of operating experience shows that the Bolting Integrity Program, following the guidance of EPRI NP-5067, has been effective in managing aging effects. No instances of cracking have been identified for bolting or fasteners, although some corroded bolting and facing surfaces (e.g., *from general corrosion or as a result of leakage) have been identified at Columbia-and corrected. For example, corrosion has been identified for some pump column-to-bowl bolting, and on some valve bonnet bolting. Corroded bolting has been replaced, and leaking bolted joints and closures have been repaired. There have also been instances of system leaks that may have been due to loss of preload that have been' identified and corrected by existing activities in the Bolting Integrity Program. Conclusion The Bolting Integrity Program will manage loss of material, loss of pre-load, and cracking for the bolting of pressure-retaining mechanical components and structural connections. The Bolting Integrity Program provides reasonable assurance that the aging effects will be managed such that bolting will continue to perform its intended functions consistent with the current licensing basis for the period of extended operation. Aging !VIanagement Programs Page 8-38 January 2010 * ,. Columbia Generating Station License Renewal Application Technical Information B.2.5 Buried Piping and Tanks Inspection Program Program Description The Buried Piping and Tanks Inspection Program will manage the effects of loss of material due to corrosion on the external surfaces of piping and tanks exposed to a buried environment. The Buried Piping and Tanks Inspection Program is a combination of a mitigation program (consisting of protective coatings) and a condition monitoring program (consisting of visual inspections). Integrity of coatings will be inspected when components are excavated for maintenance or other reasons. If an opportunistic inspection has not occurred between year 30 and year 38, an excavation of a section of buried piping for the purpose of inspection will be performed before year 40. An additional inspection of buried piping will be performed within 10 years after entering the period of extended operation. The Buried Piping and Tanks Inspection Program will continue to ensure that the pressure boundary integrity of the subject components is maintained consistent with the current licensing basis during the period of extended operation. NUREG-1801 Consistency The Buried Piping and Tanks Inspection Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M34, "Buried Piping and Tanks Inspection." Exceptions to NUREG-1801 None.Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program element:* Scope of Program -Revise the site program document to include the buried portions of the Radwaste Building Outside Air (WOA) piping.Aging Management Programs Page B-39 January 2010* B.2.5 Buried Pipin!g and Tanks Inspection Program Program Description Columbia Generating Station . License Renewal Application Technical Information The Buried Piping and Tanks Inspection Prograrri will manage the effects of loss of material due to corrosion on the external surfaces of piping and tanks exposed to a buried environment. The Buried Piping and Tanks Inspection Program is a combination of a mitigation program (consisting of protective coatings) and a condition monitoring program (consisting of visual inspections). Integrity of coatings will be inspected when components are excavated for maintenance or other reasons. If an opportunistic inspection has not occurred between year 30 and year 38, an excavation of a section of buried piping for the purpose of inspection will be performed before year 40. An additional inspection of buried piping will be performed within 10 years after entering the period of extended operation. . The Buried Piping and Tanks Inspection Program will continue to ensure that the pressure boundary integrity of the subject components is maintained consistent with the current licensing basis during the period of extended operation.

• NUREG-1801 Consistfmcy
• The Buried Piping and Tanks Inspection Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XLM34, "Buried Piping and Tanks Inspection." Exceptions to NUREG-1801 None. Required Enhancements Prior to the. period of extended operation the enhancements listed below will be implemented in the identified program element:
• Scope of Program -Revise the site program document to include the buried portions of the Radwaste Building Outside Air (WOA) piping . Aging Management Programs Page 8-39 January 2010 Columbia Generating Station License Renewal Application Technical Information
• Detection of Aging Effects -Require that an inspection of a representative sample of buried piping be performed within the 10-year period prior to entering the period of extended operation (i.e., between year 30 and year 40).Require an additional inspection of a representative sample of buried piping be performed within 10 years after entering the period of extended operation (i.e., between year 40 and year 50).Operating Experience No history of piping degradation due to external corrosion of buried piping was identified for Columbia through searches of operating experience or discussions with program owners. Columbia operating experience demonstrates that the coating of buried steel piping and tanks is effective in managing the effects of aging. Plant design considerations addressed the potential for degradation of buried piping components through the application of protective coatings.A review was conducted of station piping failures, and it was determined that there had been no documented failures attributed to externally-initiated corrosion.

Identified instances of leakage associated with buried piping have been the result of internal corrosion. The environmental conditions at Columbia are very good based on the sandy soil and electrolyte resistivity of the soil which is considered very high. This has resulted in minimal degradation of buried piping as evidenced by excavations of certain sections ofpiping for examination. There have been no significant areas of degradation caused by protective coating failure. This was determined after a section of buried Standby Service Water (SW) System piping was excavated and evaluated in 2007.Conclusion The Buried Piping and Tanks Inspection Program will manage loss of material due to corrosion for susceptible piping components and tanks in buried environments. The Buried Piping and Tanks Inspection Program, with the required enhancements, provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-40 January 2010* Detection of Aging Effects -Columbia Generating Station License Renewal Appiication Technical Information Require that an inspection of a representative sample of buried piping be performed within the 10-year period prior to entering the period of extended operation (i.e., between year 30 and year 40). Require an additional inspection of a representative sample of buried piping be performed within 10 years after entering the period of extended operation (i.e., between year 40 and year 50). Operating Experience No history of piping degradation due to external corrosion of buried piping was identified for Columbia through searches of operating experience or discussions with program owners. Columbia operating experience dem,onstrates that the coating of buried steel piping and tanks is effective in managing the effects of aging. Plant design considerations addressed the potential for degradation of buried piping components through the application of protective coatings. . . A review was conducted of station piping failures, and it was determined that there had been no documented failures attributed to externally-initiated corrosion. Identified instances of leakage associated with buried piping have been the result of internal corrosion . . The environmental conditions at Columbia are very good based on the sandy soil and electrolyte resistivity of the soil which is considered very high. This has resulted in minimal degradation of buried piping as evidenced by excavations of certain sections of piping for examination. There have been no significant areas of degradation caused by protective coating failure. This was determined after a section of buried Standby Service Water (SW) System piping was excavated and evaluated in 2007. Conclusion The Buried Piping and Tanks Inspection Program will manage loss of material due to corrosion for susceptible piping components and tanks in. buried environments. The Buried Piping and Tanks Inspection Program, with the required enhancements, provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation: Aging Management Programs Page 8-40 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information B.2.6 BWR Feedwater Nozzle Program Program Description The BWR Feedwater Nozzle Program manages cracking due to SCC/IGA and flaw growth of the feedwater nozzles. The BWR Feedwater Nozzle Program is an existing program in accordance with ASME Section XI and NRC augmented requirements.The program consists of (a) enhanced inservice inspection in accordance with the requirements of the ASME Code, Section Xl, Subsection IWB, Table IWB 2500-1 (2001 edition including the 2002 and 2003 Addenda) and the recommendations of GeneralElectric (GE)

NE-523-A71 0594-A, and (b) system modifications to mitigate cracking. The program specifies periodic ultrasonic inspection of critical regions of the feedwater nozzles.As described in FSAR Section 5.3.3.1.4.5, the solution of the feedwater nozzle cracking problems involved several elements, including material selection and processing, nozzle clad elimination, and thermal sleeve and sparger redesign. The Columbia sparger.design includes a welded thermal sleeve such that there is no thermal sleeve bypass and no rapid thermal cycling of the blend radius for each feedwater nozzle. Stainless steel cladding of the Columbia feedwater nozzles was not included in the original design.The original feedwater (FW) flow controller satisfied most of the recommended characteristics of a low flow controller. Consequently, replacement of this controller was not required at Columbia. Columbia rerouted the reactor water cleanup (RWCU) such that it discharges into all six feedwater nozzles. Columbia performed a pre-service inspection ultrasonic examination of the feedwaternozzle inner radii, bore, and safe end regions. In addition, a pre-service liquid penetrant examination was performed on the accessible areas of all feedwater nozzle inner radius surfaces.The BWR Feedwater Nozzle Program at Columbia monitors cracking by detection and sizing of cracks using ISI in accordance with ASME Section Xl, Subsection IWB. The BWR Feedwater Nozzle Program at Columbia includes augmented inservice inspection (ISI) examinations to monitor crack initiation and growth of the feedwater nozzles. The schedule, examination techniques and personnel qualification recommendations of GE NE-523-A71-0594-A have also been incorporated into the Inservice Inspection (ISI)Program.All ISI indications are evaluated to the ASME Code requirements for the component involved. Evaluation is performed in accordance with established site procedures that require use of the ASME Code, or other documents such as BWRVIP documents, if applicable. Aging Management Programs Page B-41 January 2010* *

• B.2.6 BWR Feedwc!lter Nozzle Program Program Description Columbia Generating Station License Renewal Application Technical Information The BWR Feedwater Nozzle Program manages cracking due to SCCIIGA and flaw growth of the feedwater nozzles. The BWR Feedwater Nozzle Program is an existing program in accordance with ASME Section XI and NRC augmented requirements.

The program consists of (a) enhanced inservice inspection in accordance with the requirements of the ASME Code, Section XI, Subsection IWB, Table IWB 2500-1 (2001 edition including the 2002 and 2003 Addenda) and the recommendations of General Electric (GE) NE-523-A71 0594-A, and (b) system modifications to mitigate cracking. The program specifies periodic ultrasonic inspection of critical regions of the feedwater nozzles. . , As described in FSAR Section 5.3.3.1.4.5, the solution of the feedwater nozzle cracking problems involved several elements, including material selection and processing, nozzle clad elimination, and thermal sleeve and sparger redesign. The Columbia sparger* design includes a welded thermal sleeve such that there is no thermal sleeve bypass and no rapid thermal cycling of the blend radius for each feedwater nozzle. Stainless steel cladding of the Columbia feedwater nozzles was not included in the original design. The original feedwater (FW) flow col7itroller satisfied most of the recommended characteristics of a low flow controller. Consequently, replacement of this controller was not required alColumbia. Columbia rerouted the reactor water cleanup (RWCU) such that it into all six feedwater nozzles. Columbia performed a pre-service inspection ultrasonic examination of the feedwater nozzle inner radii, bore, and safe end regions. In addition, a pre-service liquid penetrant examination was performed on the accessible areas of all feedwater nozzle inner radius surfaces. The BWR Feedwater Nozzle Program at Columbia monitors cracking by detection and sizing of cracks using lSI in accordance with ASME Section XI, Subsection IWB. The BWR Feedwater Nozzle Program at Columbia includes augmented inservice inspection (lSI) examinations to monitor crack initiation and growth of the feedwater nozzles. The schedule, examination techniques and personnel qualification recommendations of GE NE-523-A71-0594-A have also been incorporated into the Inservice Inspection (lSI) Program. . All lSI indications are evaluated to the ASME Code reqUirements for the component involved. Evaluation is performed in accordance with established site procedures that require use of the ASME Code, or other documents such as BWRVIP documents, if applicable. Aging Management Programs Page 8-41 January 2010 Columbia Generating Station License Renewal Application Technical Information The BWR Feedwater Nozzle Program credits portions of the Inservice Inspection (ISI)Program.NUREG-1801 Consistency The BWR Feedwater Nozzle Program is arf existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801 Section XI.M5, "BWR Feedwater Nozzle." Exceptions to NUREG-1801 None.Required Enhancements None.Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Industry Experience: NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Review of recent BWR License Renewal Applications identified the following industry experience. Reactor pressure vessel inner radius section ultrasonic examinations were performed for nozzles N4A, N4B, N4C and N4D at Cooper in 2005. No indications that required evaluation were recorded during these examinations. In 2007, Duane Arnold Energy Center identified the failure of a sparger bracket keeper which allowed interface wear between the mating surfaces of the sparger bracket and the vessel bracket. Temporary repairs were done to make the sparger acceptable for continued use.Columbia operating experience: Columbia operating experience, consistent with industry operating experience, shows that the BWR Feedwater Nozzle Program is effective in managing aging effects in that no feedwater nozzle cracking has been observed at Columbia.Inspections of four feedwater nozzles in the spring of 2005 found no unacceptable Aging Management Programs Page B-42 January 2010 Columbia Generating Station License Renewal Application

• Technical Information , The BWR Feedwater Nozzle Program credits portions of the Inservice Inspection (lSI) Program. NUREG-1801 Consistency The BWR Feedwater Nozzle Program is an' existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801 Section XI,M5, "BWR Feedwater Nozzle." Exceptions to NUREG-1801 None. Required Enhancements None. : Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation.

Industry Experience: NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Review of recent BWR License Renewal Applications identified the following industry experience. Reactor pressure vessel inner radius section ultrasonic examinations' were performed for nozzles N4A, N4B, N4C and N4D at Cooper in 2005. No indications that required evaluation were recorded during these examinations. In 2007, Duane Arnold Energy Center identified the failure of a sparger bracket keeper which allowed interface wear between the mating surfaces of the sparger bracket and the vessel bracket. Temporary repairs were done to make the sparger acceptable for continued use. Columbia operating experience: Columbia operating experience, consistent with industry operating experience, shows that the BWR Feedwater Nozzle Program is effective in managing aging effects in that no feedwater nozzle cracking has been observed at Columbia.

• Inspections of four feedwater nozzles in the spring of 2005 found no unacceptable
• Aging Management Programs Page 8-42 January 2010 Columbia Generating StationLicense Renewal Application Technical.

Information indications. Inspection of the nozzle, inner radius, bore, and associated safe end of two feedwater nozzles in the spring of 2009' found no unacceptable indications. Therefore, continued implementation of the program provides reasonable assurance that the effects of aging will be managed so that the feedwater nozzles will continue to perform their intended function consistent with the current licensing basis during the period of extended operation. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects.Conclusion The BWR Feedwater Nozzle Program manages cracking of the feedwater nozzles.The BWR Feedwater Nozzle Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Page B-43 January 2010 Aging Management Programs Page B-43 January 2010* * * " Columbia Generating Station License Renewal Application Technical. I nformation indications. Inspection of the nozzle, inner radius, bore, and associated safe end of. two feedwater nozzles in the spring of 2009' found no unacceptable indications. Therefore, continued implementation of the program provides reasonable assurance that the effects of aging will be managed so that the feedwater nozzles will continue to perform their intended function consistent with the current licensing basis during the period of extended operation. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects. Conclusion The BWR Feedwater Nozzle Program manages cracking of the feedwater nozzles. The BWR Feedwater Nozzle Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform the!ir intended functions consistent with the current licensing basis for the period of operation . Aging Management Programs Page 8-43 January 2010 Columbia Generating StationLicense Renewal Application Technical Information B.2.7 BWR Penetrations ProgramProgram Description The BWR Penetrations Program manages cracking due to stress corrosion cracking (SCC) or intergranular stress corrosion cracking (IGSCC) of stainless steel or nickel alloy reactor vessel penetrations, including reactor vessel instrument penetrations, jet pump instrument penetrations, control rod drive penetrations, and incore instrument penetrations. Columbia inspects all reactor vessel penetrations in accordance with the requirements of ASME Section XA. The ASME Section XI examinations are supplemented by approved BWRVIP reports.Columbia detects and sizes cracks in accordance with the guidelines of approved BWRVIP documents and the requirements of the ASME Code, Section Xl, 2001 Edition, 2003 Addenda, Section X!, IWB-3000, "Standards for Examination Evaluations." Evaluation of flaws in accordance with established site procedures and ASME Code or BWRVIP requirements may result in re-inspection or sample expansion. Acceptance of components for continued service is in accordance with the ASME code or the BWRVIP program guidance, as applicable. Repair and replacement would include the guidance in BWRVIP-53 and BWRVIP-57. The Columbia instrumentation penetrations are low alloy steel, welded to the reactor vessel with nickel alloy weld material. This configuration is addressed in BWRVIP-49-A and no further inspections beyond ASME Section XI requirements are recommended. The BWR Penetrations Program incorporates BWRVIP-49-A and will be revised if future revisions to BWRVIP-49-A require further inspections. Columbia's SLC system injects through the core spray nozzles rather than the SLC nozzle. Thus, consistent with Section 1.1 of BWRVIP-27-A, this BWRVIP document does not apply to Columbia. Consequently, cracking of Columbia's SLC penetration is managed by the Inservice Inspection (ISI) Program rather than the BWR Penetrations Program. The BWR Penetrations Program incorporates BWRVIP-27-A and will be revised if future revisions to BWRVIP-27-A make it applicable to Columbia.The Columbia drain nozzle is low alloy steel and is not susceptible to SCC/IGSCC. Degradation of this penetration is managed by the Inservice Inspection (ISI) Program rather than BWR Penetrations Program.The BWR Penetrations Program credits portions of the Inservice Inspection (ISI)Program.Aging Management Programs Page 8-44 January 2010 Aging Management Programs Page B-44 January 2010 B.2.7 BWR Penetrations Program Program Description Columbia Generating Station License Renewal Application Technical Information The BWR Penetrations Program manages cracking due to stress corrosion cracking (SCC) or intergranular stress corrosion cracking (IGSCC) of stainless steel or nickel alloy reactor vessel penetrations, including reactor vessel instrument penetrations, jet pump instrument penetrations, control rod drive penetrations, and incore instrument penetrations. Columbia inspects all reactor vessel penetrations in accordance with the requirements of ASME Section XI. The ASME Section XI examinations are supplemented by approved BWRVIP reports. Columbia detects and sizes cracks in accordance with the guidelines of approved BWRVIP documents and the requirements of the ASME Code, Section XI, 2001 Edition, 2003 Addenda, Section XI, IWB-3000, "Standards for Examination Evaluations." Evaluation of flaws in accordance with established site procedures and ASME Code or BWRVIP requirements may result in re-inspection or sample expansion. Acceptance of components for continued service is in accordance with the ASME code or the BWRVIP program guidance, as applicable. Repair and replacement would include the guidance in BWRVIP-53 and BWRVIP-57.

• The Columbia instrumentation penetrations are low alloy steel, welded to the reactor
• vessel with nickel alloy weld material.

This configuration is addressed in BWRVIP-49-A and no further inspections beyond ASME Section XI requirements are recommended. The BWR Penetrations Program incorporates BWRVIP-49-A and will be revised if future revisions to BWRVIP-49-A require further inspections. Columbia's SLC system injects through the core spray nozzles rather than the SLC nozzle. Thus, consistent with Section 1.1 of BWRVIP-27-A, this BWRVIP document does not apply to Columbia. Consequently, cracking of Columbia's SLC penetration is managed by the Inservice Inspection (lSI) Program rather than the BWR Penetrations Program. The BWR Penetrations Program incorporates BWRVIP-27-A and will be' revised if future revisions to BWRVIP-27-A make it applicable to Columbia. The Columbia drain nozzle is low alloy steel and is not susceptible to SCC/lGSCC. Degradation of this penetration is managed by the Inservice Inspection (lSI) Program rather than BWR Penetrations Program. .' The BWR Penetrations Program credits portions of the Inservice Inspection (lSI) Program. Aging Management Programs Page 8-44 January 2010

• Columbia Generating Station License Renewal Application Technical Information NUREG-1801 Consistency The BWR Penetrations Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M8, "BWR Penetrations." Exceptions to NUREG-1801 None.Required Enhancements None.Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation.

Industry Experience: NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. As a participant in the BWRVIP, Columbia is committed to incorporate lessons learned from operating experience of the entire BWR fleet.Review. of recent BWR license renewal applications found the following industry experience. At Cooper, the nozzle-to-safe-end welds of instrument nozzle and SLC nozzle were ultrasonically examined and found acceptable in 2005. Each of the instrument penetration nozzles were inspected and found acceptable during pressure testing in 2003 and in 2005.During Refueling Outage (RFO) 16 at Duane Arnold Energy Center inspections of weld susceptible to intergranular stress corrosion cracking (IGSCC) identified flaw indications on three recirculation riser nozzle-to-safe-end welds (RRB-F002, RRD-F002 and RRF-F002). The original scope of the examinations included three recirculation riser and one core spray nozzle-to-safe-end welds. The inspection scope was therefore expanded to include all of the remaining F002 welds, as well as the other similarly designed core spray welds, One weld was ground flush and re-inspected, and has been dispositioned. Two welds were repaired using weld overlays.Aging Management Programs Page B-45 January 2010* ') *

• Columbia Generating Station License Renewal Application Technical Information NUREG-1801 Consistency The BWR Penetrations Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M8, "BWR Penetrations." ) Exceptions to NUREG-1801 None. Required Enhancements None. Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation.

Industry Experience: NUREG-1801 is bclsed on industry operating experience through January 2005 . Recent industry experience has been reviewed for, applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. \ '. As a participant in the BWRVIP, Columbia is committed to incorporate lessons learned from operating experience of the entire BWR fleet. . , Review of recent BWR license renewal applications found the following industry . experience. At Cooper, the nozzle-to-safe-end welds of instrument nozzle and SLC nozzle were ultrasonically examined and found acceptable in 2005. Each of. the instrument penetration nozzles were inspected and found acceptable during pressure testing in 2003 and in 2005. . During Outage (RFO) 16 at Duane Arnold Energy Center inspections of weld susceptible to intergranular stress corrosion cracking (IGSCC) identified flaw indications on three recirculation riser nozzle-to-safe-end welds (RRB-F002 , RRD-F002 and RRF-F002). The original scope of the examinations included three recirculation riser and one core spray nozzle-to-safe-end welds. The inspection scope was therefore expanded to include all of the remaining F002 welds, as well as the other similarly designed core spray welds. One weld was ground flush and re-inspected, and has been dispositioned. Two welds were repaired using weld overlays. . Aging Management Programs Page 8-45 January 2010 j Columbia Generating Station License Renewal Application Technical Information Columbia operating experience: Columbia operating experience to date has found no indications of cracking inthe reactor vessel penetrations. Both Columbia and industry operating experience shows that the BWR Penetrations Program has been effective in managing aging effects. Therefore, continued implementation of the program provides reasonable assurance'that effects of aging will be managed so that the reactor vessel penetrations crediting this program will continue to perform their intended function consistent with the current licensing basis during the period of extended operation. Conclusion The BWR Penetrations Program manages cracking of the in-scope reactor vessel penetrations. The BWR Penetrations Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review and crediting this program will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-46 January 2010 Aging Management Programs Page B-46 January 2010 Columbia operating experience: Columbia Generating Station License Renewal Application Technical Information Columbia operating experience to date has found no indications of cracking in the reactor vessel penetrations. Both Columbia and industry operating experience shows that the BWR Penetrations Program has been effective in. managing aging effects. Therefore, continued implementation of the program provides reasonable assurance 'that effects of aging will be managed so that the reactor vessel penetrations crediting this program will continue to perform their intended function consistent with the current licensing basis during the period of extended operation. Conclusion The BWR Penetrations Program manages cracking of the in-scope reactor vessel penetrations. The BWR Penetrations Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review and crediting this program will continue to perform their intended* functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-46 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information B.2.8 BWR Stress Corrosion Cracking ProgramProgram Description The BWR Stress Corrosion Cracking Program manages stress corrosion cracking for stainless steel and nickel alloy piping, nozzle safe ends, nozzle thermal sleeves, valves, flow elements, and pump casings. 'The program to manage stress corrosion cracking and intergranular attack (SCC/IGA) in reactor coolant pressure boundary piping made of stainless steel and components made of stainless steel or nickel alloy is delineated in NUREG-0313, Revision 2, and GL 88-01 and its Supplement

1. The material includes base metal and welds. The.

BWR Stress Corrosion Cracking Program meets the requirements of GL 88-01 and BWRVIP-75. The program consists of (a) preventive measures to mitigate SCC/IGA, and (b)inspection and flaw evaluation to monitor SCC/IGA and its effects. The staff-approved BWRVIP-75 report modified the inspection scope in the GL 88-01 program.(a) preventive measures to mitigate SCC/IGA Columbia mitigates stress corrosion cracking by using, and continuing to use, materials resistant to SCC for component replacements and repairs following therecommendations delineated in GL 88-01. Prior to initial plant startup and during the first refueling outage, an induction heating stress improvement (IHSI) process was used on 148 SCC/IGA susceptible piping welds. In the 1994 refueling outage, Columbia performed a mechanical stress improvement process (MSIP) for multiple RPV nozzle to safe end and safe end to pipe welds.Columbia mitigates aging by maintaining water chemistry in accordance with the current BWRVIP guidelines, as detailed in the BWR Water Chemistry Program.Columbia has implemented hydrogen water chemistry (HWC) and noble metal chemical application (NMCA) to mitigate IGSCC.(b) Inspection and flaw evaluation The Columbia program detects and sizes cracks in accordance with the requirements of the ASME Code, Section Xl, supplemented by guidelines of approved BWRVIP documents. Inspection of piping to detect and size cracks is performed in accordance With the staff positions on schedule, methods, and.personnel and sample expansion included in GL 88-01 and BWRVIP-75. If indications are found, sample expansion occurs per BWRVIP-75. In response to GL 88-01, Columbia committed to using ASME Section Xl Section IWB-3600 of the ASME Code for methods and criteria for crack evaluation and repair. Columbia committed to notify the Commission if a flaw is found that does not meet Section XI, IWB-3500 criteria for continued operation without evaluation. Aging. Management Programs Page B-47 January 2010* **

• B.2.8 BWR Stress Corrosion Cracking Program Program Description Columbia Generating Station License Renewal Application Technical Information The BWR Stress Corrosion Cracking Program manages stress corrosion .cracking for stainless steel and nickel alloy piping, nozzle safe ends, nozzle thermal sleeves, valves, flow elements, and pump casings. . The program to manage stress corrosion cracking and intergranular attack (SCC/lGA) in reactor coolant pressure boundary piping made of stainless steel and components made of stainless steel or nickel alloy is delineated in NUREG-0313, Revision 2, and GL 88-01 and its Supplement

1. The material includes base metal and welds. The. BWR Stress Corrosion Cracking Program meets the requirements of GL 88-01 and BWRVIP-75.

The program consists of (a) preventive measures to mitigate SCC/lGA, and (b) inspection and flaw evaluation to monitor SCC/IGA and its effects. The staff-approved BWRVIP-75 report modified the inspection scope in the GL 88-01 program. (a) preventive measures to mitigate SCC/IGA Columbia mitigates stress corrosion cracking by using, and continuing to use, materials resistant to SCC for component replacements and repairs following the recommendations delineated in GL 88-01. Prior to initial plant startup and during the first refueling outage, an induction heating stress improvement (IHSI) process was used on 148 SCCIIGA susceptible piping welds. In the 1994 refueling outage, Columbia performed a mechanical stress improvement process (MSIP) for multiple RPV nozzle to safe end and safe end to pipe welds. Columbia mitigates aging by maintaining water chemistry in accordance with the current BWRVIP guidelines, as detailed in the BWR Water Chemistry Program. Columbia has implemented hydrogen water chemistry (HWC) and noble metal chemical application (NMCA) to mitigate IGSCC. (b) Inspection and flaw evaluation The Columbia program detects and sizes cracks in accordance with the requirements of the ASME Code, Section XI, supplemented by guidelines of 'approved BWRVIP documents. Inspection of piping to detect and size cracks is performed in accordance With the staff positions on schedule, methods, and . personnel and sample expansion included in GL 88-01 and BWRVIP-75. If indications are found, sample expansion occurs per BWRVIP-75. In response to GL' 88-01, Columbia committed to using ASME Section XI Section IWB-3600 of the ASME Code for methods and criteria for crack evaluation and repair. Columbia committed to notify the Commission if a flaw is found that does not meet Section XI, IWB-3500 criteria for continued operation without evaluation . Aging Management Programs Page 8-47 January 2010 Columbia Generating Station License Renewal Application Technical Informatidn Further, Columbia committed to submit an evaluation of the flaw justifying continued operation or the repair plans to the Commission for approval prior to resuming operation. Resumption of operation will not be allowed until Commission approval has been granted. Columbia monitors reactor coolant leakage as recommended by GL 88-01 in compliance with Technical Specification 3.4.5.The BWR Stress Corrosion Cracking Program credits portions of the BWR Water Chemistry Program.NUREG-1801 Consistency The BWR Stress Corrosion Cracking Program is an existing. Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M7, "BWR Stress Corrosion Cracking." Exceptions to NUREG-1801 None.Required Enhancements None.Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Industry Experience: NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Review of recent BWR license renewal applications found the following industry experience. In 2000, Cooper Nuclear Station safe end nozzles and piping components were ultrasonically examined and found acceptable. Examinations in 2000 and in 2005 for a nozzle cap had recordable indications, which were caused by ID geometry and determined to be acceptable. Aging Management Programs Page B-48 January 2010 Aging Management Programs Page B-48 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Further, Columbia committed to submit an evaluation of the flaw justifying continued operation or the repair plans to the Commission for approval prior to resuming operation.

Resumption of operation will not be allowed until Commission approval has been granted. Columbia monitors reactor coolant leakage as recommended by GL 88-01 in compliance with Technical Specification 3.4.5 . . The BWR Stress Corrosion Cracking Program credits portions of the BWR Water Chemistry Program. NUREG-1801 Consistency The BWR Stress Corrosion Cracking Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-180*1, Section XI.M7, "BWR Stress Corrosion Cracking." Exceptions to NUREG-1801 None. Required Enhancements None. Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Industry Experience: NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Review of recent BWR license renewal applications the following industry experience. In 2000, Cooper Nuclear Station safe end nozzles and piping components were ultrasonically examined and found acceptable. Examinations. in 2000 and in 2005 for a nozzle cap had recordable indications, which were caused by 10 geometry and determined to be acceptable. Aging Management Programs Page 8-48 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information During Refueling Outage (RFO) 16 at Duane Arnold Energy Center, inspections of welds susceptible to intergranular stress corrosion cracking (IGSCC) identified flaw indications on three recirculation riser nozzle-to-safe-end welds (RRB-F002 , RRD-F002 and RRF-F002). The original scope of the examinations included three recirculation riser welds and one core spray nozzle-to-safe-end weld. The inspection scope was therefore expanded to include all of the remaining F002 welds, as well as the other similarly designed core spray welds. One weld was ground flush and re-inspected, and has been dispositioned.

Two welds were repaired using weld overlays.Columbia operating experience: One indication was identified in stainless steel recirculation system piping to valve weld 20RRC(6)-8 during Refuel Outage 6 (1991). The sample size was expanded in accordance with GL 88-01. The indication did not show IGSCC characteristics; however, it was evaluated as IGSCC. The indication was determined to be acceptable for continued operation without repair. In 1996, after four successive inspections without significant change in the indication, the indication was reclassified to an IGSCC Category E weld in accordance with GL 88-01. The NRC staff was kept informed of the indication status and concurred with the actions taken and the reclassification of the indication. The weld was examined in 2001 using technology approved as part of the EPRI Performance Demonstration Initiative and no indications associated with IGSCC were identified. It was determined that the indication was not due to IGSCC and the weld was reclassified as Category B. All previous examinations were re-evaluated using the 2001 methods, and it wasconcluded that the indication had shown no identifiable growth in either length or depth in the 10 years that it had been monitored. A second indication, identified in RRC nozzle to safe end weld 24RRC(2)A-1 in 1998, has been verified to be an original construction weld repair. There is no indication of IGSCC in this weld.Therefore, continued implementation of the program provides reasonable assurance that stress corrosion cracking of austenitic stainless steel will be managed so that components crediting the BWR Stress Corrosion Cracking Program will continue to perform their intended function consistent with the current licensing basis during the period of extended operation.The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program continues, to be effective in managing the identified aging effects.Aging Management Programs Page B-49 January 2010 Aging Management Programs Page B-49 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information During Refueling Outage (RFO) 16 at Duane Arnold Energy Center, inspections of . welds susceptible to intergranular stress corrosion cracking (IGSCC) identified flaw indications on three recirculation riser nozzle-to-safe-end welds (RRB-F002 , F002 and RRF-F002).

The original scope of the examinations included three recirculation riser welds and one core spray nozzle-to-safe-end weld. The inspection scope was therefore expanded to include all of the remaining F002 welds, as well as the other similarly deSigned core spray welds. One weld was ground flush and re-inspected, and has been dispositioned. Two welds were repaired using weld overlays. Columbia operating experience: One indication was identified in stainless steel recirculation system piping to valve weld 20RRC(6)-8 during Refuel Outage 6 (1991). The sample size was expanded in accordance with GL 88-01. The indication did not show IGSCC characteristics; however, it was evaluated as IGSCC. The indication was determined to be acceptable for continued operation without repair. In 1996, after four successive inspections without significant change in the indication, the indication was reclassified to an IGSCC Category E weld in accordance with GL 88-01. The NRC staff was kept informed of the indication status and concurred with the actions taken and the reclassification of the indication. The weld was examined in 2001 using technology approved as part of the EPRI Performance Demonstration Initiative and no indications associated with IGSCC were identified. It was determined that the indication wa*s not due to IGSCC and the weld was reclassified as Category B. All previous examinations were re-evaluated using. the 2001 methods, and it was concluded that the indication had shown no identifiable growth in either length or depth in the 10 years that it had been monitored. A second indication, identified in RRC nozzle to safe end weld 24RRC(2)A-1 in 1998, has been verified to be an original construction weld repair. There is no indication of IGSCC in this weld. Therefore, continued implementation of the program provides reasonable assurance that stress corrosion cracking of austenitic stainless steel will be managed so that components crediting the BWR Stress Corrosion Cracking Program will continue to perform their intended function consistent with the current licenSing basis during the period of extended operation. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects . Aging Management Programs Page 8-49 January 2010 Columbia Generating Station License Renewal Application Technical, Information Conclusion The BWR Stress Corrosion Cracking Program manages cracking of stainless steel and nickel alloy components. The BWR Stress Corrosion Cracking Program provides reasonable assurance that cracking of stainless steel and nickel alloy components will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-50 January 2010 Conclusion Columbia Generating Station License Renewal Application Technical Information The BWR Stress Corrosion Cracking Program manages cracking of stainless steel and nickel alloy components. The BWR Stress Corrosion Cracking Program provides reasonable assurance that cracking of stainless steel and nickel alloy components will be managed such that components subject to aging management review will continue to perform their intended functions consistent with .the current licensing basis for the period of extended operation. . Aging Management Programs Page 8-50 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information B.2.9 BWR Vessel ID Attachment Welds Program Program Description The BWR Vessel ID Attachment Welds Program will manage cracking due to SCC/IGA of the welds for internal attachments to the reactor vessel.The BWR Vessel I) Attachment Welds Program performs examinations and inspections as required by ASME Section XI, augmented by BWRVIP-48-A.

These inspections include enhanced visual inspections' with resolution to the guidelines in BWRVIP-03. Inspections are scheduled in accordance with the ASME Code, Section X1. Approval for any exceptions to the ASME Code requirements is requested from the NRC via a Relief Request or an Exemption Request. Columbia has scheduled inspections in accordance with ASME Section Xl, IWB-2400 and approved BWRVIP-48-A guidelines. If flaws are detected, the scope of the examination is expanded in accordance with ASME Section Xl and BWRVIP-48-A. Cracks are detected and sized by inspection in accordance with the guidelines of approved BWRVIP documents and the requirements of the ASME Code, Section XI.Evaluation is performed in accordance with established site procedures that require use of the ASME Code and other applicable documents, such as BWRVIP reports.The program includes preventive measures to mitigate cracking by maintaining water chemistry in accordance with the current BWRVIP guidelines using the BWR Water Chemistry Program.The BWR Vessel ID Attachment Welds Program credits portions of the BWR Water Chemistry Program, the BWR Vessel Internals Program and the Inservice Inspection (ISI) Program.NUREG-1801 Consistency The BWR Vessel ID Attachment Welds Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801 Section XI.M4, "BWR Vessel ID Attachment Welds." Exceptions to NUREG-1801 None.Required Enhancements None.Aging Management Programs Aging Management Programs Page B-51 January 2010 Page B-51 January 2010* -.

• B.2.9 BWR Vessel ID Attachment Welds Program Program Description Columbia Generating Station License Renewal Application Technical Information The BWR Vessel 10 Attachment Welds Program will manage cracking due to SCCIIGA of the welds for internal attachments to the reactor vessel. . The BWR Vessel ID Attachment Welds Program performs examinations and inspections as required by ASME Section XI, augmented by BWRVIP-48-A.

These inspections' include enhanced visual inspections' with resolution to the guidelines in BWRVIP-03.' ) Inspections are scheduled in accordance with the ASME Code, Section XI. Approval for any exceptions to the ASME Code requirements is requested from the NRC via a Relief Request or an Exemption Request. Columbia has scheduled inspections in accordance with ASME Section XI, IWB-2400 and approved BWRVIP-48-A guidelines. If flaws are detected, the scope of the examination is expanded in accordance with ASME Section XI and BWRVIP-48-A. Cracks are detected and sized by inspection in accordance with the guidelines of approved BWRVIP documents and the requirements of the ASME Code, Section XI. Evaluation is performed in accordance with established site procedures that require use of the ASME Code and other applicable documents, such as BWRVIP reports. The program includes preventive measures to mitigate cracking by maintaining water chemistry in accordance with the current BWRVIP guidelines using the BWR Water Chemistry Program. The BWR Vessel 10 Attachment Welds Program credits portions of the BWR Water Chemistry Program, the BWR Vessel Internals Program and the Inservice Inspection (lSI) Program. NUREG-1801 ConSistency , The BWR Vessel 10 Attachment Welds Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801 Section XI.M4, "BWR Vessel 10 Attach,ment Welds." Exceptions to NUREG-1801 None. Required Enhancements None . Aging Management Programs Page 8-51 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Industry operating experience: NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Review of recent License Renewal Applications found no instances of aging. At Cooper Nuclear Station, a combination of components including guide rod brackets, feedwater sparger brackets, and core spray sparger brackets was examined in 2001 and 2003 with no recordable indications for the guide rod and feedwater sparger brackets. Indications found in 2000 on the core spray sparger brackets were determined to be acceptable. Jet pump riser brace attachment pad welds and steam dryer support brackets were examined in 2003 with no indications. Holddown brackets for the surveillance specimens and steam dryer were examined in 2005 with no indications. The jet pump riser brace attachment was also examined with no indications. A review of site-specific operating experience at Duane Arnold Energy Center found no instances of degradation to the vessel ID attachment welds which required repairs.Columbia operating experience: Columbia operating experience to date has not detected any flaws in reactor vessel attachment welds. Inspections of the core spray sparger and supply piping attachment welds and five jet pump riser brace attachment welds during Refuel Outage 16 (2003) found no recordable indications. Inspection of the remaining attachment welds during Refuel Outage 17 (2005), including the feedwater bracket, steam dryer, and specimen holders, found no recordable indications. Columbia site-specific operating experience agrees with industry operating experience in that the BWR Vessel ID Attachment Welds Program has been effective in managing aging effects. Therefore, continued implementation of the program provides reasonable assurance that the effects of aging will be managed so that the reactor vessel inside diameter (ID) attachment welds will continue to perform their intended function consistent with the current licensing basis during the period of extended operation. The site corrective action program. and an ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects.Aging Management Programs Page B-52 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation.

Industry operating experience: NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Review of recent License Renewal Applications found no instances of aging. At Cooper Nuclear Station, a combination of components including guide rod brackets, feedwater sparger brackets, and core spray sparger brackets was examined in 2001 and 2003 with no recordable indications for the guide rod and feedwater sparger brackets. Indications found in 2000 on the core spray sparger brackets were determined to be acceptable. Jet pump riser brace attachment pad welds and steam dryer support brackets were examined in 2003 with no indications. Holddown brackets for the surveillance specimens and steam dryer were examined in 2005 with no indications. The jet pump riser brace attachment was also examined with no indications. A review of site-specific operating experience at Duane Arnold Energy

• Center found no instances of degradation to the vessel ID attachment welds which required repairs. Columbia operating experience:

Columbia operating experience to date has not detected any flaws in reactor vessel attachment welds. Inspections of the core spray sparger and supply piping attachment welds and five jet pump riser brace attachment welds during Refuel Outage 16 (2003) found no recordable indications. Inspection of the remaining attachment welds during Refuel Outage 17 (2005), including the feedwater bracket, steam dryer, and specimen holders, found no recordable indications. Columbia site-specific operating experience agrees with industry operating experience in that the BWR Vessel ID Attachment Welds Program has been effective in managing aging effects. Therefore, continued implementation of the program provides reasonable assurance that the effects of aging will be managed so that the reactor vessel inside diameter (ID) attachment welds will continue to perform their intended function consistent with the current licensing basis during the period of extended operation. The site corrective action program* and an ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects. Aging Management Programs Page 8-52 January 2010

• Columbia Generating Station License Renewal Application Technical Information Conclusion The BWR Vessel ID Attachment Welds Program manages cracking of the vessel internal attachment welds. The BWR Vessel ID Attachment Welds Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation.

Aging Management Programs Aging Management Programs Page 8-53 January 2010 Page B-53 January 2010* *

• Conclusion Columbia Generating Station License Renewal Application Technical Information The BWR Vessel ID Attachment Welds Program manages cracking of the vessel internal attachment welds. The BWR Vessel ID Attachment Welds Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation . Aging Management Programs Page 8-53 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.10 BWR Vessel Internals Program Program Description The BWR Vessel Internals Program will manage cracking due to SCC/IASCC, SCC/IGA, flaw growth, and flow-induced vibration for various components and subcomponents of the reactor vessel internals.

The Columbia program includes mitigation, inspection, and repair. The BWR Vessel Internals Program incorporates all of the BWRVIP guidance documents, including those specifically called out in NUREG-1 801, Section XI.M9.(a) mitigation Columbia mitigates reactor vessel internals cracking by maintaining water chemistry in accordance with the current BWRVIP guidelines using the BWR Water Chemistry, Program.(b) inspection Inspection is performed by the Inservice Inspection (ISI) Program as required by the ASME Code. Augmented inspections as recommended by the BWRVIP program are performed by the BWR Vessel Internals Program. The BWRVIP requirements typically include more stringent inspections and components beyond the ASME requirements. The Columbia program includes enhanced visual examinations, including the equipment and environmental 6conditions necessary to achieve the resolution recommended by the BWRVIP guidelines. Columbia implements all the BWRVIP requirements, including re-inspection and sample expansion requirements. Columbia detects and sizes cracks in accordance with the guidelines of approved BWRVIP documents and the requirements of the ASME Code, Section Xl, 2001 Edition, 2003 Addenda.Columbia evaluates all flaws in accordance with either the ASME code or BWRVIP guidance. Flaw evaluations that deviate from the guidance in BWRVIP reports are submitted to the NRC for approval.(c) repair Repair or replacement, as necessary, is performed in accordance with approved BWRVIP documents and ASME Section Xl, as applicable. Columbia's top guide will have received neutron fluence exceeding the IASCC threshold (5E20, E>1 MeV) before entering the period of extended operation. Columbia complies with BWRVIP-183. Although BWRVIP-183 has not yet been approved by the NRCstaff, it includes the top guide inspections recommended by NUREG-1801. BWRVIP-Aging Management Programs Page B-54 January 2010) Columbia Generating Station

• License Renewal Application Technical Information B.2.10 BWR Vessel Internals Program Program Description The BWR Vessel Internals Program will manage cracking due to SCC/IASCC, SCC/IGA, flaw growth, and flow:-induced vibration for various components and subcomponents of the reactor vessel internals.

The Columbia program includes mitigation, inspection, and repair. The BWR Vessel Internals Program incorporates all of the BWRVIP guidance documents, including those, specifically called out in NUREG-1801, Section XI.M9. (a) mitigation Columbia mitigates reactor vessel internals cracking by maintaining water chemistry in accordance with the current BWRVIP guidelines using the BWR Water Chemistry, Program. (b) inspection Inspection is performed by the Inservice Inspection (lSI) Program as required by the ASME Code. Augmented inspections as recommended by the BWRVIP program are performed by the BWR Vessel Internals Program. The BWRVIP requirements

• typically include' more stringent inspections and components beyond the ASME requirements.

The Columbia, program includes enhanced visual examinations, including the equipment and environmental conditions necessary to achieve the resolution recommended by the BWRVIP guidelines. Columbia implements all the BWRVIP requirements, including re-inspection and sample expansion requirements. Columbia detects and sizes cracks in accordance with the guidelines of approved BWRVIP documents and the requirements of the ASME Code, Section XI, 2001 Edition', 2003 Addenda. Columbia evaluates all flaws in accordance with either the ASME code or BWRVIP guidance. Flaw evaluations that deviate from the guidance in BWRVIP reports are submitted to the NRC for approval. (c) repair Repair or replacement, as necessary, is performed in accordance with approved BWRVIP and ASME Section XI, as applicabl,e. Columbia's top guide will have received neutron fluence e)(ceeding the IASCC threshold (5E20, E>1 MeV) before entering the period of extended operation. Columbia complies 'with BWRVIP-183. Although BWRVIP-183 has not yet been approved by the NRC staff, it includes the top guide inspections recommended by NUREG-1801. BWRVIP-Aging Management Programs Page 8-54 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information 183 requires either EVT-1 or UT inspection, of 10% of the top guide grid beam cells containing control rod drives and blades every 12 years with at least 5% to be performed within 6 years.The BWR Vessel Internals Program credits portions of the BWR Water ChemistryProgram and the Inservice Inspection (ISI) Program.NUREG-1801 Consistency The BWR Vessel Internals Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801 Section XI.M9, "BWR Vessel Internals." Exceptions to NUREG-1801 None.Required Enhancements None.Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation.

Industry operating experience: NUREG-1801 is based on-industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Review of recent License Renewal Applications shows that BWRs continue to inspect per the BWRVIP guidelines and that occasional indications are found and dispositioned. No indications were reported that required repair or replacement of any component. Columbia operating experience: Columbia operating experience is consistent with industry experience; a large number of examinations are being performed, and an occasional indication is being found and resolved. Columbia has found cracking of the core shroud, cracking of the steam dryer, gaps on the jet pump set screws, and wear of the jet pump wedges.All conditions have been evaluated and actions taken in accordance with approved BWRVIP documents for the component involved. No aging mechanisms not already Aging Management Programs Page B-55 January2010

• Columbia Generating Station License Renewal Application Technical Information 183 requires either EVT-1 or UT inspection.

of 10% of the top guide grid beam cells containing control rod. drives and blades every 12 years with at least 5% to be performed within 6 years. . The BWR Vessel Internals Program credits portions of the BWR Water Chemistry Program and the Inservice Inspection (lSI) Program. NUREG-1801 Consistency The BWR Vessel Internals Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801 Section XI.M9, "BWR Vessel Internals." Exceptions to NUREG-1801 None. Required Enhancements None. *. Operating Experience

• Based on review of plant-specific and industry operating experience, the identified aging require management for the period of extended operation.

Industry operating expe!rience: NUREG-1801 is based on('industry operating experience through January 2005. , Recent industry op'3rating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. _ Review of recent license Renewal Applications shows that BWRs continue to inspect per the BWRVIP guidelines and that occasional indications are found and dispositioned. No indications were reported that required repair or replacement of any component. . Columbia operating experience: Columbia operating experience is consistent with industry experience; a large number of examinations are being performed, and an occasional indication is being found and resolved. Columbia has found cracking of the core shroud, cracking of the steam dryer, gaps on the jet pump set screws, and wear of the jet pump wedges. All conditions have been evaluated and actions taken in accordance with approved BWRVIP documents for the component involved. No aging mechanisms not already Aging Management Programs Page 8-55 January 2010 Columbia Generating Station License Renewal Application Technical Information addressed by the BWRVIP have been discovered. The extensive industry operating experience with the BWRVIP to date provides assurance that the program is effective in' managing the effects of aging so that components crediting these programs will continue to perform their intended function consistent with the current licensing basis during the period of extended operation. INPO conducted a BWRVIP vessel and internals review visit at Columbia during 2005 that resulted in three recommendations for Columbia. Columbia conducted a self assessment in 2006 and determined that the BWRVIP program was effective and that the INPO recommendations had been properly implemented. The self assessment also noted that there was strong commitment to the BWRVIP program among Columbia organizations. The BWR Vessel Internals Program includes provisions to adopt future changes to BWRVIP guidelines. This ensures that operating experience from the BWR fleet will continue to be incorporated into the Columbia program.The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects.Conclusion The BWR Vessel Internals Program manages cracking for the reactor vessel internals components and subcomponents. The BWR Vessel Internals Program provides reasonable assurance that the effects of aging will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-56 January 2010 Columbia Generating Station . License Renewal Application

• Technical Information addressed by the BWRVIP have been discovered.

The extensive industry operating experience with the BWRVIP to date provides assurance that the program is effective in' managing the effects of aging so that components crediting these programs will continue to perform their intended function consistent with the current licensing basis during the period of extended operation. INPO conducted a BWRVIP vessel and internals review visit at Columbia during 2005 that resulted in three recommendations for Columbia. Columbia conducted a self assessment in 2006 and determined that the BWRVIP program was effective and that the INPO recommendations had been properly implemented. The self assessment also noted that there was strong commitment to the BWRVIP program among Columbia organizations. The BWR Vessel Internals Program includes provisions to adopt future changes to BWRVIP guidelines. This ensures that operating experience from the BWR fleet will continue to be incorporated into the Columbia program. The site corrective action program and an ongoing review of industry experience will be used to ensure that the program. continues to be effective in managing the identified aging effects. Conclusion The BWR Vessel Internals Program manages cracking for the reactor vessel internals components and subcomponents. The BWR Vessel Internals Program provides reasonable assurance that the effects of aging will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-56 January 2010 **

• Columbia Generating Station License Renewal Application Technical Information B.2.11 BWR Water Chemistry ProgramProgram Description The BWR Water Chemistry Program will mitigate damage related to loss of material due to corrosion or erosion, cracking due to SCC, and reduction of heat transfer due to fouling of plant components that are within the scope of license renewal and contain or are exposed to treated water, treated water in the steam phase, reactor coolant, or treated water in a sodium pentaborate solution. The program manages the relevantconditions (e.g., concentrations of chlorides, oxygen, and sulfates) that could lead to the onset and propagation of a loss of material, cracking, or reduction of heat transfer through proper monitoring and control consistent with the current EPRI water chemistry guidelines. The relevant conditions are specific parameters such as sulfates, halogens, dissolved oxygen, and conductivity that could lead to, or are indicative of, conditions for corrosion or SCC of susceptible materials, as well as erosion and fouling. The BWR Water Chemistry Program is a mitigation program.The BWR Water Chemistry Program is supplemented by separate one-time inspections of representative areas of treated water systems. One inspection is the Chemistry Program Effectiveness Inspection.

This one-time inspection provides further confirmation that loss of material and cracking are effectively mitigated, or to detect and characterize whether, and to what extent, degradation is occurring. The other inspection is the Heat Exchangers Inspection. This one-time inspection provides further confirmation that reduction in heat transfer is effectively mitigated, or to detect and characterize whether, and to what extent, degradation. is occurring. Additionally, the BWR Water Chemistry Program is supplemented by the BWR Feedwater Nozzle Program, BWR Stress Corrosion Cracking Program, BWR Penetrations Program, BWR Vessel ID Attachment Welds Program, BWR Vessel Internals Program, Inservice Inspection (ISI) Program, and -Small Bore Class 1 Piping Inspection to provide verification of the program's effectiveness in managing the effects of aging for reactor pressure vessel, reactor vessel internals, and reactor coolant pressure boundary components. NUREG-1801 Consistency The BWR Water Chemistry Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M2, "Water Chemistry." Exceptions to NUREG-1801 None.Aging Management Programs Page B-57 January 2010.' * ** B.2.11 BWR Water Chemistry Program Program Description Columbia Generating Station license Renewal Application Technical Information The BWR Water Chemistry Program will mitigate damage related to loss of material due to corrosion or erosion, cracking due to SCC, and reduction of heat transfer due to fouling of plant components that are within the scope of license renewal and contain or are exposed to treated water, treated water in the steam phase, reactor coolant, or . treated water in a sodium pentaborate solution. The program manages the relevant conditions (e.g., concentrations of chlorides, oxygen, and sulfates) that could lead to the onset and propagation of a loss of material, cracking, or reduction of heat transfer through proper monitoring and control consistent with the current EPRI water chemistry guidelines. The relevant conditions are specific parameters such as sulfates, halogens, dissolved oxygen, and conductivity that could lead to, or are indicative of, conditions for corrosion or SCC of susceptible materials, as well as erosion and fouling. The BWR Water Chemistry Program is a mitigation program. The BWR Water Chemistry Program is supplemented by separate one-time inspections of representative areas of treated water systems. One inspection is the Chemistry Program Effectiveness Inspection. This one-time ins*pection provides further confirmation that loss of material and cracking are effectively mitigated, or to detect and characterize whether, and to what extent, degradation is occurring. The other inspection is the Heat Exchangers Inspection. This one-time inspection provides further cOQfirmation that reduction in heat transfer is effectively mitigated, or to detect and characterize whether, and to what extent, degradation is occurring. Additionally, the BWR Water Chemistry Program is supplemented by the BWR Feedwater Nozzle Program, BWR Stress Corrosion Cracking Program, BWR Penetrations Program, BWR Vessel 10 Attachment Welds Program, BWR Vessel Internals Program, Inservice Inspection (lSI) Program, and -Small Bore Class 1 Piping Inspection to provide verification of the program's effectiveness in managing the effects of aging for reactor pressure vessel, reactor vessel internals, and reactor coolant pressure boundary components. NUREG-1801 Consistency The BWR Water Chemistry Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M2, "Water Chemistry." Exceptions to NUREG-1801 None . Aging Management Programs Page 8-57 January 2010 Columbia Generating Station License Renewal Application Technical Information Required Enhancements None.Operating Experience The BWR Water Chemistry Program is an ongoing program that effectively incorporates the best practices of industry guidance, vendor recommendations, and industry experience in defining chemistry control requirements, monitoring of plant performance in implementing them, and continual review of their adequacy. The program incorporates EPRI guideline documents as well as "lessons learned" from site and other utility operating experience. The program has been, and continues to be, subject to periodic internal and external assessment of the performance to identify strengths, potential adverse trends, and areas for improvement. In addition, quarterly program health reports are generated addressing chemistry performance indicators. Review of site-specific operating experience did not reveal a loss of component intended function for components exposed to reactor water, feedwater condensate, control rod drive water, accident mitigation water (suppression or fuel pool), or steam that could be attributed to an inadequacy of the BWR Water Chemistry Program. The known chemistry-related problems suffered by other utilities are a consideration in the ongoing refinement of the BWR Water Chemistry Program for Columbia. No change of the BWR Water Chemistry Program was required as a result of these evaluations. Abnormal chemistry conditions are promptly identified, evaluated (with increased sampling to better trend the data), and corrected. Furthermore, the program is periodically updated to the latest guidance documents. An internal self-assessment of the performance of the BWR Water Chemistry Program is conducted and reported periodically (at least annually) to identify strengths, potentially adverse trends, and areas for improvement. This assessment covers theentire program. The latest self-assessments noted that the corrective action process is used extensively in the Chemistry Department, and that data review and reporting requirements are in compliance with procedures.There were also challenges with condenser in-leakage for much of cycle 18; a long-term project to replace the condenser is underway (to solve the leakage problem and issues with copper). Past operating experience has demonstrated the effectiveness of the program in identifying out of specification reactor water chemistry conditions resulting from condenser in-leakage with prompt actions taken to restore below Action Level 1 limits.Aging Management Programs Page B-58 January 2010 Required Enhancements None. Operating Experience Columbia Generating Station License Renewal Application Technical Information The BWR Water Chemistry Program is an ongoing program that effectively incorporates the best practices of industry guidance, vendor recommendations, and industry experience in defining chemistry control requirements, monitoring of plant performance in implementing them, and continual review of their adequacy. The program incorporates EPRI guideline documents as well as "lessons learned" from site and other utility operating experience. The program has been, and continues to be, subject to. periodic internal and external assessment of the performance to identify strengths, potential adverse trends, and areas for improvement. In addition, quarterly program health reports are generated addressing chemistry performance indicators.

• Review of site-specific operating experience did not reveal a loss of component intended function for components exposed to reactor water, feedwater condensate, control rod drive water, accident mitigation water (suppression or fuel pool), or steam that could be attributed to an inadequacy of the BWR Water Chemistry Program. The known chemistry-related problems suffered by other utilities are a consideration in the ongoing refinement of the BWR Water Chemistry Program for Columbia.

No change of

• the BWR Water Chemistry Program was required as a result of these evaluations:

Abnormal chemistry conditions are promptly identified, evaluated (with increased sampling to better trend the data), and corrected. Furthermore, the program is periodically updated to the latest guidance documents. An internal self-assessment of the performance of the BWR Water Chemistry Program is conducted and* reported periodically (at least annually) to identify strengths, potentially adverse trends, .and areas for improvement. This assessment covers the entire program. The latest self"'-assessments noted that the corrective action process is used. extensively in the Chemistry Department, and that data review and reporting requirements are in compliance with procedures. There were also challenges with condenser in-leakage for much of cycle 18; a long-term project to replace the condenser is underway (to solve the leakage problem and issues with copper). . Past operating experience has demonstrated the effectiveness of the program in identifying out of specification reactor water chemistry conditions resulting from condenser in-leakage with prompt actions taken to restore below Action Level 1 limits. Aging Management Programs Page 8-58 January 2010

• Columbia Generating Station License Renewal Application Technical Information Conclusion The BWR Water Chemistry Program will manage loss of material, cracking, and reduction in heat transfer for susceptible components through monitoring and control of the relevant parameters in treated water (and steam). The BWR Water ChemistryProgram provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation.

Aging Management Programs Page B-59 January 2010* *

• Conclusion Columbia Generating Station License Renewal Application Technical Information The BWR Water Chemistry Program will manage loss of material, cracking,and reduction in heat transfer for susceptible components through monitoring and control of the relevant parameters in treated water (and' steam). The .sWR Water Chemistry Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of operation . Aging Management Programs Page January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.12 Chemistry Program Effectiveness Inspection Program DescriptionThe Chemistry Program Effectiveness Inspection is a new one-time inspection that will detect and characterize the material conditions in representative low-flow and stagnant areas of plant systems influenced by the BWR Water Chemistry Program, the Fuel OilChemistry Program, and the Closed Cooling Water Chemistry Program (which are mitigation programs).

The inspection provides direct evidence as to whether, and to what extent, a loss of material due to crevice, general, galvanic, or pitting corrosion (in treated water or fuel oil environments) has occurred. The inspection provides direct evidence as to whether, and to what extent, microbiologically-influenced corrosion (MIC)in a fuel oil environment has occurred. The inspection also provides direct evidence as to whether, and to what extent, cracking due to SCC of susceptible materials in susceptible locations has occurred.Implementation of the Chemistry Program Effectiveness Inspection will provide confirmation of program effectiveness and further assurance that the integrity of susceptible components is maintained consistent with the current licensing basis during the period of extended operation. NUREG-1801 ConsistencyThe Chemistry Program Effectiveness Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below." Scope of Program The scope of the Chemistry Program Effectiveness Inspection includes the surfaces of copper alloy, copper alloy > 15% zinc (Zn), steel, gray cast iron, -nickel alloy, and stainless steel (including cast austenitic stainless steel) components in treated water environments. The scope includes gray cast iron, copper alloy, copper alloy> 15% Zn, steel, and stainless steel components in fuel oil environments.

• Preventive Actions No actions are taken as part of the Chemistry Program Effectiveness Inspection to prevent aging effects or to mitigate aging degradation.

Aging Management Programs Page B-60 January 2010 Columbia Generating Station License Renewal Application .' Technical Information 8.2.12 Chemistry Program Effectiveness Inspection Program Description The Chemistry Program Effectiveness Inspection is a new one-time inspection that will detect and characterize the material conditions in representative low-flow and stagnant areas of plant systems influenced by the BWR Water Chemistry Program, the Fuel Oil Chemistry Program, and the Closed Cooling Water Chemistry Program (which are mitigation programs), The inspection provides direct evidence as to whether, and to what extent, a loss of material due to crevice, general, galvanic, or pitting corrosion (in treated water or fuel oil environments) has occurred. The inspection provides direct evidence as to whether, and to what. extent, microbiologically-influenced corrosion (MIC) in a fuel oil environment has occurred. The inspection also provides direct evidence as to whether, and to what extent, cracking due to SCC of susceptible materials in susceptible locations has occurred. Implementation of the Chemistry Program Effectiveness Inspection will provide confirmation of program effectiveness and further assurance that the integrity of susceptible components is maintained consistent with the current licensing basis during the period of extended operation. NUREG-1801 Consistency The Chemistry Program Effectiveness Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None. Aging Management Program Elements The results of an evaluation of each program element are provided below.

• Scope of Program The scope of the Chemistry Program Effectiveness Inspection includes the surfaces of copper alloy, copper alloy> 15% zinc (Zn), steel, gray cast iron, -nickel alloy, and stainless steel (including cast austenitic stainless steel) components in treated water environments.

The scope includes gray iron, copper alloy, copper alloy > 15% Zn, steel, and stainless steel components in fuel oil environments.

• Preventive Actions No actions are taken as part of the Chemistry Program Effectiveness Inspection to prevent aging effects or to mitigate aging degradation.

Aging Management Programs Page 8-60 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information
• Parameters Monitored or Inspected The parameters to be inspected by the Chemistry Program Effectiveness Inspection include wall thickness and visual evidence of surface degradation as measures.

of loss of material, or of cracking for stainless steel exposed to treated water above 140 OF and copper alloy > 15% Zn exposed to fuel oil. Inspections will be performed by qualified personnel using established NDE techniques, 'including visual, volumetric, and surface techniques.

• Detection of Aging Effects-The Chemistry Program Effectiveness Inspection will use a combination of established volumetric and visual examination techniques (such as equivalent to VT-1 or VT-3) performed by qualified personnel on a sample population of subject mechanical components to identify evidence of a loss of material, or cracking of stainless steel exposed to treated water above 140 OF and copper alloy > 15% Zn exposed to fuel oil, or to confirm a lack thereof on the susceptible internal and external surfaces of components.

A sample population Will be determined by engineering evaluation based on soundstatistical sampling methodology, and, where practical, focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and design margins.The Chemistry Program Effectiveness Inspection will be conducted within the 10-year period prior to the period of extended operation. Monitoring and Trending This one-time inspection activity is used to characterize conditions and to determine if, and to what extent, further actions may be required. The activity includes increasing the inspection sample size and location .if degradation is detected.The sample size will be determined by engineering evaluation of the materials of construction, the environment (i.e., service conditions), aging effects, and operating experience (e.g., time in-service, susceptible locations, lowest design margin).Unacceptable inspectioh results (if degradation is detected), if any, will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and for further monitoring and trending of the results.Acceptance Criteria Indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria, such as design minimum wall thickness for piping. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in.a loss of component intended function during the period of extended operation. Aging Management Programs Page B-61 January 2010* * *

• Parameters MonitorEld or Inspected Columbia Generating Station License Renewal Application Technical Information The parameters to be inspected by the Chemistry Program Effectiveness Inspection include wall thickness and visual evidence of surface degradation as measures.

of loss of material, 'or of cracking for stainless steel exposed to treated water above 140 of and copper alloy> 15% Zn exposed to fuel oil. will be performed by qualified personnel using established NDE techniques, i including visual, volumetric, and surface techniques.

• Detection of Aging Effects -The Chemistry Program Effectiveness Inspection will use a combination of established volumetric and visual examination techniques (such as equivalent to VT-1 or VT-3) performed by qualified personnel on a sample population of subject mechanical cor;nponents to identify evidence of a loss of material, or cracking of stainless steel exposed to treated water above 140 of and cop'per alloy> 15% Zn exposed to fuel oil, or to confirm alack thereof on the susceptible internal and external surfaces of components.

A sample population Vl(ill be determined by engineering evaluation based on sound statistical sampling methodology, and, where practical, focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and design margins. The Chemistry Effectiveness Inspection will be conducted within the 10-year period prior to. the period of extended operation.

• Monitoring and Trending , This one-time inspection activity is ,used to characterize conditions and to determine if, and to what extent, further actions may be required.

The activity includes increasing the inspedion sample size and location.if degradation is detected. The sample size will be determined by engineering evaluation of the materials of construction, the environment (i.e., service conditions), aging effects, and operating experience (e.g., time in-service, susceptible locations, lowest design margin). Unacceptable inspe!ction results (if degradation is detected), if any, will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and for further monitoring and trending of the results.

• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria, such as design minimum wall thickness for piping. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in.a loss of component intended function during the period of extended operation . Aging Management Programs Page January 2010 Columbia Generating Station License Renewal Application Technical Information
• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Operating Experience The Chemistry Program Effectiveness Inspection is a new one-time inspection activity.

The inspection provides for confirmation of material conditions, and thereby chemistry program effectiveness, near the period of extended operation. The elements comprising the inspection activity are to be consistent with industry practice.NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience identified instances of microbiologically-influenced corrosion in the fuel oil system associated-with the fire protection diesel.Corrective actions included more stringent chemical control of new fuel and biocide addition, in addition to cleaning of the tank.Required Enhancements Not applicable, this is a new activity.Conclusion Implementation of the Chemistry Program Effectiveness Inspection will verify the effectiveness of the chemistry programs in managing the effects of aging or will identify corrective actions, possibly including programmatic enhancement, to be taken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page B-62 January 2010 Columbia Generating Station License Renewal Application

• Technical Information
• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Operating Experience The Chemistry Program Effectiveness Inspection is a new one-time inspection activity.

The inspection provides for confirmation of material conditions, and thereby chemistry program effectiveness, near the period of extended operation. The elements comprising the inspection activity are to be consistent with industry practice. NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability; none was I identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience identified instances of influenced corrosion in the fuel oil system associated-with the fire protection diesel. Corrective actions included more stringent chemical control of new fuel and biocide addition, in addition to cleaning of the tank. Required Enhancements Not applicable, this is a new activity. Conclusion Implementation of the Chemistry Program Effectiveness Inspection will verify the effectiveness of the chemistry programs in managing the effects of aging or will identify corrective actions, possibly including programmatic enhancement, to betaken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page 8-62 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information B.2.13 Closed Cooling Water Chemistry ProgramProgram Description The Closed Cooling Water Chemistry Program will mitigate damage due to loss of material, cracking, and reduction in heat transfer of plantcomponents within the scope of license renewal that contain treated water in a closed cooling water system or component (e.g., heat exchanger) served by or connected to a closed cooling water system. The program manages the relevant conditions (e.g., concentrations of chlorides, fluorides, oxygen, and sulfates) that could lead to the onset and propagation of a loss of material, cracking, or reduction of heat transfer through proper monitoring and control of corrosion inhibitor corlcentrations consistent with current EPRI closed cooling water chemistry guidelines.

The relevant conditions are specific parameters such as sulfates, halogens, dissolved oxygen, and conductivity that could lead to, or are indicative of, conditions for corrosion or SCC of susceptible materials, as well. as erosion and fouling. The Closed Cooling Water Chemistry Program is a mitigation program.The Closed Cooling Water Chemistry Program includes corrosion rate measurement at a select location in the Reactor Closed Cooling Water (RCC) System. The program is supplemented by a separate one-time inspection of representative areas of select closed cooling water systems, as well as components served by or connected to those closed cooling water systems, to provide confirmation that loss of material and cracking are effectively mitigated or to further detect and characterize whether, and to what extent, degradation is occurring. The Closed Cooling Water Chemistry Program is supplemented by the Chemistry Program Effectiveness Inspection for managing loss of material and cracking. The Closed Cooling Water Chemistry Program is supplemented by the Heat Exchangers Inspection for managing reduction in heat transfer. The effectiveness inspection and at least one additional measurement of RCC corrosion rates will be performed and evaluated prior to entering the period of extended operation. NUREG-1801 Consistency The Closed Cooling Water Chemistry Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M21, 'Closed-Cycle Cooling Water System," with exceptions. Aging Management Programs Page B-63 January 2010 Aging Management Programs Page B-63.January201,0

• *
• B.2.13 Closed Cooling Water Chemistry Program Program Description Columbia Generating Station License Renewal Application Technical Information The Closed Cooling Water Chemistry Program will mitigate damage due to loss of material, cracking, and reduction in heat transfer 9f plant' components within the scope of license renewal that contain treated water in a closed cooling water system or component (e.g., heat exchanger) served by or connected to a closed cooling water system. The program manages the relevant conditions (e.g., concentrations of chlorides, fluorides, oxygen, and sulfates) that could lead to the onset and propagation of a loss of material, cracking, or reduction of heat transfer through proper monitoring' and control of 'corrosion inhibitor concentrations consistent with current EPRI closed cooling water chemistry guidelines.

The relevant conditions are specific parameters such as sulfates, halogEms, dissolved oxygen, and conductivity that could lead to, or are / indicative of, conditions for corrosion or SCC of susceptible materials, as well* as erosion and fouling. The Closed Cooling Water Chemistry Program is a mitigation program. The Closed Cooling Water Chemistry Program includes corrosion rate measurement at a select location in the Reactor Closed Cooling Water (RCC) System. The program is supplemented by a sElparate one-time inspection of representative areas of select closed cooling water systems, as well as components served by or connected to those closed cooling water systems, to provide confirmation that loss of material and cracking are effectively mitigated or to further detect and characterize whether, and to what extent, degradation is occurring. The Closed Cooling Water Chemistry Program is supplemented by the Chemistry Program Effectiveness Inspection for managing loss of material and cracking. The Closed Cooling Water Chemistry Program is supplemented by the Heat Exchangl3rs Inspection for managing reduction in heat transfer. The effectiveness inspection' and at least one additional measurement of RCC corrosion rates will be performed and evaluated prior to entering the period of extended operation. NUREG-1801 Consisb:mcy The Closed Cooling v\fater Chemistry Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in Section XI.M21, "Closed-Cycle Cooling Water System," with exceptions. ( Aging Management Programs Page 8-63 / January 201.0 Columbia Generating Station License Renewal Application Technical Information Exceptions to NUREG-1801 Program Elements Affected: Parameters Monitored or Inspected (and Detection of Aging Effects, Monitoring and Trending, and Acceptance Criteria) -The program does not include performance or functional testing for management of loss of material or cracking since performance and functional testing verify that component active functions can be accomplished but, in most cases, provide little definitive information or value with respect to the condition of passive components. In lieu of performance monitoring and functional testing, the Closed Cooling Water Chemistry Program includes measurement of corrosion rates in select RCC System locations and is supplemented by the one-time Chemistry Program Effectiveness Inspection, which includes closed cooling water system locations and heat exchangers served by closed cooling water' systems, to confirm adequate mitigation of loss of material and cracking in low flow and stagnant areas. The Closed Cooling Water Chemistry Program is supplemented by the one-time Heat Exchangers Inspection to confirm adequate mitigation of reduction in heat transfer.Required Enhancements Prior to the period of extended operation the enhancement listed below will be.implemented in the identified program element: Detection of Aging Effects -Ensure that at least one additional RCC corrosion rate measurement is performed and evaluated prior to entering the period of extended operation to provide direct. information as to the effectiveness of the chemical treatments. If necessary, based on the results, establish a frequency for subsequent measurements. Operating Experience The Closed Cooling Water Chemistry Program is an ongoing program that effectively incorporates EPRI closed cooling water guideline documents as well as "lessons learned" from site and other utility operating experience. The program has been, and continues to be, subject to periodic internal and external assessment of its performance to identify strengths and potential adverse trends. In addition, monthly reports are generated addressing chemistry performance' indicators. The February 2008 report identified the parameters for closed cooling water systems; the reactor building closed cooling water, diesel cooling water, and chilled water systems in particular, to be nominal. A November 2004 internal assessment, including industry input, found that the program does an adequate job of maintaining effective chemistry control, with a Aging Management Programs Page B-64 January 2010 Exceptions to NUREG-1801 Program Elements Affected: Columbia Generating Station License Renewal Application Technical Information

• Parameters Monitored or Inspected (and Detection of Aging Effects, Monitoring and Trending, and Acceptance Criteria)

-The program does not include performance or functional testing for management of loss of material or cracking since performance and functional testing verify that component active functions can be accomplished but, in most cases, provide little definitive information or value with respect to the condition of passive components. In lieu of performance monitoring and functional testing, the Closed Cooling Water Chemistry Program includes measurement of corrosion rates in select RCC System locations and is supplemented by the one-time Chemistry Program Effectiveness Inspection, which includes closed cooling water system locations and heat exchangers served by closed cooling water' systems, to confirm adequate mitigation of loss of material and cracking in low flow and stagnant areas. The Closed Cooling Water Chemistry Program is supplemented by the one-time Heat Exchangers Inspection to confirm adequate mitigation of reduction in heat transfer. . Required Enhancements Prior to the period of extended operation the enhancement listed below will be implemented in the identified program element:

• Detection of Aging Effects-Ensure that at least one additional RCC corrosion rate measurement is performed and evaluated prior to entering .the period of extended operation to provide direct information as to the effectiveness of the chemical treatments.

If necessary, based on the establish a frequency for subsequent measu rements. Operating Experience The Closed Cooling Water Chemistry Program is an ongoing program that effectively incorporates EPRI closed cooling water guideline documents as well as "lessons learned" from site and other utility operating experience. The program has been, and continues to be, subject to periodic internal and external assessment of its performance to identify strengths and potential adverse trends. In addition, monthly reports are generated addressing chemistry performance' indicators. The February 2008 report identified the parameters for closed cooling water systems; the reactor building closed cooling water, diesel cooling water, and chilled water systems in particular, to be nominal. A November 2004 internal assessment, including industry input, found that the program does an adequate j,ob of maintaining effective chemistry control, with a Aging Management Programs Page 8-64 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information strength being the aggressiveness in returning out-of-limit parameters to within limits in a timely manner. The assessment found no chemistry control related equipment reliability issues over the scope of the review.Review of Columbia operating experience did not reveal a loss of component intended function of subject components exposed to closed cooling water that could be attributed to an inadequacy of the Closed Cooling Water Chemistry Program. Furthermore, industry, particularly INPO, operating experience is periodically evaluated by Columbiaand incorporated into plant programs.

No changes to the Closed Cooling Water Chemistry Program were required as a result of these evaluations. Review of condition reports (CRs) indicates that abnormal chemistry conditions are identified, evaluated, and corresponding adjustments made to correct the chemistry conditions well before a loss of function would become plausible. Corrosion monitoringprobes are also used.Conclusion The Closed Cooling Water Chemistry Program will manage loss of material, cracking, and reduction in heat transfer for susceptible components through monitoring and control of the corrosion inhibitor concentrations and relevant parameters in closed cooling water systems and the components that are connected to or served by them.The Closed Cooling Water Chemistry Program, with the required enhancement, and supplemented by the one-time Chemistry Program Effectiveness Inspection and Heat Exchangers Inspection prior-to entering the period of extended operation provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-65 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information strength being the aggn3ssiveness in returning out-of-limit parameters to within limits in a timely manner. The assessment found no chemistry control related equipment reliability issues over the scope of the review. ' Review of Columbia operating experience did not reveal a loss of component intended function of subject components exposed to closed cooling water that could be attributed to an inadequacy of the Closed Cooling Water Chemistry Program. Furthermore, industry, particularly INPO, operating experience is periodically evaluated by Columbia and incorporated into plant programs.

No changes to the Closed Cooling Water Chemistry Program were required as a result of these evaluations. Review of condition reports (CRs) indicates that abnormal chemistry conditions are identified,evaluated, and corresponding adjustments made to correct the chemistry conditions well before al loss of function would become plausible. Corrosion monitoring probes are also used. Conclusion The Closed Cooling Water Chemistry Program. will manage loss of material, cracking, : and reduction in heat transfer for susceptible components through monitoring and . control of the corrosion inhibitor concentrations and relevant parameters in closed cooling water systems and the components are connected to or served by them. The Closed Cooling Water Chemistry Program, with the required enhancement,and supplemented by the one-time Chemistry Program Effectiveness Inspection and Heat Exchangers Inspection prior -to entering ,the period of extended operation provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation . Aging Management Programs Page 8-65 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.14 Cooling Units Inspection Program Description The Cooling Units Inspection is a new one-time inspection that will detect and characterize the material conditions of aluminum, steel, copper alloy, and stainless steel cooling unit components that are exposed to a condensation (internal or external)environment. The Cooling Units Inspection provides direct evidence as to whether, and to what extent, a loss of material due to crevice, galvanic, general, pitting, or microbiologically influenced corrosion, a reduction in heat transfer due to fouling of heatexchanger tubes and fins, or cracking of aluminum components, has occurred or is likely to occur that could result in a loss of intended function.Implementation of the Cooling Units Inspection will ensure that the pressure boundary integrity and heat transfer capability of susceptible components are maintained consistent with the current licensing basis during the period of extended operation. Implementation of the inspection will also provide assurance (and confirmation) that the structural integrity of susceptible NSR components will be maintained such that spatial interactions (e.g., leakage) will not result in the loss of any safety-related component intended functions during the period of extended operation. NUREG-1801 Consistency The Cooling Units Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The Cooling Units Inspection detects and characterizes conditions relative to the following subject mechanical components to determine whether, 'and to what extent, degradation is occurring:

• Loss of material due to crevice and pitting corrosion, and MIC of stainless steel components exposed to condensation.

a Loss of material due to crevice, pitting, and galvanic corrosion, cracking due to SCC, and reduction in heat transfer due to fouling of aluminum heat exchanger fins exposed to condensation. Aging Management Programs Page B-66 January 2010 Columbia Generating Station

• License Renewal Application Technical Information B.2.14 Cooling Units Inspection Program Description The Cooling Units Inspection is a new one-time inspection that will detect and characterize the material conditions of aluminum, steel, copper alloy, and stainless steel cooling unit components that are exposed to a condensation (internal or external) environment.

The Cooling Units Inspection provides direct evidence as to whether, and to what extent, a loss of material due to crevice, galvanic, general, pitting, or microbiologically influenced corrosion, a reduction in heat transfer due to fouling of heat exchanger tubes and fins, or cracking of aluminum components, has occurred or is likely to occur that could resulf in a loss of intended function. Implementation of the Cooling Units Inspection will ensure that the pressure boundary integrity and heat transfer capability of susceptible components are maintained consistent with the current licensing basis during the period of extended operation. Implementation of the inspection will also provide assurance (and confirmation) that the structural integrity of susceptible NSR components will be maintained such that spatial interactions (e.g., leakage) will not result in the loss of any safety-related component intended functions during the period of extended operation. I NUREG-1801 The Cooling Units Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801 ,Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None. Aging Management Program Elements The results of an evaluation of each program element are provided below.

• Scope of Program The Cooling Units Inspection detects and characterizes conditions relative to the following subject mechanical components to determine whether, 'and to what extent, degradation is occurring:
• Loss of material due to crevice and pitting corrosion, and MIC of stainless steel components exposed to condensation.
• Loss of material due to crevice, pitting, and galvanic corrosion, cracking due to SCC, and reduction in heat transfer due to fouling of aluminum heat exchanger fins exposed to condensation.

Aging Management Programs Page 8-66 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information" Loss of material due to crevice, pitting, and galvanic corrosion and reduction in heat transfer due to fouling of copper alloy heat exchanger tubes exposed to condensation." Loss of material due to crevice, pitting, galvanic, and general corrosion and MIC for steel components exposed to condensation.

The Cooling Units Inspection focuses on a representative sample population ofsubject components at susceptible locations to be defined in the implementing documents. The inspections identify symptomatic evidence of cracking, loss of material, or reduction in heat transfer at other susceptible locations within the scope of the inspection due to the similarities in materials and environmental conditions." Preventive Actions /No actions are taken as part of the Cooling Units Inspection to prevent aging effects or to mitigate aging degradation." Parameters Monitored or Inspected The parameters to beinspected by the Cooling Units Inspection are wall thickness or visual evidence of degradation, as measures of loss of material and cracking, and visual evidence of fouling as a measure of reduction in heat transfer. Inspections will be performed by qualified personnel using established NDE techniques.

• Detection of Aging Effects The Cooling Units Inspection will use a combination of established volumetric (radiographic testing or ultrasonic testing) and visual (VT-I or VT-3 or equivalent) examination techniques performed by qualified personnel on a sample population ofsubject components determined by engineering evaluation, to identify evidence of cracking (of aluminum), a loss of material, or fouling, or to confirm a lack thereof.The sample population will be determined by engineering evaluation based on sound statistical sampling methodology, and, where practical, will be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operation, and the lowest design margins.The Cooling Units Inspection will be conducted within the 10-year period prior to the period of extended operation.

Monitoring and Trending This one-time inspection activity is used to characterize conditions and determine if, and to what extent, further actions may be required. The activity includes provisions for increasing the inspection sample size and location if degradation is detected.The sample size will be determined by engineering evaluation of the materials of construction, the environment (i.e., service conditions), aging effects, and operating Aging Management Programs Page B-67 January 2010* ** /

• Columbia Generating Station License Renewal Application Technical Information
• Loss of material due to crevice, pitting, and galvanic corrosion and reduction in heat transfer due to fouling of copper alloy heat exchanger tubes to condensation.
• Loss of material due to crevice, pitting, galvanic, and general corrosion and MIC for steel components exposed to condensation.

The Cooling Units Inspection focuses on a representative sample population of subject components at susceptible locations to be defined in the implementing documents. The inspections identify symptomatic evidence of cracking, loss of material, or reduction in heat transfer at other susceptible locations within the scope of the inspection due to the similarities in materials and environmental conditions.

• Preventive Actions / No actions are taken as part of the Cooling Uriits Inspection to prevent aging effects or to mitigate aging degradation.
• Parameters Monitored or Inspected The parameters to be, inspected by the Cooling Units Inspection are wall thickness or visual evidence of degradation, as measures of loss of material and cracking, and visual evidence of fouling as a measure of reduction in heat transfer.

Inspections will be performed by qualified personnel using established NDE techniques.

• Detection of Aging Effects The Cooling Units Inspection will use a combination of established volumetric (radiographic or ultrasonic testing) and visual (VT;.f or VT-3 or equivalent) examination techniques performed by qualified personnel on a sample population of su,bject components determined by engineering revaluation, to identify evidence of cracking (of aluminum), a loss of material, or fouling, or to confirm a lack thereof. . ( The sample population will be determined by engineering evaluation based. on sound statistical sampling methodology, and, where practical, will be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operation, and the lowest design margins. The Cooling Units Inspection will be conducted within the 1 O-year period prior to the period of extended operation.
• Monitoring a,nd Trending This one-time inspection activity is used to characterize conditions and determine if, and to what extent, further actions may be required.

The activity includes provisions for increasing the inspection sample size and location if degradation is detected. The sample size will be determined by engineering evaluation of the materials of construction, the environment (i.e., service conditions), aging effects, and operating Aging Management Programs Page 8-67 January 2010 Columbia Generating Station License Renewal Application Technical Information experience (e.g., time in-service, most susceptible locations, lowest design margins).Inspection findings that do not meet the acceptance criteria will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and for monitoring and trending of the results.Acceptance Criteria Indications or relevant conditions of degradation detected during the inspections will be compared to pre-determined acceptance criteria. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Operating Experience The Cooling Units Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effects. The inspection provides for confirmation of material conditions near the period of extended operation.

The elements comprising the inspection activity are to be consistent with industry practice.NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience, documented in recent work orders, revealed that cooling unit coils have been found clean and no leakage was observed.Aging Management Programs Page B-68 January 2010 Aging Management Programs Page B-68 January 2010 Columbia Generating Station License Renewal Application Technical Information experience (e.g., time in-service, most susceptible locations, lowest design margins). Inspection findings that do not meet the acceptance criteria will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and for monitoring and trending of the results.

• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspections will be compared to pre-determined acceptance criteria.

If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in* Section B.1.3.
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.'
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience The Cooling Units Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effects. The inspection provides for confirmation of material conditions near the period of extended operation.

The elements comprising the inspection activity are to be consistent with industry practice. NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience, documented in recent work orders, revealed that cooling unit coils have been. found clean and no leakage was observed. Aging Management Programs Page 8-68 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information The site corrective action program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for components within the scope of this activity.Required Enhancements Not applicable, this is a new activity.Conclusion Implementation of the Cooling Units Inspection will verify that there are no aging effects requiring management for the subject components, or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation and that spatial interactions (e.g., leakage) will not result in loss of safety-related component intended functions during the period of extended operation.

Aging Management Programs Page B-69 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information The site corrective action program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for components within the scope of this activity.

Required Enhancements Not applicable, this is a new activity. Conclusion Implementation of the Cooling Units Inspection will verify that there are no aging effects requiring management for the subject components, or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current licensing'basis during the period of extended operation and that spatial interactions (e.g., leakage) will not result in loss of safety-related component intended functions during the period of extended operation. . Aging Management Programs Page 8-69 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.15 CRDRL Nozzle Program Program Description The CRDRL Nozzle Program manages cracking due to flaw growth of the control rod drive return line (CRDRL) nozzle, safe end, cap, and connecting welds. This program was developed in response to industry events involving the control rod drive return linenozzle. The program includes modifications, mitigation, and inspection.(a) modification Columbia has modified the CRDRL by the second option discussed in NUREG-1801, XI.M6, cutting and capping the CRDRL with no alternate return line flow established. The modifications were performed prior to initial startup of the Columbia Unit. Modifications were completed by the vessel Original Equipment Manufacturer (OEM).Since the modifications were performed prior to initial startup of the Columbia Unit, CRD system functionality was demonstrated by the initial system testing, as described in FSAR Section .14.2. This startup testing and subsequent system operation have demonstrated CRD return flow capacity.(b) mitigation Columbia mitigates CRDRL nozzle cracking by maintaining water chemistry in accordance with the current BWRVIP guidelines using the BWR Water Chemistry Program.(c) inspection The CRDRL Nozzle Program performs ultrasonic inspection of the nozzle in accordance with ASME Section XI, subsection IWB.The nozzle to safe end and safe end to cap are category B-J welds and are covered by the Risk Informed ISI Program. In part because of the all low alloy steel construction that is not susceptible to stress corrosion cracking, these are low riskwelds and are not scheduled for inspection in the third 10-year interval.Enhanced ISI / Maintenance Programs are not required as Columbia did not install an altdrnate return line.NUREG-1801'states that the effects of cracking will also be monitored in accordance with NUREG-0619. For licensees who have cut and capped the CRD return line nozzle with rerouting of the CRD return line, NUREG-0619 requires that during each refueling outage the licensee inspect the welded connection joining the rerouted CRD return line to the system which then returns flow to the reactor vessel. Columbia has used the second option, of not Aging Management Programs Page B-70 January 2010 8.2.15 CRDRL Nozzle Program Program Description Columbia Generating Station License Renewal Application Technical Information The CRDRL Nozzle Program manages cracking due to flaw growth of the control rod drive return line (CRDRL) nozzle, safe end, cap, and connecting welds. This program was developed in response to industry events involving the control rod' drive return line nozzle. The program includes modifications, mitigation, and inspection. (a) modification Columbia has modified the CRDRL by the second option discussed in NUREG-1801, XI.M6, cutting and capping the CRDRL with no return line flow established. The modifications were performed prior to initial startup of the Columbia Unit. Modifications were completed by the vessel Original Equipment Manufacturer (OEM). Since the modifications were performed prior to initial startup of the Columbia Unit, . CRD system functionality was demonstrated by the initial system testing, as described in FSAR Section 14.2. This startup testing and subsequent sysfem operation have demonstrated CRD return flow capacity. (b) mitigation Columbia mitigates CRDRL nozzle cracking by maintaining water chemistry in accordance with the current BWRVIP guidelines using the BWR Water Chemistry Program. (c) inspection The CRDRL Nozzle Program performs ultrasonic inspection of the nozzle in accordance with ASME Section XI, subsection IWB. The nozzle to safe end and safe end to cap are category B-J welds and are covered by the Risk Informed lSI Program. In part because of the all low alloy steel construction that is not susceptible to stress corrosion cracking, these are low risk welds and are not scheduled for inspection in the third 1 O-year interval. Enhanced lSI/Maintenance Programs are not required as Columbia did not install an alternate return line.NUREG-180f'states that the effects of cracking will also be monitored in accordance with NUREG-0619. For licensees who have cut and capped the CRD return line nozzle with rerouting of the CRD return line, NUREG-0619. requires that during each refueling outage the licensee inspect the welded connection joining the rerouted CRD return line to the system which then returns flow to the reactor vessel. Columbia has used the second option, of not Aging Management Programs Page 8-70 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information establishing an alternate return line flow, so there is no alternate connection to inspect. This NUREG-0619 requirement is not applicable to Columbia.Cracking found during inservice inspection is evaluated and dispositioned in accordance with ASME Section XI, subsection IWB. Removing cracks by mechanical means is acceptable per ASME Section XI. However, recent industry practice has been to repair such cracks by weld overlay, in accordance with Code Cases N504-2 and N638. Columbia does not anticipate any indications in their low alloy steel CRDRL nozzle welds; however, should indications be found and repair be required, all available repairtechniques would be evaiuated.

If Columbia opts for a repair technique different from ASME Section Xl, a relief request will be submitted for NRC review and approval.The CRDRL Nozzle Program credits portions of the BWR Water Chemistry Program and the Inservice Inspection (ISI) Program.NUREG-1801 Consistency The CRDRL Nozzle Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M6, "BWR Control Rod Drive Return Line Nozzle." Exceptions to NUREG-1801 None.Required Enhancements None.Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Industry Experience: Recent License Renewal Applications report that the CRDRL Nozzle Program is effectively managing aging. During RE22 in 2005 the Cooper Nuclear Stations control rod drive return line nozzle inner radius weld and the nozzle-to shell weld were ultrasonically examined and found acceptable. Absence of -aging effectsindicates that the preventive actions of the program have been effective. The last inspection of the CRDRL stagnant water pipe welds at Duane Arnold Energy Center was performed during Refueling Outage 18. No indications were found in the welds.Aging Management Programs Page B-71 January.2010

• *
• Columbia Generating Station License Renewal Application Technical Information establishing an alternate return line flow, so there is no alternate connection to inspect. This NUREG-0619 requirement is not applicable to Columbia.

Cracking found during inservice inspection is* evaluated and dispositioned in accordance with ASME Section XI, subsection IWB. Removing cracks by mechanical means is acceptable per ASME Section XI. However, recent industrY practice has been to repair such cracks by weld overlay, in accordance with Code. Cases N504-2 and N638. Columbia does not anticipate. any indications in their low alloy steel CRDRL nozzle welds; however, should indications be found and repair be required, all available repair'techniques would be evaiuated. If Columbia opts for a repair technique different from ASME Section XI, a relief request will be submitted for NRC review and approval. The CRDRL Nozzle Program credits portions of the BWR Water Chemistry Program and the Inservice Inspection (lSI) Program. NUREG-1801 Consistency The CRDRL Nozzle Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described inNUREG-1801, Section XI.M6, "BWRControl Rod Drive Return Line Nozzle." Exceptions to NUREG-1801 None. Required Enhancements None. Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation . . Industry Experience: Recent License Renewal Applications report that the CRDRL Nozzle Program is effectively managing aging. During RE22 in 2005 the Cooper Nuclear Stations control rod drive return line nozzle inner radius weld and the nozzle-to shell weld were ultrasonically examined and found acceptable. Absence of aging effects indicates that the preventive actions of the program have been effective. The last inspection of the CRDRL stagnant water pipe welds at Duane Arnold Energy Center was performed during Refueling Outage 18. No indications were found in the welds . Aging Management Programs Page 8-71 January 2010 Columbia Generating Station License Renewal Application Technical Information Columbia operating experience: Columbia operating experience is consistent with industry experience and confirms that the CRDRL Nozzle Program is effective in managing cracking of the CRDRL nozzle. Periodic inspections of the CRDRL nozzle, during the second 10-year ISI interval found no cracking. Therefore, continued implementation of the program provides reasonable assurance that the effects of aging will be managed so that the CRDRL nozzle, safe end, cap, and connecting welds will continue to perform their intended function consistent with the current licensing basis during the period of extended operation. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects.Conclusion The CRDRL Nozzle Program will manage cracking of the CRDRL nozzle, safe end, cap, and connecting welds. The CRDRL Nozzle Program provides reasonable assurance that cracking will be managed such that the subject components will continue to perform their intended function consistent with the current licensing basis for the period of extended operation. Aging Management Programs Aging Management Programs Page 8-72 January 2010 Page B-72 January 2010/ Columbia operating experience: Columbia Generating Station License Renewal Application Technical Information Columbia operating experience is consistent with industry experience and confirms that the CRDRL Nozzle Program is effective in managing cracking of the CRDRL nozzle. Periodic inspections of the CRDRL nozzle, during the second 10-yearlSI interval found no cracking. Therefore, continued implementation of the program . provides reasonable assurance that the effects of aging will be managed so that the CRDRL nozzle, safe end, cap, and connecting welds will continue to perform their intended function consistent with the current licensing basis during the period of extended operation. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects. Conclusion The CRDRL Nozzle Program will manage cracking of the CRDRL nozzle, safe end, cap, and connecting welds. The CRDRL Nozzle Program provides reasonable .assurance that cracking will be managed such that the subject components will continue to perform their intended function consistent with the current licensing basis for the period of

• extended operation.
• Aging Management Programs Page 8-72 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.16 Diesel Starting Air InspectionProgram Description The Diesel Starting Air Inspection is a new one-time inspection that will detect and characterize the material condition of the air dryers and downstream stainless steel and steel piping and components in the DSA System (excluding the DSA System air receivers).

The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion has occurred or is likely to occur.Implementation of the Diesel Starting Air. Inspection will provide confirmation that controls on compressed air quality are effective for the DSA System. and that theintegrity of the air dryers and downstream piping and-components (excluding the DSA System air receivers), will be maintained consistent with the current licensing basis during the period of extended operation. NUREG-1801 Consistency The Diesel Starting Air Inspection is a new one-time inspection for Columbia that will be consistent with the 1() elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The scope of the Diesel Starting Air Inspection includes the air dryers and, conservatively, the downstream stainless steel and steel piping and components in the DSA System (excluding the DSA System air receivers). The DSA System is subject to periodic air quality sampling inspections through the Air Quality Sampling Program to verify that the dewpoint is within specified limits.The, Diesel Starting Air Inspection will confirm that the controls on moisture content of the air have been effective in ensuring that unacceptable degradation is not occurring in the air dryers and downstream piping and components (excluding the DSA System air receivers). Preventive Actions No actions are taken as part of the Diesel Starting Air Inspection to prevent aging effects or to mitigate aging degradation. Aging Management Programs Page B-73 January 2010* *

• B.2.16 Diesel Startil1lg Air Inspection Program Description Columbia Generating Station License Renewal Application Technical Information The Oiesel Starting Air Inspection is a new one-time inspection that will detect and characterize the material condition of the air dryers and downstream stainless steel and steel piping. and components in the DSA System (excluding the DSA System air 'receivers).

The inspection provides direct evidence as to whether, an,d to what extent, a loss of material due to corrosion has occurred or is likely to occur. Implementation of the Diesel Starting Air. Inspection will provide confirmation that controls on compressed air quality are effective for the DSA System. and that the integrity of the air dryers and downstream piping and_components (excluding the DSA System air receivers), will be maintained consistent with the current licensing basis during the period of extended operation. . NUREG-1801 ConsistE!ncy The Diesel Starting Air Inspection is a new one-time inspection for Columbia that will be consistent* with the 1 () elements of an effective aging management program as described in NUREG-1B01, Section XI.M32,"One-Time Inspection." Exceptions to NUREG-1801 None. Aging Management Prrogram Elements The results of an evaluation of each program element are provided below.

• Scope of Program The scope of the Diesel Starting Air Inspection includes the air dryers and, conservatively; the downstream stainless steel and steel piping and components in the DSA System (e)(c1uding the DSA System air receivers).

The DSA System is subject to periodic air quality sampling inspections through the Air Quality Sampling Program to verify that the dewpoint is within specified limits. ,The, Diesel Starting Air Inspection will confirm that the controls on moisture content of the air have be!en effective in ensuring that unacceptable degradation is not occurring in the air dryers and downstream piping and components (excluding the DSA System air rec:eivers).

• Preventive Actions No actions are taken as part of the Diesel Starting Air Inspection to prevent aging effects or to aging degradation . Aging Management Programs Page 8-73 January 2010 Columbia Generating Station License Renewal Application Technical Information
• Parameters Monitored or Inspected The parameters to be inspected by the Diesel Starting Air Inspection include wall thickness or visual evidence of internal surface degradation, of the DSA System air dryers and downstream piping and components (excluding the DSA System air receivers) as measures of loss of material.

Inspections will be performed by qualified personnel using established NDE techniques (i.e., ultrasonic examination). Visual inspection of downstream piping and components for evidence of corrosion and corrosion products may be performed.

• Detection of Aging Effects The Diesel Starting Air Inspection will use a combination of established visual examination techniques and 'non-destructive methods performed by qualified personnel on a sample population of the DSA System air dryers and downstream piping and components (excluding the DSA System air receivers) to identify evidence of any loss of material.There are three air dryers in the DSA System. A sample population of these air dryers and the downstream piping and components will be determined by engineering evaluation based on sound statistical sampling methodology.

The results of previous inspections will be utilized in consideration of those components most susceptible to degradation. Components will also be evaluated based upon time in service, the severity of conditions during normal plant operation (i.e., the results of the air quality sampling), and design margins.The Diesel Starting Air Inspection will be conducted within the 10-year period prior to the period of extended operation.

• Monitoring and Trending No actions are taken as part of the Diesel Starting Air Inspection to monitor or trend inspection results. This is a one-time inspection activity used to determine if, and to what extent, further actions (including monitoring and trending) may be required.Sample size will be determined by engineering evaluation, as described in the Detection of Aging Effects element above. Results of the inspection activities that require further evaluation and resolution (e.g., if degradation is detected), will be evaluated using the Columbia corrective action process, including expansion of the sample size and inspection locations to determine the extent of the degradation.
• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspections will be compared to pre-determined acceptance criteria.

If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation. Aging Management Programs Page B-74 January 2010"

• Parameters Monitored or Inspected Columbia Generating Station License Renewal Application Technical Information The parameters to be inspected by the Diesel Starting Air Inspection include wall thickness or visual evidence of internal surface degradation, of the DSA System air dryers and downstream piping and components (excluding the DSA System air receivers) as measures of loss of material.

Inspections will be performed by qualified personnel using established NDE techniques (i.e., ultrasonic examination). Visual inspection of downstream piping and components for evidence of corrosion and corrosion products may be performed.

• Detection of Aging Effects The Diesel Starting Air Inspection will use a combination of established visual examination techniques and' non-destructive methods performed by qualified personnel on a sample population of the DSA System air dryers and downstream piping and components (excluding the DSA System air receivers) to identify evidence of any loss of material.

'

• There are three air dryers in the DSA System. A sample population of these air dryers and the downstream piping and components will be determined by engineering evaluation based on sound statistical sampling methodology.

The results of previous inspections will be utilized in consideration of those components most susceptible to degradation. Components will also be evaluated based upon time in service, the severity of conditions during normal plant operation (i.e., the * 'results of the air quality sampling), and design margins. The Diesel Starting Air Inspection will be conducted within the 1 O-year period prior to the period of extended operation.

• Monitoring and Trending No actions are taken as part of the Diesel Starting Air Inspection to monitor or trend inspection results. This is a one-time inspection activity used to determine if, and to what extent, further actions (including monitoring and trending) may be required.

Sample size will be determined by engineering evaluation, as described in the Detection of Aging Effects element above. Results of the inspection activities that require further evaluation and resolution (e.g., if degradation is detected), will be evaluated using the Columbia corrective action process, including expansion of the sample size and inspection locations to determine the extent of the degradation.

• Acceptance Criteria Indications or relevant conditions of degradation detected during.the inspections will be compared to pre-determined acceptance criteria.

If the acceptance criteria are not met, then the indication's and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation. Aging Management Programs Page 8-74 January 2010 /

• Columbia Generating StationLicense Renewal Application Technical Information
• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3." Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3." Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Operating Experience The Diesel Starting Air Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effect. The inspection is intended to determine the condition of the DSA System air dryers as well as of the downstream piping and components (excluding the DSA System air receivers), and whether additional controls are required for the period of extended operation.

NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience reveals that the air receiver tanks have been inspected regularly for indications of loss of material. Relevant operating experience associated with DSA System air receivers is used to identify relevant age related degradation for the DSA System; however, aging of the DSA System air receivers is managed by the Air Quality Sampling Program. Inspection techniques for the air dryers and downstream piping and components will be consistent with accepted industry practices.The site corrective action program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for components within the scope of this activity.Required Enhancements Not applicable, this is a new activity.Aging Management Programs Page B-75 January 2010* *

• Corrective Actions Columbia Generating Station License Renewal Application Technical Information This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation' and is discussed in Section 8.1.3.
• Operating Experience The Diesel Starting Air Inspection is a new one-time inspection activity for which plant operating experience has not shown' the occurrence of the aforementioned aging effect. The inspection is intended to determine the condition of the DSA System air dryers as well as of the downstream piping and components (excluding the DSA System air receivers), and whether additional controls are required for the of extended operation.

NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience reveals that the air receiver tanks have been inspected for indications of loss of material. Relevant operating experience associated with DSA System air receivers is used to identify relevant age related degradation for the DSA System; however, aging of the DSA System air receivers is managed by the Air Quality Sampling Program. Inspection techniques for the air dryers and downstream piping and components will be consistent with accepted industry practices. . I The site corrective action program and an ongoing review of industry operating experience will be used' to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for components within the scope of this activity. Required Enhancements

• Not applicable, this is al new activity.

Aging Management Programs Page 8-75 January 2010 Columbia Generating Station, License Renewal Application Technical Information Conclusion Implementation of the Diesel Starting Air Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions of the DSA System will be maintained consistent with the current licensing basis during the period of extended operation. 0 AgngMnaemn Pogas ag -7 Jnar 21 Aging Management Programs Page B-76 January 2010 Conclusion Columbia Generating Station* License Renewal Application Technical Information Implementation of the Diesel Starting Air Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly* including programmatic oversight, to* be taken to ensure that the component intended functions of the DSA System will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page 8-76 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information B.2.17 Diesel Systems Inspection Program Description The Diesel Systems Inspection is a new one-time inspection that will detect and characterize the material condition of the interior of the exhaust piping for the Division 1, 2, and 3 diesels in the Diesel Engine Exhaust System, including the loop seal drains from the exhaust piping, and the drain pans and drain piping associated with air-handling units of the Diesel Building HVAC systems. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion has occurred or is likely to occur.Implementation of the Diesel Systems Inspection will provide confirmation that the integrity of the subject components will be maintained consistent with the current licensing basis during the period of extended operation.

NUREG-1801 Consistency The Diesel Systems Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1 801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The scope of the Diesel Systems Inspection includes the steel exhaust piping exposed to an air-outdoor environment, and the loop seal drains from the exhaust piping that are exposed to a raw water environment, for the following diesel engines: DG-ENG-1AI/1A2

• DG-ENG-1BI/1B2
• DG-ENG-1C* DSA-ENG-C/2C Additionally the stainless steel drain pans and steel drain piping exposed to a raw water environment and associated with the following equipment are in the scope of the Diesel Systems Inspection:

Aging Management Programs Page B-77 January 2010* *

• 8.2.17 Diesel Systems Inspection Program Description Columbia Generating Station License Renewal Application Technical Information The Diesel Systems Inspection is a new one-time inspection that will detect and characterize the material condition of the interior of the exhaust piping for the Division 1, 2, and 3 diesels in the Diesel Engine Exhaust System, including the loop seal drains from the exhaust piping, and the drain pans and drain piping associated with* handling units of the Diesel Building HVACsystems.

The inspection provides direct evidence as to whether, and to what extent, a loss of material due to corrosion has occurred or is likely to occur. Implementation of the Diesel Systems Inspection will provide confirmation that the integrity of the subject components will be maintained consistent with the* current licensing basis during the period.of extended operation. NUREG-1801 ConsistE!ncy The Diesel Systems Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1 B01, Section XI,M32, "One-Time Inspection." . Exceptions to NUREG-1801 None. Aging Management Program Elements The results ofan evaluation of each program element are provided below.

• Scope of Program The scope of the Diesel Systems Inspection includes the steel exhaust piping exposed to an air-outdoor environment, and the loop seal drains from the exhaust piping that are exposed to a raw water environment, for the following diesel engines: .* DG-ENG-1A'1/1A2
• DG-ENG-1B1/1B2
• DG-ENG-1C
• DSA-ENG-C/2C Additionally the stainless steel drain pans and steel drain piping exposed to a raw water environment and associated with the following equipment are in the scope of the Diesel Systems Inspection:

Aging Management Programs Page 8-77 January 2010 Columbia Generating StationLicense Renewal Application Technical Information DMA-AH-11, 12, 21, 22, 31, 32, and 51 (air-handling unit housings)* Preventive Actions No actions are taken as part of the Diesel Systems Inspection to prevent aging effects or to mitigate aging degradation.

• Parameters Monitored or Inspected The parameters to be inspected by the Diesel Systems Inspection include wall thickness or visual evidence of internal surface degradation, of the diesel exhaust piping and the drain pans and drain piping as measures of loss of material.Inspections will be performed by qualified personnel using established NDE techniques (i.e., ultrasonic examination).

Visual inspection of the internals for evidence of corrosion and corrosion products may be performed as opportunities for access arise.* Detection of Aging Effects The Diesel Systems Inspection will use a combination of established volumetric and visual examination techniques (such as equivalent to VT-1 or VT-3) performed by qualified personnel on a representative sample of the subject components to identify evidence of loss of material.The sample population will be determined by engineering evaluation based on sound statistical sampling methodology, and, where practical, will be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and design margins.The Diesel Systems Inspection will be conducted after the issuance of the renewed license and prior to the end of the current operating license, with sufficient time to implement programmatic oversight for the period of extended operation. The activities will be conducted no earlier than 10 years prior to the end of the current operating license, so that conditions are more representative of the conditions expected during the period of extended operation. Monitoring and Trending This one-time inspection activity is used to characterize conditions and to determine if, and to what extent, further actions may be required. The activity includes provisions for increasing the inspection sample size and locations if degradation is detected.The sample size will be determined by engineering evaluation of the materials of construction, the environment (i.e., service conditions), aging effects, and operating experience (e.g., time in-service, susceptible locations, lowest design margins).Inspection findings that do not meet the acceptance criteria will be evaluated using Aging Management Programs Page B-78 January 2010 Columbia Generating Station License Renewal Application

• Technical Information
• DMA-AH-11, 12, 21, 22, 31, 32, and 51 (air-handling unit housings)
• Preventive Actions No actions are taken as part of the Diesel Systems Inspection to prevent aging effects or to mitigate aging degradation.
• Parameters Monitored or Inspected The parameters to be inspected by the Diesel Systems Inspection include wall thickness or visual evidence of internal surface degradation, of the diesel exhaust piping and the drain pans and drain piping as measures of loss of material.

Inspections will be performed by qualified personnel using established NDE techniques (i.e., ultrasonic examination). Visual inspection of the internals for evidence of corrosion and corrosion products may be performed as opportunities for access arise.

• Detection of Aging Effects The Diesel Systems Inspection will use a combination of established volumetric and visual examination techniques (such as equivalent to VT-1 or VT-3) performed by qualified personnel on a representative sample of the subject components to identify evidence of loss of material.

The sample population will be determined by engineering evaluation based on

• sound statistical sampling methodology, and, where practical, will be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and design margins. The Diesel Systems Inspection will be conducted after the issuance of the renewed license and prior to the end of the current operating license, with sufficient time to implement programmatic oversight for the period of extended operation.

The activities will be conducted no earlier than 10 years prior to the end of the current operating license, so that conditions are more representative of the conditions expected during the period of extended operation.

• Monitoring and Trending This one-time inspection activity is used to characterize conditions and to determine if, and to what extent, further actions may be required.

The activity inCludes provisions for increasing the inspection sample size and locations if degradation is detected. The sample size will be determined by engineering evaluation of the materials of construction, the environment (i.e., service conditions), aging effects, and operating experience (e.g., time in-service, susceptible locations, lowest design margins). Inspection findings that do not meet the acceptance criteria will be evaluated using Aging Management Programs Page 8-78 January 2010

• Columbia Generating Station License Renewal Application Technical Information the Columbia corrective action process to determine the need for subsequent aging management activities and for further monitoring and trending of the results.
• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria.

Inspection results will be compared against minimum wall thickness values established in accordance withdesign requirements or engineering evaluation. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intendedfunction during the period of extended operation.

• Corrective Actions This element is common to Columbia, programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3." Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3." Operating ExperienceThe Diesel Systems Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effect. The activity provides confirmation of conditions where degradation is not expected, has not evidenced as a problem, or where the'aging mechanism is slow acting. The inspection provides for confirmation of material conditions near the period of extended operation.

The elements comprising the inspection activity are to-be consistent with industry practice.NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience to date has found no indications of loss of material in the subject diesel system components. The site corrective action Aging Management Programs Page B-79 January 2010.-*

• Columbia Generating Station License Renewal Application Technical Information the Columbia corrective action process to determine the need for subsequent aging management activitiE!S and for further monitoring and trending of the results.
• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria.

Inspection results will be compared against minimum wall thickness values established in accordance with design requirements or engineering evaluation. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action' program to determine whether they could result in a loss of component intended function during the period of extended operation.

• Corrective Actions This element is common to Columbia, programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3 .
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. .
• Operating ExperienGe The Diesel Systems Inspection is a new one-time inspection activity for which plant operating experienc:e has not shown the occurrence of the aforementioned aging effect. The activity provides confirmation of conditions where degradation is not expected, has not E!videnced as a problem, or where the 'aging mechanism is slow acting. The inspection provides for confirmation of material conditions near the period of extended operation.

The elements comprising the inspection activity are to ,be consistent with industry practice. NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience to date has found no indications of loss of material in the subject diesel system components. The site corrective action Aging Management Programs Page 8-79 January 2010 Columbia Generating Station License Renewal Application Technical Information program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for components within the scope of this activity.Required Enhancements Not applicable, this is a new activity.Conclusion Implementation of the Diesel Systems Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the intended functions of the subject components will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page 8-80 January 2010 Aging Management Programs Page B-80 January 2010 Columbia Generating Station License Renewal Application Technical Information program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for components within the scope of this activity. Required Enhancements Not applicable, this is a new activity. Conclusion Implementation of the Diesel Systems Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the intended functions of the subject components will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page 8-80 January 2010

• Columbia Generating Station License Renewal Application Technical Information B.2.18 Diesel-Driven Fire Pumps Inspection Program Description The Diesel-Driven Fire Pumps Inspection is a new one-time inspection that will detect and characterize the material condition of the interior of the Fire Protection System diesel engine exhaust piping, and of Fire Protection System diesel heat exchangers exposed to a raw water (antifreeze) environment.

The inspection provides direct evidence as to whether, and to what extent, a loss of material or reduction in heat transfer has occurred or is likely to occur that could result in a loss of intended function.The inspection also determines whether cracking due to stress corrosion cracking of susceptible materials has occurred. Implementation of the Diesel-Driven Fire Pumps Inspection will ensure that the pressure boundary, structural integrity, and heat transfer capability of susceptible components is maintained consistent with the current licensing basis during the period of extended operation. NUREG-1801 Consistency The Diesel-Driven Fire Pumps Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The scope of the Diesel-Driven Fire Pumps Inspection includes the steel exhaust lines that are exposed to an air-outdoor environment and copper alloy, copper alloy> 15% Zn, gray cast iron, and stainless steel heat exchanger components exposed to a raw water (antifreeze) environment for the following diesels: 0 FP-ENG-1 a FP-ENG-110

• Preventive Actions No actions are taken as part of the Diesel-Driven Fire Pumps Inspection to prevent aging effects or to mitigate aging degradation.

Aging Management Programs Page B-81 January 2010 Aging Management Programs Page B-81 January 2010* *

• 8.2.18 Diesel-Driven Fire Rumps Inspection Program Description Columbia Generating Station License Renewal Application Technical Information The Diesel-Driven Fire Pumps Inspection is a new one-time inspection that will detect and characterize the material condition of the interior of the Fire Protection System diesel engine exhaust piping, ahd of Fire Protection System diesel heat exchangers exposed to a raw water (antifreeze) environment.

The inspection provides direct evidence as to whether, and to what extent, a loss of material or reduction in heat transfer has occurred or is likely to occur that could result in a loss of intended function. The inspection also determines whether cracking due to stress corrosion cracking of susceptible materials has occurred. Implementation of the Diesel-Driven Fire Pumps Inspection will ensure that the pressure boundary, structural integrity, and heat transfer capability of susceptible! components is maintained consistent with the current licensing basis during the period of extended operation. NUREG-1801 Consistency The Diesel-Driven Fire Pumps Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None. Aging Management Pirog ram Elements . The results of an evaluation of each program element are provided , .

• Scope of Program The scope of the Diesel-Driven Fire Pumps Inspection includes the steel exhaust lines that are exposed to an air-outdoor environment and copper alloy, copper alloy > 15% Zn, gray cast iron, and stainless steel heat exchanger components exposed to a raw water (antifreeze) environment for the following diesels:
• FP-ENG-1
• FP-ENG-110
• Preventive Actions No actions are taken as part of the Diesel-Driven Fire Pumps Inspection to prevent aging effects or to mitigate aging degradation . Aging Management Programs Page 8-81 January 2010 Columbia Generating Station License Renewal Application Technical Information
• Parameters Monitored or Inspected The parameters to be inspected by the Diesel-Driven Fire Pumps Inspection include: wall thickness or visual evidence of internal surface degradation, of the diesel exhaust piping and heat exchangers as measures of cracking, loss of material, or reduction in heat transfer.

Inspections will be performed by qualified personnel using established NDE techniques (i.e., ultrasonic examination). Visual inspection of the internal surfaces for evidence of corrosion, corrosion products, or fouling may be performed." Detection of Aging Effects The Diesel-Driven Fire Pumps Inspection will use a combination of established volumetric and visual examination techniques (such as equivalent to VT-1 or VT-3)performed by qualified personnel on the subject components to identify evidence of loss of material due to corrosion or erosion. In addition, the inspection will determine whether cracking due to stress corrosion cracking of copper alloy > 15% Zn or reduction in heat transfer due to fouling of copper alloy and stainless steel heatexchanger tubes exposed to a raw water (antifreeze) environment is occurring. The inspection locations will be determined by engineering evaluation and, where practical, focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and lowest design .margins.The Diesel-Driven Fire Pumps Inspection activities will be conducted within the 10-year period prior to the period of extended operation.

• Monitoring and Trending This one-time inspection activity is used to characterize conditions and to determine if, and to what extent, further actions may be required. The activity includes provisions for increasing the number of inspection locations if degradation is detected.There are two components in the scope of the inspection (FP-ENG-1 and FP-ENG-1 10). The inspection locations include the exhaust lines and heat exchanger parts associated with those components.

The inspection locations will be determined by engineering evaluation. Inspection findings that do not meet the acceptance criteria will be evaluated using the Columbia corrective actioh process todetermine the need for subsequent aging management activities and for further monitoring and trending of the results.* Acceptance Criteria Indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective Aging Management Programs Page B-82 January 2010* Parameters Monitored or Inspected Columbia Generating Station License Renewal Application Technical Information The parameters to be inspected by the Diesel-Driven Fire Pumps Inspection include: wall thickness or visual evidence of internal surface degradation, of the diesel exhaust piping and heat exchangers as measures of cracking, loss of material, or reduction in heat transfer. Inspections will be performed by qualified personnel using established NDE techniques (i.e., ultrasonic examination). Visual inspection of the internal surfaces for evidence of corrosion, corrosion products, or fouling may be performed. * . Detection of Aging Effects The Diesel-Driven Fire Pumps Inspection will use a* combination of established volumetric and visual examination techniques (such as equivalent to VT-1 or VT-3) performed by qualified personnel on the subject components to identify evidence of loss of material due to corrosion or erosion. In addition, the inspection will determine whether cracking due to stress corrosion cracking of copper alloy> 15% Zn or reduction in heat transfer due to fouling of copper alloy and stainless steel heat exchanger tubes exposed to a raw water (antifreeze) environment is occurring.

• The inspection locations will be determined by engineering evaluation and, where practical, focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and lowest design margins.
• The Diesel-Driven Fire Pumps Inspection activities will be conducted within the 10-year period prior to the period of extended operation.
• Monitoring and Trending This one-time inspection activity is used to characterize conditions and to determine if, and to what extent, further actions may be required.

The activity includes provisions for increasing the number of inspection locations if degradation is detected. There are two components in the scope of the inspection (FP-ENG-1 and ENG-110). The inspection locations include the exhaust lines and heat exchanger parts associated with those components. The inspection locations will be determined by engineering evaluation. Inspection findings* that do not meet the acceptance criteria will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and* for further monitoring and trending of the results.

• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria.

If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective Aging Management Programs Page 8-82 . January 2010

• Columbia Generating Station License Renewal Application Technical Information action program to determine whether they could result in a loss of component intended function during the period of extended operation.
• Corrective Actions This element is common to Columbia programs and aging management during the period of extended Section B.1.3.* Confirmation Process This element is common to Columbia programs and aging management during the period of extended Section B.1.3.* Administrative Controls This element is common to Columbia programs and aging management during the period of extended Section B.1.3.activities that are operation and is activities that are operation and is activities that are operation and is credited with discussed in credited with discussed in credited with discussed in Operating Experience The Diesel-Driven Fire Pumps Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effects. The activity provides confirmation of conditions where degradation is not expected, has not been observed, or where the aging mechanism is slow acting. The elements comprising the inspection activity are to be consistent with industry practice.NUREG-1801 is based on industry 'operating experience through. January 2005.Recent industry operating experience has been reviewed for applicability; none was identified.

Future operating experience is captured through the normal operating ,experience review process, which will continue through the period of extended operation. A review of Columbia operating experience reveals past issues associated with the subject components, including a loose clamp, a small oil leak, discolored oil, and a damaged connection pipe. None of these, issues are age-related, nor do, they involve the subject exhaust piping or heat exchanger components. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate. method for managing the effects of aging for components within the scope of this activity.Required Enhancements Not applicable, this is a new activity.(Aging, Management Programs Page B-83 January 2010*

• Columbia Generating Station License Renewal Application Technical Information action program to determine whether they could result in a loss of component intended function during the period of extended operation.
• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Operating Experience The Diesel-Driven Fire Pumps Inspection is a new one-time inspection activity for which plant* operelting experience has not shown the occurrence of' the aforementioned aging effects. The activity provides *confirmation of conditions where degradation is not expected; has not been observed, or where the aging mechanism is slow acting. The elements comprising the inspection activity are to be consistent with industry practice . . NUREG-1801 is based on industry 'operating experience through. January 2005: Recent indLlstry opelrating experience has been reviewed for applicability; none was identified.

Future ()perating experience is captured through the normal operating review process, which will continue through the period of extended operation, A review of Columbia operating experience reveals past issues associated with the subject components, including a loose clamp, a small oil leak, discolored oil, and a damaged connection pipe. None of these issues are age-related, nor do they involve the subject exhaust piping or heat exchanger components. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that a one-time _ inspection activity remains the appropriate methoci for managing the effects of aging for components within the scope of this activity. Required Enhancements

• Not applicable, this is a new activity.

Aging Management Programs Page 8-83 January 2010 Columbia Generating Station License Renewal Application Technical Information, Conclusion Implementation of the Diesel-Driven Fire Pumps Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions of the subject components will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page B-84 January 2010 Conclusion 1 Columbia Generating Station License Renewal Application Technical Information . Implementation of the Diesel-Driven Fire Pumps Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions of the subject components will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page 8-84 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information B.2.19 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements ProgramProgram Description The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program will manage the aging of electrical cables and connections that are not environmentally qualified and are within the scope of license renewal. The program provides for the periodic visual inspection of accessible, non-environmentally qualified electrical cables and connections, in order to determine if age-related degradation is occurring, particularly in plant areas with adverse localized environments caused by high temperatures or high radiation levels. The program will provide reasonable assurance that the electrical components will continue to perform their intended functions for the period of extended operation.

The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program is a new aging management program that will be implemented prior to the period of extended operation, and will be repeated every 10 years thereafter. NUREG-1801 Consistency The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program is a new Columbia program that will be consistent with the 10 elements of aneffective aging management program as described in NUREG-1801, Section XI.E1,"Electrical Cables and Connections Not Subject to 10 CFR 50.49 Environmental Qualification Requirements." Exceptions to NUREG-1801 None.Aging Management Program Elements i The results of an evaluation of each program element are provided below. Scope of Program The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program includes all cables and connections (terminal blocks, fuse holders, and electrical penetration assemblies) that are not subject to the EQ requirements of 10 CFR 50.49 and that are within the scope of license renewal. The program is credited with detecting aging effects from adverse localized environments in non-environmentally qualified cables and connections. This program is directed by physical location in the plant; because there is no simple way (during an inspection) to determine which components are in scope for license Aging Management Programs Page B-85 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information 8.2.19 Electrical Calbles and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program . Program Description The Electrical Cables and Connections.

Not Subject to 10 CFR 50.49 EO Requirements Program will manage the aging of electrical cables and connections that are not environmentally qualified and are within the scope of license renewal. The program provides for the periodic visual inspection of accessible, non-environmentally qualified electrical cab.les and connections, in order to determine if age-related degradation is occurring, particularly in plant areas with adverse 10calizE!d environments caused by high temperatures or high radiation levels. The program will provide reasonable assurance that the electrical components will continue to perform their' intended fu'nctions for the period of extended operation. The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Program is a new aging management program that will be implemented prior to the period of extended operation, and will be repeated every 10 years thereafter. NUREG-1801 ConsistEmcy The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Program is a new Columbia program that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.E1, "Electrical Cables and Connections' Not Subject to 10 CFR 50.49 Environmental Qualification Requirements." Exceptions to NUREG-1801 None. Aging Management Program Elements .The results of an evaluation of each program element are provided below.

• Scope of Program . The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Program includes all cables and connections (terminal blocks, fuse holders, and electrical penetration assemblies) that are not subject to the EQ requirements of 10 CFR 50.49 and that are within the scope of license renewal. The program is credited with detecting aging effects from adverse localized environments in non-environmentally qualified cables and connections.

This program is directed by physical location in the plant; because there is no simple way (during an inspection) to determine which components are in scope for license Aging Management Programs Page 8-85 January 2010 Columbia Generating Station License Renewal Application Technical Information renewal and which are not, the program inspections will be prioritized based on location rather than component identification or function.Particular attention will be given to the identification of adverse localized environments. The inspection program will define these areas through a review of plant engineering data (EQ records, environmental surveys, etc.) and plant walkdowns." Preventive Actions The Electrical Cables and Connections Not Subject to 10CFR50.49 EQ Requirements Program is an inspection program; no actions are taken to prevent or mitigate aging degradation.' The program is based on visual observation (and detection) only.* Parameters Monitored or Inspected The Electrical Cables and Connections Not Subject to 10CFR50.49 EQ Requirements Program will provide for the visual inspection of accessible cables and connections located in. adverse localized environments. The implementing documents for the program will provide the technical basis for the sample selection, with respect to both sample size and inspection locations. Temperature, radiation,and moisture levels will be considered, along with cable insulation material.The Electrical Cables and Connections Not Subject to 10CFR50.49 EQ Requirements Program focuses on a visual inspection of accessible cables and connections. The calbles and connections will not be touched during the inspection (either lifted, separated, felt, or handled in any way). The inspection will record the visible condition of the cable jacket or the visible condition of the connection (splice, terminal block, fuse block, etc.).Detection of Aging Effects As described above in Parameters Monitored or Inspected, the Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program provides for a visual inspection of a representative sample of accessible electrical cables and connections located in adverse localized environments. The visual inspections will be performed on a 10-year interval, with the first inspection taking place within the 10-year period prior to the end of the current operating license. The program will inspect the accessible cables and connections for aging effects due to heat, radiation, and moisture, in the presence of oxygen. The visible effects -are embrittlement, discoloration, cracking, and surface contamination. Monitoring and Trending The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program will not include trending actions. If anomalies are found Aging Management Programs Page B-86 January 2010 Columbia Generating Station License Renewal Application

• . Technical Information renewal and which are not, the program inspections will be prioritized based on location rather than component identification or function.

Particular attention will be given to the* identification of adverse localized environments. The inspection program will define these areas through a review of plant engineering data (EQ records, environmental surveys, etc.) and plant walkdowns.

• Preventive Actions The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program is an inspection program; no actions are taken to prevent or mitigate aging degradation.\

The program is based on visual observation (and detection) only.

• Parameters Monitored or Inspected The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program will provide for the visual inspection of accessible cables and connections located in. adverse localized environments.

The implementing documents for the program will provide the technical basis for the sample selection, with respect to both sample size and inspection locations. Temperature, radiation, and moisture levels will be considered, along with cable insulation material. The Electrical Cables and Connections Not Subject. to 10 CFR 50.49 EQ . Requirements Program focuses on a visual inspection of accessible cables and connections. The cables and connections will not be touched during the inspection (either lifted, separated, felt, or handled in any way). The inspection will record the visible condition of the cable jacket or the visible condition .of the connection (splice, terminal block, fuse block, etc.).

• Detection of Aging Effects As described above in Parameters Monitored or Inspected, the Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program provides for a visual inspection of a representative sample of accessible electrical cables and connections located in adverse localized environments.

The visual inspections will be performed on a 10-year interval, with the first inspection taking place within the 10-year period prior to the end of the current operating license. The program will inspect the accessible cables and connections for aging effects dl!e to heat, radiation, and moisture, in the presence of oxygen. The visible effects 'are embrittlement, discoloration, cracking, and surface contamination.

• Monitoring and Trending The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program will not include trending actions. If anomalies are found Aging Management Programs Page 8-86 January 2010
• Columbia Generating Station License Renewal Application Technical Information during the visual inspection process, they will be addressed at that time through the corrective action process.Acceptance Criteria The inspections of accessible cables and connections will identify unacceptable visual indications of surface anomalies, such as embrittlement, cracking, discoloration, crazing, crumbling, melting, and any other distinct visual evidence of oxidation, material deterioration, or other visible degradation.

The implementing documents for the Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program will provide specific guidance on the identification of surface degradation. Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.In addition, for the Electrical Cables and Connections Not Subject to 10 CFR 50.49 Requirements Program, all unacceptable visual indications of cable and connection jacket surface anomalies are subject to an engineering evaluation. The evaluation will consider the age and operating experience of the component, as well as the severity of the anomaly and whether the anomaly has previously been correlated to degradation of the conductor insulation or connections. Corrective actions may include, but are not limited to, testing, shielding or otherwise changing the environment, and relocation or replacement of the affected cable or connection. When an unacceptable condition or situation is identified, a determination will be made as to whether the same condition or situation is applicable to other in-scope cables or connections. Confirmation Process This element is-common to Columbia programs and activities that are crelited with*aging management during the period of extended, operation and is discussed in Section B.1.3." Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Operating Experience The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program is a new program for which there is no direct site-specific operating. experience. Based on review of plant-specific and industry operating Aging Management Programs Aging Management Programs Page B-87 January 2010 Page B-87 January 2010* * * ( . Columbia Generating Station License Renewal Application Technical Information during the visual inspection process, they will be addressed' at that time through the corrective action proGess.

• Acceptance Criteria The inspections of accessible cab!es and connections will identify unacceptable visual indications of surface anomalies, such as embrittlement, cracking, discoloration, crumbling, melting, and any other distinct visual evidence of oxidation, material deterioration, or other visible*degradation. "I The implementing d()cuments for the Electrical Cables and Connections Not Subject to 10 CFR 50.49 Eel Requirements Program will provide specific guidance on the of surface degradation.
• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. In addition, for the Electrical Cables and Connections Not Subject to 10 CFR 50.49 Requirements Program, all unacceptable visual indications of cable and connection jacket surface anomalies are subject to an engineering evaluation.

The evaluation will consider the age and operating experience of the component, as well as the severity of the anomaly and whether the anomaly has previously been correlated to degradation of the conductor insulation or connections. Corrective actions may include, but are not limited to, testing, shielding or otherwise changing the environment, and relocation .or replacement of the affected cable or connection. When an unacceptable condition or situation is identified, a determination will be made as to whether the same condition or situation is applicable to other in-scope cables or connections.

• Confirmation Process This element is'common to Columbia programs and activities that are creCiited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation' and is discussed in* Section B. 1 .3.
• Operating Experience i The Electrical Calbles and Connections Not Subject to 10 CFR50.49 EO Requirements Program is a new program for which there is no direct site-specific operating experienGe, 'Based on review of plant-specific and industry operating Aging Management Programs Page 8-87 January 2010 Columbia Generating Station License Renewal Application Technical Information experience, the identified aging effects require management for the period of extended operation.

Plant operating experience has shown that the corrective action program hasaddressed issues of cable degradation in recent years. Cables have been identified with degraded insulation, primarily as a result of exposure to excessive localized overheating. For example, wiring on an insulated cable associated with the B phase of a motor connection was found to be degraded from overheating, due to the hot connection. Also, wiring to level switches located in the Turbine Building was found to be embrittled as a result of close proximity to hot piping. Cables have also been identified with mechanical damage, such as crimping or pinching (although these are not aging issues). Industry operating experience will be included in the development of this program.Required Enhancements Not applicable, this is a new program.Conclusion The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program Will manage aging effects due to heat, radiation, and moisture, in the presence of oxygen, for non-environmentally qualified cables and connections. The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Program will provide reasonable assurance that the aging effects will be managed such that the non-environmentally qualified cables and connections subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-88 January 2010 Aging Management Programs Page B-88 January 2010 Columbia Generating Station License Renewal Application Technical Information experience, the identified aging effects require management for the period of . extended operation. Plant operating experience has shown that the corrective action program has addressed issues of cable degradation in recent Cables have been identified with degraded insulation, primarily as a result of exposure to excessive localized overheating. For example, wiring on an insulated cable associated with the B phase of a motor connection was found to be degraded from overheating, due to the hot connection. Also, wiring to level switches located in the Turbine Building was found to be embrittled as a result of close proximity to hot piping. Cables have also been identified with mechanical damage, such as crimping or pinching (although these are not aging issues). Industry operating experience will be included in the development of this program . . Required Enhancements Not applicable, this is a new program. Conclusion The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Program will manage aging effects due to heat, radiation, and moisture, in the presence of oxygen, for non-envirdnmentally qualified cables and connections. The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Program will provide reasonable assurance that the aging effects will be managed such that the non-environmentally qualified cables and connections subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-88 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information B.2.20 Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program Program Description The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program will detect and identify age-related degradation associated with sensitive, high-voltage, low-current instrumentation cables and connections that are not environmentally qualified and are within the scope of license renewal. This program addresses a subset of the overall. in-scope, non-environmentally qualified cable and connection population at Columbia (which is primarily addressed by the program guidelines of the NUREG-1801, Section XI.EIprogram -see Section B.2.19).The program applies to in-scope, non-environmentally qualified electrical cables and connections used in circuits with sensitive, high-voltage, low-current signals (such as radiation monitoring and nuclear instrumentation loops). The sensitive nature of these circuits is such that visual inspection alone may not detect degradation to the insulation resistance function of the conductor insulation.

This program will provide the technical input necessary to manage the aging of the non-environmentally qualified low-current instrumentation cables and connections within the license renewal scope. The program relies upon a review of calibration records for surveillance tests'routinely performed on the circuits to determine if any degradation to the cable system is occurring. Reduced insulation resistance is the parameter of interest. The cables associated with this program at Columbia are not disconnected from their instruments when the present surveillance testing is performed. The program retains the option to perform direct cable testing.The following instruments are the components within the scope of the program:* In-Containment Hi Range Radiation Detectors* Intermediate Range Neutron Monitors* Local and Average Power Range Neutron Monitors* Main Steam Line Radiation Detectors" Reactor Building Exhaust Plenum Radiation Detectors" Radwaste Building Remote Intake Radiation Detectors* Standby Service Water Radiation Detectors The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ RequirementsUsed in Instrumentation Circuits Program is a new aging management program that willbe implemented prior to the period of extended operation, and will be performed every 10 years thereafter. Aging Management Programs Page B-89 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information B.2.20 Electrical Cables and Connectiol1s Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program Program Description The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program will detect and identify age-related degradation associated with sensitive, low-current instrumentation cables and connections that are not environmentally qualified and are within the scope of license renewal. This program addresses a subset of. the overall. in-scope, non-environmentally qualified cable and connection population at Columbia (which is primarily addressed by the program guidelines of NUREG-1801, Section XI.EI program -see Section 8.2.19). The program applies to in-scope, non-environmentally qualified electrical cables and connections used in circuits with sensitive, high-voltage, low-current signals (such as radiation monitoring and nuclear instrumentation loops). The sensitive nature of these circuits is such that visual inspection alone may not detect degradation to the insulation resistance function of the conductor insulation.

This program will provide the technical input necessary to manage the aging of the non-enVironmentally qualified 10w-currel1t instrumentation cables and connections within the license renewal scope. The program relies upon a review of calibration records for surveillance tests'routinely performed on the circuits to determine if any degradation to the cable system is occurring. Reduced I insulation resistance is the parameter of interest. The cables associated with this program at Columbia are not disconnected from their instruments when the present surveillance testing is performed. The program retains the option to perform direct cable testing. ( The following instruments are the components within the scope of the program:

• In-Containment Hi Range Radiation Detectors (
• Intermediate Range Neutron Monitors
• Local and Average Power Range Neutron Monitors
• Main Steam Radiation Detectors
• Reactor Buildingl Exhaust Plenum Radiation Detectors
• Radwaste Building Remote Intake Radiation Detectors
• Standby Water Radiation Detectors The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program is a new aging management program that will be implemented prior to the period 'of extended operation, and will be performed every 10 years thereafter.

..-Aging Management Programs Page 8-89 January 2010 Columbia Generating Stati6nLicense Renewal Application Technical Information NUREG-1801 Consistency The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program is a new Columbia program that will be consistent with the 10 elements of an effective aging management program, as described in NUREG-1801, Section XI.E2, "Electrical Cables and Connections Not Subject to 10 CFR 50.49 Environmental Qualification Requirements Used in Instrumentation Circuits." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The Electrical Cables and Connections Not Subject to 10CFR50.49 EQ Requirements Used in Instrumentation Circuits Program is credited with identifying aging effects for sensitive, high-voltage, low-current signal applications that are in-scope for license renewal. These sensitive circuits are potentially subject to reduction in insulation resistance (IR) when found in adverse localized environments. The scope of the circuits in the program will be detailed fully in the implementing documents. The scope of the program includes the following components:

• In-Containment Hi Range Radiation Detectors (connectors) (CMS-RIS-27E/F)
• Intermediate Range Neutron Monitors (all)* Local and Average Power Range Neutron Monitors (all)* Main Steam Line Radiation Detectors (MS-RIS-61OA/B/C/D)" Reactor Building Exhaust Plenum Radiation Detectors (REA-RIS-609A/B/C/D)
• Radwaste Building Remote Intake Radiation Detectors (WOA-RIS-31A/B, -32A/B)* Standby Service Water Radiation Monitors (SW-RIS-604/605)
• Preventive Actions The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program involves a review of calibration records of low-current instruments designed to identify cable (and Aging Management Programs Aging Management Programs Page B-90 January 2010 Paige B-90 January 2010 Columbia Generating Station
• License Renewal Application Technical Information NUREG-1801 Consisten'cy The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program is a new Columbia program that will be consistent with the 10 elements of an effective aging management program, as described in NUREG-1801, Section XI.E2, "Electrical Cables and Connections Not Subject to 10 CFR 50.49 Environmental Qualification Requirements Used in Instrumentation Circuits." Exceptions to NUREG-1801 None. Aging Management Program Elements The results of an evaluation of each program element are provided below. * $cope of Program The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program is credited with identifying , aging effects for sensitive, high-voltage, low-current signal applications that are in-scope for license renewal. These sensitive circuits are potentially subject to
• reduction in insulation resistance (IR) when found in adverse localized environments.

The scope of the circuits in the program will be detailed fully in the implementing documents. The scope of the program includes the following components:

• In-Containment Hi Range Radiation Detectors (connectors) (CMS-RIS-27E/F)
• Intermediate Range Neutron Monitors (all)
• Local and Average Power Range Neutron Monitors (all)
• Main Steam Line Radiation Detectors (MS-RIS-610AlB/C/D)
• Reactor Building Exhaust Plenum Radiation Detectors (REA-RIS-609A/B/C/D)
• Radwaste Building Remote Intake Radiation Detectors (WOA-RIS-31 AlB, -32A1B)
• Standby Service Water Radiation Monitors (SW-RIS-604/605)
• Preventive Actions The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program involves a review of calibration records of low-current instruments designed to identify cable (and Aging Management Programs , Page 8-90 January 2010
• Columbia Generating StationLicense Renewal Application Technical Information connection) degradation; no actions are taken to prevent or mitigate aging degradation.
• Parameters Monitored or Inspected The parameters monitored (reviewed) by the Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program are determined from the specific calibration surveillances.

The calibration records (from surveillance testing) of the circuits will be reviewed to determine if there is any indication of the existence of aging effects based on acceptance criteria related to instrumentation circuit performance. The program retains the option to perform direct cable testing of selected circuits." Detection of Aging Effects The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program will perform a review of the calibration (surveillance testing) records of the cable systems of sensitive, high-voltage, low-current instrumentation circuits to identify indications of the existence of aging effects based on acceptance criteria related to instrumentation circuit performance. The initial calibration records review will be conducted prior to the period of extended operation, with subsequent reviews to be conducted at least once every 10 years, with the frequency to be determined by engineering evaluation.The program retains the option to perform direct cable testing of selected circuits. If direct cable testing is performed, it will be a proven cable system test for detecting deterioration of the insulation system (such as insulation resistance testing, time-domain reflectometry testing, or other testing judged to be effective in determining the cable insulation condition). Testing will be conducted at least once every 10 years." Monitoring and Trending The Electrical Cables and Connections Not Subject to 10CFR50.49 EQ Requirements Used in Instrumentation Circuits Program does not include trending actions as part of the program. The review of calibration test results (or, if used, direct cable testing) that can be trended provides additional information on the rate of degradation." Acceptance Criteria The acceptance criteria for the Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program will be provided by the implementing documents for the program. Results outside the acceptance criteria will be evaluated in conjunction with the corrective action process. The program will utilize guidance from surveillance test procedures in evaluating the readings (anomalies) that are reviewed.Aging Management Programs Page 8-91 January 2010 Aging Management Programs Page B-91 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information connection) degradation; no actions are taken to prevent or mitigate aging degradation.
• Parameters Monitored or Inspected The parameters monitored (reviewed) by the Electrical Cables and Connections Not ,Subject to 10 CFR 50.49 EO Requirements Used in Instrumentation Circuits Program are determined from the specific calibration surveillances.

The calibration records (from surveillance testing) of the circuits will be reviewed to determine if there is any indication of the existence of aging effects based on acceptance criteria related to instrumentation circuit performance. The program retains the option to perform direct cable testing of selected circuits,

• Detection of Aging E.ffects \ The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits' Program will perform a review of the calibration (surveillance testing) records of the cable systems of sensitive, voltage, low.:.current instrumentation circuits to identify indications of the existence of aging effects on acceptance criteria related to instrumentation circuit performance.

The initial calibration records review will be conducted prior to the period of extended operation, with subsequent reviews to be conducted at least once every 10 years, with the frequency to be determined byengineering evaluation . The program retains the option to perform direct cable testing of selected circuits, If direct cable testing is performed, it will be a proven cable system test for detecting deterioration of the insulation system (such as insulation resistance testing, domain reflectometry testing, or other testing judged to be effective in determining the cable insulation condition). Testing will be conducted at least once every 10

• Monitoring and Trending The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Used in Instrumentation Circuits Program does not include trending actions as part of the program. The review of calibration test results (or, if used, direct cable testing) that can be trended provides additional information on the rate of degradation.
• Acceptance Criteria The acceptance criteria for the Electrical Cables and Connections Not Subject to . 10 CFR 50.49 EO Requirements Used in Instrumentation Circuits Program will be provided by the implementing documents for the program. Results outside the 'acceptance criteria will be evaluated in conjunction with the corrective action process. The will utilize guidance from surveillance test procedures in evaluating the readings (anomalies) that are reviewed . Aging Management Programs Page 8-91 January 2010 Columbia Generating StationLicense Renewal Application Technical Information" Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.In addition, for the Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program, corrective actions such as recalibration and circuit trouble-shooting are implemented when calibration or surveillance results do not meet the acceptable criteria.

An engineering evaluation is performed when the test acceptance criteria are not met in order to ensure thatthe intended functions of the electrical cable system can be maintained consistent with the current licensing basis. Such an evaluation will consider the significance of the test results, the operability of the component, the reportability of the event, the extent of the concern, the potential root causes for not meeting the test acceptance criteria, the corrective actions required, and the likelihood of recurrence." Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Operating Experience The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program is a new program for which there is no direct site-specific operating experience. Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation.Plant operating experience has shown that the corrective action program has addressed issues of cable degradation in recent years. Cables have been identified with degraded insulation, primarily as a result of exposure to excessive localized overheating. Low-current instrument cable issues have also been identified during loop testing, such as a failed source range monitor cable. An intermediate range monitor cable was found smashed against a ladder (although this is not an insulation resistance aging issue). Industry operating experience will be considered in the development of this program.Required Enhancements Not applicable, this is a new program. *Aging Management Programs Page B-92 January 2010 Columbia Generating Station

• License Renewal Application Technical Information
• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1 .. 3. In addition, for the Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Used in Instrumentation Circuits Program, corrective actions such as recalibration and circuit trouble-shooting are implemented when calibration or surveillance results do not meet the acceptable criteria.

An engineering evaluation is performed when the test acceptance criteria are not met in order to ensure that the intended functions of the electrical cable system can be maintained consistent with the current licensing basis. Such an evaluation will consider the significance of the test results, the operability of the component, the reportability of the event, the extent of the concern, the potential root causes for not meeting the test acceptance criteria, the corrective actions required, and the likelihood of

• Confirmation Process This element is common to Columbia programs and ,activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Administrative Controls
• This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Used in Instrumentation Circuits Program is a new program for which there is no direct site-specific operating experience.

Based on review of specific and industry operating experience, the identified aging effects require management for the period of extended operation. Plant operating experience has shown that the corrective action program has . addressed issues of cable degradation in recent years. Cables have been identified with degraded insulation, primarily as a result of exposure to excessive localized overheating. Low-current instrument cable issues have also been identified during loop testing, such as a failed source range monitor cable. An interm.ediate range monitor cable was found smashed against a ladder (although this is not an insulation resistance aging issue).* Industry operating experience will be considered in the development of this program. Required Enhancements Not applicable, this is a new program. Aging Management Programs Page 8-92 January 2010

• Columbia Generating Station License Renewal Application Technical Information Conclusion The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program will manage reduction in insulation resistance for non-environmentally qualified cables and connections used in sensitive, high-voltage, low-current circuits.

The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EQ Requirements Used in Instrumentation Circuits Program will provide reasonable assurance that the aging effects will be managed such that the non-environmentally qualified cables and connections used in sensitive, high-voltage, low-current-circuits that are subject to aging management review, will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-93 January 2010* *

• Conclusion Columbia Generating Station License Renewal Application Technical Information The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Used in Instrumentation Circuits Program will manage reduction in insulation resistance for non-environmentally qualified cables and connections used in sensitive, voltage, low-current circuits .* The Electrical Cables and Connections Not Subject to 10 CFR 50.49 EO Requirements Used in Instrumentation Circuits Program will provide reasonable assurance that the aging effects will be 'managed such that the non-environmentally qualified cables and connections used in sensitive, high-voltage, low-current

,-circuits that are subject to aging management review, will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. . Aging Management Programs Page 8-93 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.21 Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements InspectionProgram Description The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection will detect and identify aging effects for the metallic parts of non-environmentally qualified electrical cable connections within the scope of license renewal.This inspection will address cable connections that are used to connect cable conductors to other cables or electrical end devices, such as motor terminations, switchgear, motor control centers, bus connections, transformer connections, and passive electrical boxes such as fuse cabinets. The most common types of connections used in nuclear power plants are splices (butt splices or bolted splices), crimp-type ring lugs, connectors, and terminal blocks. Most connections involve insulating material and metallic parts. The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection will focus primarily on bolted connections. This aging management inspection will account for aging stressors such as thermal cycling, ohmic heating, electrical transients, vibration, chemical contamination, corrosion, and oxidation of the, metallic parts. Implementation of this inspection will provide added assurancethat the electrical connections in the plant have electrical continuity and are not overheating due to increased resistance. Performance of this inspection will confirm the absence of aging degradation on electrical cable connections. The Electrical Cable Connections Not Subject to 10 CFR 50.49'EQ Requirements Inspection is a new aging management activity (a one-time inspection) that will be conducted prior to the period of extended operation. NUREG61801 Consistency The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection is a new one-time inspection that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XlE6,"Electrical Cable Connections Not Subject to 10 CFR 50.49 Environmental Qualification Requirements," with exceptions. Exceptions to NUREG-1801 Program Elements Affected: Detection of Aging Effects -The one-time inspection does not provide for periodic testing (i.e., at least once every 10 years). Because electrical cable connections for many end devices (such as motors, bus connections, and transformers) are inspected (and repaired Aging Management Programs Page B-94 January 2010 I Columbia Generating Station License Renewal Application

• Technical Information 8.2.21 Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection Program Description The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection will detect and identify aging effects for the metallic parts* of non-environmentally qualified electrical cable connections within the scope of license renewal. This inspection will address cable connections that are used to connect cable conductors to other cables or electrical end devices, such as motor terminations, switchgear, motor control centers, bus connections, transformer connections, and passive electrical boxes such as fuse cabinets.

The most common types of connections used in nuclear power plants are splices (butt splices or bolted splices), crimp-type ring lugs, connectors, and terminal blocks. Most connections involve insulating material and metallic parts. The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection will focus primarily on bolted connections. This aging management inspection will account for aging stressors such as thermal cycling, ohmic heating, electrical transients, vibration, chemical contamination, corrosion, and oxidation of the. metallic parts. *Implementation of this inspection will provide added assurance that the electrical connections in the plant have electrical continuity and are not

• overheating due to increased resistance.

Performance of this inspection will confirm the absence of aging degradation on electrical cable connections. The Electrical Cable Connections Not Subject to 10 CFR 50.49 . EQ Requirements Inspection is a new aging management activity (a one-time inspection) that will be conducted prior to the period of extended operation. NUREG*1801 Consistency The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection is a new one,.time inspection that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.E6, "Electrical Cable Connections Not Subject to 10 CFR 50.49 Environmental Qualification Requirements," with exceptions. Exceptions to NUREG-1801 Program Elements Affected:

• Detection of Aging Effects-The one-time inspection does not provide for periodic testing (i.e., at least once every 10 years). Because electrical cable connections for many end devices (such as motors, bus connections, and transformers) are inspected (and repaired
• Aging Management Programs Page 8-94 January 2010 Columbia Generating StationLicense Renewal Application Technical Information or remade as necessary) whenever the end device is tested or worked on, and because Columbia has a thermography program that routinely inspects electrical connections throughout the plant (based on current industry practices), a one-time inspection in response to the guidance of NUREG-1801 XI.E6 is adequate.Performance of the inspection will confirm the absence of aging degradation on electrical cable connections.

The technical methodology utilized by the program (thermography augmented by contact resistance tests) is identical to that of NUREG-1801, XI.E6.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The metallic parts of electrical cable connections, not subject to 10 CFR 50.49, and associated with cables that are within the scope of license renewal, are part of this program, regardless of their association with active or passive components. The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection is applicable to non-environmentally qualified electrical cable connections for the site buildings that are within the scope of license renewal.* Preventive Actions No actions are taken as part of this activity to prevent or mitigate aging degradation. Parameters Monitored or Inspected This inspection will focus on the metallic parts of electrical cable connections. The inspection will include detection of loosened bolted connections due to thermal cycling, ohmic heating, electrical transients, vibration, chemical contamination, corrosion, and oxidation. A representative sample of electrical cable connections will be inspected. The following factors will be considered for sampling: application (high, medium, and low voltage), circuit loading, and physical location (high temperature, high humidity, vibration, etc.) with respect to connection stressors. The technical basis for the sample selected will be documented. If an unacceptable condition or situation is identified in the sample, a determination will be made as to whether the same condition or situation is applicable to other connections. Detection of Aging Effects A representative sample of the metallic electrical cable connections not subject to 10 CFR 50.49 EQ requirements and within the scope of license renewal will receive a one-time inspection via thermography (augmented with contact resistance testing)prior to the period of extended operation. Thermography is a proven test method for detecting loose connections and degraded connections (i.e., chemical contamination, corrosion, oxidation) leading to increased resistance, and will be Aging Management Programs Page B-95 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information or' remade as necessary) whenever the end device is tested or worked on, and because Columbia has a thermography program that routinely inspects electrical connections throughout the plant (based on current industry practices), a time inspection in response to the guidance of NUREG-1801 XI.E6 is adequate.

Performance of the inspection will confirm the absence of aging degradation on electrical cable connections. The technical methodology utilized by the program (thermography augmented by contact resistance tests) is identical to that of NUREG-1801, XI.E6. Aging Management Program Elements The results of an evaluation of each program element are provided below.

• Scope of Program The metallic parts of electrical cable connections, not subject to 10 CFR 50.49, and associated with cables that are within the scope of license renewal, are part of this program, regardless of their association with active or passive components.

The Electrical Connections Not Subject to 10 CFR 50.49 EO Requirements Inspection is applicclble to non-environmentally qualified electrical cable connections for the site buildings that are within the scope of license renewal.

• Preventive Actions No actions are taken as part of this activity to prevent or mitigate aging degradation.
• Parameters Monitored or Inspected This inspection will focus on the metallic parts of electrical cable connections

.. The inspection will include detection of loosened bolted connections due to thermal cycling, ohmic heating, electrical transients, vibration, chemical contamination, corrosion, and oxidation. A representative sample of electrical cable connections will be inspected. The following factors will be co)nsidered for sampling: application (high, medium, and low voltage), circuit loading, and physical location (high temperature, high humidity, vibration, etc.) with respect to connection stressors. The technical basis for the sample selected will be documented. If an unacceptable . condition or situation is identified in the sample, a determination will be made as to whether the same condition or situation is applicable to other connections.

• Detection of Aging Effects A representative sample of the metallic electrical cable connections not subject to 10 CFR 50.49 EO requirements and within the scope of license renewal will receive a one-time inspection via thermography (augmented with contact resistance testing) prior to the period of extended operation.

Thermography is a proven test method for detecting loose connections and degraded connections (i.e., chemical contamination, c'orrosion,' oxidation) leading to increased resistance, and will be Aging Management Programs Page B*95 January 2010 Columbia Generating Station License Renewal Application Technical Information used to test a sample of electrical connections at a variety of plant locations. Thermography can detect aging effects due to thermal cycling, ohmic heating, vibration, and electrical transients. Thermography is an effective tool for inspecting connections that are covered by electrical tape, insulating boots or ,covers, heat-shrink material, and sleeving. Contact resistance testing of a sample of motor termination connections and other connections will also be utilized.Monitoring and Trending No actions are taken as part of the Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection to monitor or trend inspection results.This is a one-time inspection activity used to determine if, and to what extent, further actions, including monitoring and trending, may be required.Sample size will be determined by engineering evaluation, as described for the Detection of Aging Effects element above. Results of the inspection activities that require further evaluation and resolution (e.g., if degradation is detected), will be evaluated using the corrective action process, including expansion of the samplesize and inspection locations to determine the extent of the degradation.

• Acceptance Criteria The acceptance criteria for thermography will be based on the current criteria used for the thermography process at Columbia.

The acceptance criteria for the contact resistance tests will be defined in the implementing procedure.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.In addition, for the Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection, an engineering evaluation is performed when the test acceptance criteria are not met in order to ensure that the intended functions of the cable connections can be maintained consistent with the current licensing basis.Such an evaluation will consider the significance of the test results, the operability of the component, the reportability of the event, the extent of the concern, the potential root causes for not meeting the test acceptance criteria, the corrective actions necessary, and the likelihood of recurrence.

When an unacceptable condition or situation is identified, a determination is made as to whether the same condition or situation is applicable to other in-scope cable connections. Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Aging Management Programs Aging Management Programs Page B-g6 January 2010.Page B-96 January 2010" Columbia Generating Station License Renewal Application Technical Information used to test a sample of electrical connections at a variety of plant locations. Thermography can detect aging effects due to thermal cycling, ohmic heating, vibration, and electrical transients. Thermography is an effective tool for inspecting connections that are covered by electrical tape, insulating boots or {covers, shrink material, and sleeving. Contact resistance testing of a sample of motor termination connections and other connections will also be utilized.

• Monitoring and Trending No actions are taken as part of the Electrical Cable Connections Not Subject to 10 CFR 50.49 EO Requirements Inspection to monitor or trend inspection results. This is a one-time inspection activity used to determine if, and to what extent, further actions, including monitoring and trending, may be required.

Sample size will. be determined by engineering evaluation, as described for the Detection of Aging Effects element above. Results of the inspection activities that require further evaluation and resolution (e.g., if degradation is detected), will be evaluated using the corrective action process, including expansion of the sample size and inspection locations to determine the extent of the degradation.

• Acceptance Criteria
• The acceptance criteria for thermography will be based on the current criteria used
• for the thermography process at Columbia.

The acceptance criteria for the contact resistance tests will be defined in the implementing procedure.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. In addition, for the Electrical Cable Connections .Not Subject to 10 CFR 50.49 EO Requirements Inspection, an engineering evaluation is performed when the test acceptance criteria are not met in order to ensure that the intended functions of the cable connections can be maintained consistent with the current licensing basis. Such an evaluation will consider the significance of the test results, the operability of the component, the reportability of the event, the extent of the concern, the potential root causes for not meeting the test acceptance criteria, the corrective actions necessary, and the likelihood of recurrence.

When an unacceptable condition or situation is identified, a determination is' made as to whether the same condition or situation is applicable to other in-scope cable connections.

• Confirmation Process This element is common to Colum_bia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. Aging Management Programs Page 8-96 January 2010
• Columbia Generating Station License Renewal Application Technical Information Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Operating Experience The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection is a new activity for which there is no site-specific operating experience.

Based on review of plant-specific and industry operating experience, the identified aging effects will require inspection to determine the presence (and extent) of any degradation associated with the non-environmentally qualified cable electrical connections. Plant operating experience has shown that the corrective action program hasaddressed issues related to degraded cable connections in recent years. Cable connections have been identified with degraded electrical continuity (i.e., 'increased resistance), primarily as a result of loosened electrical connections or corrosion. For example, corroded electrical connections were identified in the cooling tower lighting panels (which are not within the scope of license renewal), and an abnormally warm connection on a diesel generator power panel was identified via thermography. Industry operating experience will be included in the development of this activity.Required Enhancements Not applicable, this is a new activity.Conclusion The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection will detect and identify aging issues related to the metallic parts of non-environmentally qualified electrical cable connections. The Electrical Cable Connections Not Subject to 10 CFR 50.49 EQ Requirements Inspection will provide reasonable assurance that aging effects will be identified (and addressed) such that the non-environmentally qualified electrical cable connections subject to aging management review will continue to perform their intended function consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-97 January 2010 Aging Management Programs Page B-97 January 2010* * * !

• Administrative Controls Columbia Generating Station License Renewal Application Technical Information This element is common to Columbia programs and activities that are credited with' aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience The Electrical Connections Not Subject to 10 CFR 50.49 EO Requirements Inspection is a new activity for which there is no site-specific operating experience.

Based on review of plant-specific and industry operating experience, the identified aging effects will require inspection to determine the presence (and extent) of any degradation associated with the non-environmentally qualified cable electrical connections. Plant operating experience has shown that the corrective action program has addressed issues related to degraded cable connections in recent years. Cable connections have been identified with degraded electrical continuity (i.e., . increased resistance), primarily as a result of loosened electrical connections or corrosion. For example, corroded electrical connections identified in the cooling tower lighting panels (which are not within the scope of license renewal), and an abnormally warm connection on a diesel generator power panel was identified via thermography. Industry operating experience will be included in the development of this activity . Required Enhancements Not applicable, this is a new activity. Conclusion The Electrical Cable Connections Not Subject to 10 CFR 50.49 EO Requirements Inspection will detect and identify aging issues related to the metallic parts of non-environmentally qualified cable connections. \ The Electrical Cable Connections Not Subject to 10 CFR 50.49 EO Requirements Inspection will provide reasonable assurance that aging effects will be identified (and addressed) such that the non-environmentally qualified electrical cable connections subject to aging management review will continue to perform their intended function consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-97 January 2010 1' . Columbia Generating Station License Renewal Application Technical Information B.2.22 EQ Program Program Description The NRC .has established nuclear station environmental qualification (EQ) requirements in 10 CFR 50, Appendix A, Criterion 4 and 10 CFR 50.49. 10 CFR 50.49 specifically requires that an environmental qualification program be established to demonstrate that electrical components located in harsh plant environments (i.e., those areas of the plant that could be subject to the harsh environmental effects of a loss of coolant accident, high energy line breaks,*or post-LOCA environment) are qualified to perform their safety function in those harsh environments after the effects of aging during service life.10 CFR 50.49 requires that the effects of significant aging mechanisms be addressed as part of environmental qualification. Columbia has established an EQ program for electrical equipment that meets the requirements of 10CFR50.49 for electrical components important to safety.10 CFR 50.49 defines the scope of components to be included, requires the preparation and maintenance of a list of in-scope components, and requires the preparation and maintenance of a qualification file that includes component performance specifications, electrical characteristics, and the environmental conditions to which the components could be subjected. 10 CFR 50.49(e)(5) contains provisions for aging that require, in part, consideration of all significant types of aging degradation that can affect component functional capability. 10 CFR 50.49(e) also requires replacement or refurbishment of components not qualified for the current license term prior to the end of designated life, unless additional life is established through ongoing qualification. 10 CFR 50.49(f) establishes four methods of demonstrating qualification for aging and accident conditions. 10 CFR 50.49(k) and 10 CFR 50.49(l) permit different qualification criteria to apply based on plant and component vintage. Supplemental EQ regulatory guidance for compliance with these different qualification criteria is provided in the Division of Operating Reactor (DOR) Guidelines, NUREG-0588, and Regulatory Guide 1.89 Revision 1. Compliance with 10 CFR 50.49 provides reasonable assurance that the component can perform its intended functions during accident conditions after experiencing the effects of inservice aging.The EQ Program manages component thermal, radiation, and cyclic aging through the use of aging evaluations based on the methods identified in 10 CFR 50.49(f) and NRC Regulatory Guide 1.89 Revision 1. As required by 10 CFR 50.49, components subject to, EQ but not qualified for the entire current license term are to be refurbished, replaced, or have their qualification extended prior to reaching the aging limits established in the evaluation. Aging evaluations for environmentally qualified components that specify a qualification of at least 40 years are identified as TLAAs for license renewal.The EQ 'Program, which implements the requirements of 10 CFR 50.49 (as further defined and clarified by NUREG-0588 and Regulatory Guide 1.89 Revision 1), is an Aging Management Programs Page B-98 January 2010 8.2.22 EQ Program Program Description . Columbia Generating Station License Renewal Application Technical Information The NRC .has established nuclear station environmental qualification (EO) requirements in 10 CFR 50, Appendix A, Criterion 4 and 10 CFR 50.49. 10 CFR 50.49 specifically requires that an environmental qualification program be established to demonstrate that electrical components located in harsh plant environments (i.e., those areas of the plant that could be subject to the harsh environmental effects of a loss of coolant accident, high energy line 'breaks,' or post-LOCA environment) qualified to perform their safety function in those harsh environments after the effects of aging during service' life. 10 CFR 50.49 requires that the effects of significant aging mechanisms be addressed as part of environmental qualification.

• Columbia has established an EO program for electrical equipment that meets the requirements of 10 CFR 50.49' for electrical components important to safety. 10 CFR 50.49 defines the scope of components to be included, requires the preparation and maintenance of a list of in-scope components, and requires the preparation and maintenance of a qualification file that includes component performance specifications, electrical characteristics, and the environmental conditions to which the components could be subjected.

10 CFR 50.'49(e)(5) contains provisions for aging that require, in part, consideration of all significant types of aging degradation that can

• component functional capability..

10 CFR 50.49(e) also requires replacement or refurbishment of components not qualified for the current license term prior to the end of designated life, unless additional life is established through ongoing qualification. 10 CFR 50.49(f) establishes four methods of demonstrating qualification for aging and accident conditions. 10 CFR 50.49(k) and 10 CFR 50.49(1) permit different qualification criteria to apply based on plant and component vintage. Supplemental EO regulatory guidance for compliance with these different qualification' criteria is provided in the Division of Operating Reactor (DOR) Guidelines, NUREG-0588, and Regulatory Guide 1.89 Revision 1. Compliance with 1 0 CFR 50.49 provides reasonable assurance that the component can perform its intended functions during accident conditions after the effects of inservice aging. The EQ Program manages component thermal, radiation, and cyclic aging through the use of aging evaluations based on the methods identified in 10 CFR 50.49(f) and NRC Regulatory Guide 1.89 Revision 1. As required by 10 CFR 50.49, components subject to* EO but not qualified for the entire current license term are to be refurbished, replaced, or have their qualification extended prior to reaching the aging limits established in the evaluation. Aging evaluations for environmentally qualified components that specify a qualification of at least 40 years are identified as TLAAs for license renewal. The EO 'Program, which implements the requirements of 10 CFR 50.49 (as further defined and clarified by NUREG-0588 and Regulatory Guide 1.89 Revision 1), is an Aging Management Programs Page 8-98 January 2010

• Columbia Generating Station License Renewal Application Technical Information aging management program for license renewal. This existing program is used to manage aging of components in the scope of 10 CFR 50.49 during the current license term and is used routinely to adjust (extend or reduce) qualified life via re-analysis and to determine when replacement or refurbishment is required.A 40-year administrative limit was placed on qualified life of components in the EQ Program, even when the original EQ analyses indicated a longer qualified life. Prior to entering the period of extended operation, the actual qualified life will be established for those components that were subject to this administrative limit. This actual qualified life will be based on existing analytical methods and data. For those components that do not show a minimum 60-year life after lifting the administrative limit, the EQ Program will ensure qualified life is not exceeded by directing refurbishment, replacement, or re-analysis to extend the qualification.

Re-analysis of an aging evaluation to extend the qualification of components under 10 CFR 50.49(e) is performed on a routine basis as part of the EQ Program. Re-analysis may be applied to environmentally qualified components whose qualified life is less than that of the renewed operating license term. Importa'nt attributes for the re-analysis of an aging evaluation include analytical methods, data collection and reduction methods, underlying assumptions, acceptance criteria, and corrective actions (if acceptance criteria are not met). A complete discussion of the EQ re-analysis attributes is found in Section 4.4 of the Application. Consistent with NRC guidance provided in Regulatory Issue Summary 2003-09, no additional information is required to address Generic Safety Issue 168, "Environmental Qualification of Electrical Component." NUREG-1801 Consistency The EQ Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section X.E1, "Environmental Qualification (EQ) of Electrical Components." Exceptions to NUREG-1801 None.Required Enhancements None.Operating Experience A formal process for review of industry operating experience is used to identify and transfer lessons learned from industry experience into Columbia processes and Aging Management Programs Page B-99 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information aging management program for license. renewal. This existing program is used to manage aging of components in the scope of 10 CFR 50.49 during the current license term and is used routinely to adjust (extend or reduce) qualified life via re-analysis and to determine when replacement or refurbishment is required.

A 40-year administrative limit was placed on qualified life of components in the EQ Program, even when the original EQ analyses indicated a longer qualified life. Prior to entering the period of extended operation, the actual qualified life will be established for those components that were subject to this administrative limit. This actual qualified life will be based on existing analytical methods and data. For those components that do not show a minimum 60-year life after lifting the administrative limit, the EQ Program will ensure qualified life is not exceeded by directing refurbishment, replacement, or re-* analysis to extend the qualification. Re-analysis of an aging evaluation to extend the qualification of components under 10CFR 50.49(e) is performed on a routine basis as part of the EQ Program. analysis may be applied to environmentally qualified components whose qualified life is . less than that of the remewed operating license term. Important attributes for the analysis of an aging evaluation include analytical methods, data collection and reduction methods, underlying assumptions, acceptance criteria,and corrective actions (if acceptance criteria are not met). A complete discussion of the EQ re-analysis attributes is found in Section 4.4 of the Application. Consistent with NRC guidance provided in Regulatory Issue Summary 2003-09, no additional information is required to address Generic Safety Issue 168, "Environmental Qualification of Electrical Component." NUREG-1801 Consistency The EQ Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section X.E1, "Environmental Qualification (EQ) of Electrical Components." Exceptions to NUREG-1801 None. Required Enhancements None. Operating , . . A formal process for review of industry operating experience is used to identify and transfer lessons learned from industry experience into Columbia processes and Aging Management Programs Page 8-99 January 2010 Columbia Generating StationLicense Renewal Application Technical Information programs, including the EQ Program. Plant-specific operating experience is identified and evaluated primarily through the corrective action program. Evaluation of both industry and plant-specific operating experience includes consideration of the need to modify qualification bases and conclusions, including qualified life. The EQ Program is in compliance with 10 CFR 50.49, thereby providing reasonable assurance that the environmentally qualified components will be able to perform their intended functions even at the end of their qualified life.Selected operating experience that affected the qualified lives of environmentally qualified equipment at Columbia are as follows: " Lead wires on certain normally energized solenoid valves are required to be replaced periodically (from INPO)." Normally energized relays have been assigned an operating life based on plant-specific operating experience.

• The orientation of ASCO and Marotta solenoid valves is controlled to prevent excessive heat rise to the electrical components (INPO).* Replacement of Namco switches on the MSIVs is now based on plant-specific operating experience.
• A Columbia EQ procedure was modified to consider the effect of high float voltages on DC coils (industry EQ group operating experience).

Conclusion The EQ Program is in compliance with the requirements of 10 CFR 50.49 and is successfully being used to manage the aging of equipment in the program during thecurrent license term. The existing EQ Program will be used to manage aging during the period of extended operation and includes provisions to ensure that the qualification bases are maintained and that components do not exceed their qualified lives. The EQ Program provides reasonable assurance that the effects of aging will be adequately managed and that environmentally qualified components will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-1 00 January 2010 Columbia Generating Station License Renewal Application Technical Information programs, including the EO Program. Plant-specific operating experience is identified and evaluated primarily through the corrective action program. Evaluation* of both industry and plant-specific operating experience includes consideration of the need to modify qualification bases and conclusions, including qualified life. The EO Program is in compliance with 10 CFR 50.49, thereby providing reasonable assurance that the environmentally qualified components will be able to perform their intended functions even at the end of their qualified life. Selected operating experience that affected the qualified lives of environmentally qualified equipment at Columbia are as follows:

• Lead wires on certain normally energized solenoid valves are required to be replaced periodically (from INPO).
• Normally energized relays have been assigned an operating life based on specific operating experience.
• The orientation of ASCO and Marotta solenoid valves is controlled to prevent excessive heat rise to the electrical components (INPO).
• Replacement of Namco switches on the MSIVs is now based on plant-specific operating experience.
• A Columbia EO procedure was modified to consider the effect of high float voltages on DC coils (industry EO group operating experience).

Conclusion The EO Program is in compliance with the requirements of 10 CFR 50.49 and is successfully being used to manage the aging of equipment in the program during the current license term. The existing EO Program will be used to manage aging during the period of extended operation and includes provisions to ensure that the qualification bases are maintained and that components do not exceed their qualified lives. The EO Program provides reasonable assurance that the effects of aging will be adequately managed and that environmentally qualified components will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. . Aging Management Programs Page 8-100 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information B.2.23 External Surfaces Monitoring ProgramProgram Description The External Surfaces Monitoring Program will manage the following aging effects for the external surfaces, and in some cases the internal surfaces, of mechanical components within the scope of license renewal:* Loss of material for metals (aluminum, copper alloy, copper alloy > 15% Zn, gray cast iron, stainless steel (including CASS), and steel) that are exposed to condensation, air-indoor uncontrolled, and air-outdoor environments
• Cracking of aluminum and stainless steel exposed to condensation environments
• Hardening and loss of strength for elastomer-based mechanical sealants and flexible connections in HVAC systems The External Surfaces Monitoring Program is a condition monitoring program that consists of visual inspections and surveillance activities of accessible external surfaces on a frequency that generally exceeds once per fuel cycle. Surfaces that are inaccessible during normal plant operation are inspected during refueling outages.Surfaces that are inaccessible or not readily visible during both plant operations and refueling outages, such as surfaces that are insulated, are inspected opportunistically, for example during maintenance activities during which insulation is removed.The External Surfaces Monitoring Program is supplemented by the Aboveground Steel Tanks Inspection to manage loss of material for the inaccessible external surfaces of the carbon steel condensate storage tanks (i.e., the tank bottom).NUREG-1801 Consistency The External Surfaces Monitoring Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M36, "External Surfaces Monitoring." Exceptions to NUREG-1801 None.Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program element: Aging Management Programs Page B-101 January 2010*
• B.2.23 External Surfaces Monitoring Program Program Description Columbia Generating Station License Renewal Application Technical Information , The External Surfaces Monitoring Program will manage the following aging effects for the external surfaces, and in some cases the internal surfaces,.

of mechanical components within the scope of license renewal:

• Loss of material for metals (aluminum, copper alloy, copper alloy> 15% ln, gray cast iron, stainless steel (including CASS), and steel) that are exposed to condensation, air-indoor uncontrolled, and air-outdoor environments
• Cracking of aluminum and stainless steel exposed to condensation environments
• Hardening and loss of strength for elastomer-based mechanical sealants and flexible connections in HVAC systems The External Surfaces Monitoring Program is a condition monitoring program that consists of visual inspections and surveillance activities of accessible external surfaces on a frequency that generally exceeds once per fuel cycle. Surfaces that are inaccessible during normal plant operation are inspected during refueling outages. Surfaces that are inaccessible or not readily visible during both plant operations and refueling outages, such as surfaces that are insulated, are inspected opportunistically, for example during maintenance activities during which insulation is removed. The External Surfaces Monitoring Program is supplemented by the Aboveground Steel Tanks Inspection to manage loss of material for the inaccessible external surfaces of the carbon steel condensate storage tanks (i.e., the tank bottom). . NUREG-1801 Consistency The External Surfaces Monitoring Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M36, "External Surfaces Monitoring." Exceptions to NUREG-1801 None. Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program element: . Aging Management Programs Page 8-101 January 2010 Columbia Generating Station License Renewal Application Technical Information
• Scope of Program -* Add aluminum, copper alloy, copper alloy >15% Zn, gray cast iron, stainless steel (including CASS), and elastomers to the scope of the program." Add cracking as an aging effect for aluminum and stainless steel components.
• Add hardening and loss of strength as aging effects for elastomer-based mechanical sealants and flexible connections in HVAC systems." Monitoring and Trending -" Add physical examination techniques in addition to visual inspection to detect hardening and loss of strength for elastomer-based mechanical sealants and flexible connections in HVAC systems.* Add visual (VT-1 or equivalent) or volumetric examination techniques to detect cracking.Operating Experience The elerhents that comprise the External Surfaces Monitoring Program are consistent with industry practice and have proven effective in' maintaining the material condition of Columbia plant systems and components.

A review of the most recent plant-specific operating experience, through a search of condition reports, revealed that minor component leakage (typically at bolted joints and closures), damage (event-driven, not age-related), and degradation are routinely identified by the External Surfaces Monitoring Program, with subsequent corrective actions taken in a timely manner; and that no loss of pressure boundary integrity has occurred that was, or could have been, attributed to the aging effects that are in the scope of the program.Operating experience associated with the External Surfaces Monitoring Program is routinely documented and communicated to site personnel in System Health Reports.System Health Reports are updated after significant changes, or at least quarterly. Aging Management Programs Page B-102 January 2010 Aging Management Programs Page B-102 January 2010 Columbia Generating Station License Renewal Application

• Technical Information
• Scope of Program -* Add. aluminum, copper alloy, copper alloy >15% Zn, gray cast iron, stainless steel (including CASS), and elastomers to the scope of the program.
• Add cracking as an aging effect for aluminum and stainless steel components.
• Add hardening and loss of strength as aging effects for elastomer-based mechanical sealants and flexible connections in HVAC systems.
• Monitoring and l'rending

-* Add physical examination techniques in addition to visual inspection to detect hardening and loss of strength for elastomer-based mechanical sealants and flexible connections in HVAC systems.

• Add visual (VT-1 or equivalent) or volumetric examination techniques to detect cracking.

Operating Experience The elements that comprise the External Surfaces Monitoring Program are consistent with industry practice and have proven effective in'maintaining the material condition of Columbia plant systems and components. A review of the most recent plant-specific operating experience, through a search of condition reports, revealed that minor component leakage (typically at bolted joints and closures), damage (event-driven, not age-related), and degradation are routinely identified by the External Surfaces Monitoring Program, with subsequent corrective actions taken in a timely manner; and that no loss of pressure boundary integrity has occurred that was, or could have been, attributed to the aging effects that are in the scope of the program. Operating experience associated with the External Surfaces Monitoring Program is routinely documented and communicated to site personnel in System Health Reports. System Health Reports are updated after significant or at least quarterly. Aging Management Programs Page 8-102 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information Conclusion The External Surfaces Monitoring Program will detect and manage loss of material for aluminum, copper alloy, copper alloy >15% Zn, gray cast iron, stainless steel (including CASS), and steel components. The continued implementation of the External Surfaces, Monitoring Program, with the required enhancements, provides reasonable assurance that the effects of aging, including cracking for aluminum and stainless steel components and hardening and loss of strength for elastomer-based mechanical sealants and flexible connections in HVAC systems, will be managed such thatcomponents subject to aging management will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation.

Aging Management Programs*.Page B-1 03 January 2010* *

• Conclusion Columbia Generating Station license Renewal Application Technical Information The External Surfaces Monitoring Program will detect and manage loss of material for aluminum, copper alloy, copper alloy >15% Zn, gray cast iron, stainless steel (including CASS), and steel components.

The continued implementation of the External Surfaces. Monitoring Program, with the required enhancements, provides reasonable assurance that the effects of aging, including cracking for aluminum and stainless steel components and hardening and loss of strength for elastomer-based mechanical sealants and flexible connections in HVAC systems, will be managed such that components subject to aging management will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. ( Aging Management Programs Page 8-103 January 2010 / Columbia Generating Station License Renewal Application Technical Information B.2.24 Fatigue Monitoring Program Program Description The Fatigue Monitoring Program manages fatigue of the reactor pressure vessel by tracking thermal cycles as required by Technical Specification 5.5.5, "Component Cyclic or Transient Limit." The Fatigue Monitoring Program also manages fatigue of other components (including the ASME Class 1 reactor coolant pressure boundary, high energy line break locations, and Primary Containment) by tracking transient cycles. The Fatigue Monitoring Program is a combination of time-limited aging analyses (cumulative usage factor calculations) and transient counting procedures. The Fatigue Monitoring Program uses the systematic counting of plant transient cycles to ensure that the numbers of analyzed cycles are not exceeded, thereby ensuring that component fatigue usage limits are not exceeded.The BWR Vessel Internals Program contributes to managing fatigue of the jet pumps by checking the jet pump set screw gaps each outage. If any out of specification-gaps are found, Columbia will calculate the additional fatigue accumulated by the jet pumps due to those gaps.The Fatigue Monitoring Program acceptance criteria are to maintain the number of counted transient cycles below the analyzed number of cycles for each transient. The Columbia program periodically updates the cycle counts. When the accumulated cycles approach the analyzed design cycles, corrective action is required to ensure the analyzed number of cycles is not exceeded. Corrective action may include update of the fatigue usage calculation. Any re-analysis will use an NRC-approved version of the ASME code or NRC-approved alternative (e.g., NRC-approved code case) to determine a valid CUF.Columbia has assessed the impact of the reactor coolant environment on the sample of critical components identified in NUREG/CR-6260. These components were evaluated by applying environmental life correction factors to ASME Code fatigue analyses.Formulae for calculating the environmental life correction factors are contained in NUREG/CR-6583 for carbon and low alloy steels and in NUREG/CR-5704 for austenitic stainless steel. The austenitic stainless steel formulae are also applied to nickel alloys.Columbia will enhance the Fatigue Monitoring Program to include the cycles analyzed for the effects of the reactor coolant environment on fatigue prior to the period of extended operation. The enhancement is explained in detail under Required Enhancements below.NUREG-1801 Consistency The Fatigue Monitoring Program is an existing Columbia program that,, with enhancement, will be consistent with the 10 elements of an effective aging management Aging Management Programs Page B-1 04 January 2010 B.2.24 Fatigue Monitoring Program Program Description Columbia Generating Station License Renewal Application Technical Information The Fatigue Monitoring Program manages fatigue of the reactor pressure vessel by tracking thermal cycles as required by Technical Specification 5.5.5, "Component Cyclic or Transient Limit." The Fatigue Monitoring Program also manages fatigue of other components (including the ASME Class 1 reactor coolant pressure boundary, high energy line break locations, and Primary Containment) by tracking transient cycles. The Fatigue Monitoring Program is a combination of time-limited aging analyses (cumulative usage factor calculations) and transient counting procedures. The Fatigue Monitoring Program uses the systematic counting of plant transient cycles to ensure that the numbers of analyzed cycles are not exceeded, thereby ensuring that component fatigue usage limits are not exceeded. The BWR Vessel Internals Program contributes to managing fatigue of the jet pumps by checking the jet pump set screw gaps each outage. If any out of specification -gaps are found, Columbia will calculate the additional fatigue accumulated by the jet pumps due to those gaps.

• The Fatigue Monitoring Program acceptance criteria are to maintain the number of
• counted transient cycles below the analyzed number of cycles for each transient.

The Columbia program periodically updates the cycle counts. When the accumulated cycles approach the analyzed design cycles, corrective action is required to ensure the analyzed number of cycles is not exceeded. Corrective action may include update of the fatigue usage calculation. Any re-analysis will use an NRC-approved version of the ASME code or NRC-approved alternative (e.g., NRC-approved code case) to determine a valid CUF. Columbia has assessed the impact of the reactor coolant environment on the sample of critical components identified in NUREG/CR-6260. These components were evaluated by applying environmental life correction* factors to ASME Code fatigue analyses. Formulae for calculating the environmental life correction factors are contained in NUREG/CR-6583 for carbon and low alloy steels and in NUREG/CR-5704 for austenitic stainless steel. The austenitic stainless steel formulae are also applied to nickel alloys. Columbia will enhance the Fatigue Monitoring Program to include the cycles analyzed for. the effects of the reactor coolant environment on fatigue prior to the period of extended operation. The enhancement is explained in detail under Required Enhancements below. NUREG-1801 Consistency The Fatigue Monitoring Program is an existing Columbia program that,* with enhancement, will be consistent with the 10 elements of an effective aging management Aging Management Programs. Page 8-104 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information program as described in .NUREG-1801, Section X.M1, "Metal Fatigue of Reactor Coolant Pressure Boundary." Exceptions to NUREG-1801 None.Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program elements: " Preventive Actions, Monitoring and Trending, Acceptance Criteria -Columbia has analyzed the effects of the reactor coolant environment on fatigue for the six locations recommended by NUREG\CR-6260.

These analyses are based on the projected cycles for 60. years of operation (plus some conservatism) rather than the original design cycles in FSAR Table 3.9-1. The Fatigue Monitoring Program will be enhanced to ensure that action will be taken when the lowest number of analyzed cycles is approached.

• Acceptance Criteria -For each location that may exceed a cumulative usage factor (CUF) of 1.0 (due to projected cycles exceeding analyzed, or due to as-yet undiscovered industry issues), the Fatigue. Monitoring Program will implement one or more of the following:

(1) Refine the fatigue analyses to determine valid CUFs less than 1.0.This includes refining the analysis to increase accuracy and. reduce conservatism. Any re-analysis will use an NRC-approved version of the ASME code or NRC-approved alternative (e.g., NRC-approved code case)to determine a valid CUF less than 1.0.(2) Manage the effects of aging due to fatigue at the affected locations by an inspection program that has been reviewed and approved by the NRC (e.g., periodic non-destructive examination of the affected locations at inspection intervals to be determined by a method acceptable to the NRC).Should Columbia select the option to manage the aging effects due. to fatigue, the inspection program will meet the following criteria: (1) the inspection program will.be based on the 10 elements for an effective aging management program, as defined in NRC Branch Position RLSB-1, (2) the aging management program will be submitted for NRC review and approval Aging Management Programs Page B-1 05 January 2010* *

• Columbia Generating Station License Renewal Application Technical.1 nformation program as described in. NUREG-1801, Section X.M1, "Metal Fatigue of Reactor Coolant Pressure Boundary." r Exceptions to NUREG**1801 None. Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program elements:
• Preventive Actions, Monitoring and Trending, Acceptance Criteria -Columbia has analyzed the effects of the reactor coolant environment on fatigue for the six locations recommended by NUREG\CR-6260.

These analyses are . , based on the . prOjected cycles for 60. years of operation (plus some conservatism) rather than the original design cycles in FSAR Table 3.9-1. The Fatigue Monitoring Program will be enhanced to ensure that action will be taken when the lowest number of analyzed cycles is approached .

• Acceptance Crifteria

-For each location that may exceed a cumulative usage factor (CUF) of 1.0 (due to projected cycles exceeding analyzed, or due to as-yet undiscovered industry issues), the Fatigue Monitoring Program will implement one or more of the following: (1) Refine the fatigue analyses to determine valid CUFs less than 1.0. This includes refining the analysis to increase accuracy and reduce conservatism. Any re-analysis will use an NRC-approved version of the ASME or NRC-approved alternative (e.g., NRC-approved code case) to determine a valid CUF less than 1.0. (2) Manage the effects of aging due to fatigue at the affected locations by an inspection program that has been reviewed and approved by the NRC (e.g., periodic non-destructive examination of the affected locations at inspection intervals to be determined by a method acceptable to the NRC). Should Columbia select the option to manage the aging effects due to fatigue, the inspection program will meet the following criteria: (1) the inspection program will. be based on the 10 elements for an effective aging management program, as defined in NRC Branch Position RLSB-1, (2) the aging management program will be su.bmitted for NRC review and approval Aging Management Programs Page 8-105 January 2010 Columbia Generating Station License Renewal Application Technical Information at least two years prior to entering the period of extended operation, and (3)the method of inspection will be based on a qualified volumetric examination technique. (3) Repair or replace the affected locations before exceeding a CUF of 1.0.By implementation of one or more of these options, Columbia will manage theaging effect of fatigue for the period of extended operation, with consideration of the effects of the reactor coolant environment on fatigue.Scope-Correlate information relative to fatigue monitoring and provide more definitive verification that the transients monitored and their limits are consistent with or bound the FSAR and the supporting fatigue analyses, including the environmentally-assisted fatigue analyses.Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Industry Experience: NRC document RIS 2008-30 dealt with the use of single dimension stress factors in on-line fatigue analyses. Columbia reviewed RIS 2008-30 and determined that no changes were required to the Columbia Fatigue Monitoring Program. Columbia has no on-line fatigue analyses. Columbia's fatigue analyses of record evaluated multi-dimensional stresses and analyzed the dimensions appropriate to each component. Columbia operating experience: The three most recent counting of cycles show the systematic implementation of the Fatigue Monitoring Program.In August 2000, Columbia operated for a period of time with the recirculation pumps in an unbalanced mode (pump speeds different by more than 50%). The effect of that flow on the fatigue usage of the jet pumps was evaluated. Jet pump clamps were installed on all 20 jet pumps during refueling outage R-17 (2005). Each jet pump mixer was clamped to its diffuser to minimize flow induced vibration caused by leakage at the mixer to diffuser, slip joint interface. As long as the set screw gaps remain within their revised criteria no additional fatigue due to bypass leakage flow induced vibration is accumulated. Columbia reviewed the latest gap status after the 2007 outage and extended the usage factor to 60 years. The Columbia Fatigue Monitoring Program will continue to monitor both the occurrence of design cycles Aging Management Programs Page B-1 06 January 2010 Columbia Generating Station License Renewal Application Techl')ical Information at least two years prior to entering the period of extended operation, and (3) the method of inspection will be based on a qualified volumetric examination technique. (3) Repair or replace the affected locations before exceeding a CUF of 1.0. By implementation of one or more of these options, Columbia will manage the aging effect of fatigue for the period of extended operation, with consideration of the effects of the reactor coolant environment on fatigue. ' , *. Scope-Correlate information relative to fatigue monitoring and provide more definitive verification that the transients monitored and their limits are consistent with or bound the FSAR and the supporting fatigue analyses, including the environmentally-assisted fatigue analyses. Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Industry Experience: NRC docume*nt RIS 2008-30 dealt with the use of single dimension stress factors in on-line fatigue analyses. Columbia reviewed RIS 2008-30 and determined that no changes were required to the Columbia Fatigue Monitoring Program. Columbia has no on-line fatigue analyses. Columbia's fatigue analyses of record evaluated dimensional stresses and. analyzed the dimensions appropriate to eaqh component. Columbia operating experience: The three most recent counting of cycles show the systematic implementation of the Fatigue Monitoring Program. In August 2000, Columbia operated for a period of time with the recirculation pumps in an unbalanced mode (pump speeds different by more than 50%). The effect of that flow on the fatigue usage of the jet pumps was evaluated. Jet pump clamps were installed on all 20 jet pumps during refueling outage R-17 (2005). Each jet pump mixer was clamped to its diffuser to minimize flow induced vibration caused by leakage at the mixer to diffuser. slip joint interface. As long as the set screw gaps remain within their revised criteria no additional fatigue due to bypass leakage flow induced vibration is accumulated. Columbia reviewed the latest gap status after the 2007 outage and extended the usage factor to 60 years. The Columbia Fatigue Monitoring Program will continue to monitor both the occurrence of design cycles . Aging Management Programs Page 8-106 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Informationand the jet pump gaps, effectively managing the fatigue of the jet pumps through the period of extended operation.

Review of the Fatigue Monitoring Program for license renewal identified improvements for the verification that the Columbia cycle counting program included all the fatigue transients identified in the FSAR and fatigue analyses of. record, including the environmentally-assisted fatigue analyses. A review of the program and enhancement of the documentation of that correlation were initiated as part of the License Renewal Project. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects.Conclusion The Fatigue Monitoring Program is in compliance with the requirements of ASME Section II1. The Fatigue Monitoring Program will maintain the validity of the fatigue design basis for reactor coolant system components designed to withstand the effectsof cyclic loads due to reactor coolant system transients. The Fatigue Monitoring Program will be used to manage aging during the period of extended operation and includes provisions to ensure that the analyzed transients are not exceeded. The Fatigue Monitoring Program provides reasonable assurance that the effects of aging will be .adequately managed and that components will continue to perform their intended functions for the period of extended operation. Aging Management Programs Page 8-107 January 2010 Aging Management Programs Page B-1 07 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information I . and the jet pump gaps, effectively managing the fatigue of the jet pumps through the period of extended operation.

Review of the Fatigue Monitoring Program for license renewal identified improvements for verification that the Columbia cycle counting program included all the fatigue transients identified in the FSAR and fatigue analyses of record, including the environmentally-assisted fatigue analyses. A review of the program and enhancement of the documentation of that correlation were initiated .as part of the License Renewal Project. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects. Conclusion The Fatigue Monitoring Program is in compliance with the requirements of ASME Section III. The Fatigue Monitoring Program will maintain the validity of the fatigue design basis for reactor coolant system components designed to withstand the effects of cyclic loads due to reactor. coolant system transients. The Fatigue Monitoring Program will be used to manage aging during the period of extended operation and includes provisions to ensure that the analyzed transients are not exceeded. The Fatigue Monitoring provides reasonable assurance that the effects of aging,will be adequately managE!d and that components will continue to perform their intended functions for the period of extended operation . Aging Management Programs Page 8-107 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.25 Fire Protection Program Program Description The Fire Protection Program is an existing program that is described in the Fire Protection Evaluation, Appendix F (Section F.5) of the FSAR, and which is credited with managing loss of material, cracking, delamination, separation, and change in material properties for susceptible components in the scope of license renewal that have a fire barrier function. Periodic visual inspections and functional tests are performed of fire dampers, fire barrier walls, ceilings and floors, fire-rated penetration seals, fire wraps, fire proofing, and fire doors to ensure that functionality and operability are maintained. In addition, the Fire Protection Program supplements the Fuel Oil Chemistry Program and External Surfaces Monitoring Program through performance monitoring of the diesel-driven fire pump fuel oil supply components and testing and inspection of the halon suppression system, respectively. The Fire Protection Program is a condition monitoring program, comprised of tests and inspections in accordance with National Fire Protection Association (NFPA) recommendations. NUREG-1801 Consistency The Fire Protection Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M26, "Fire Protection," with exceptions. Exceptions to NUREG-1801 Program Elements Affected:* Scope -A low pressure carbon dioxide (suppression) system automatically provides fire protection for the turbine generator exciter housing, as described in FSAR Section F.2.4.5. However, neither the turbine generator exciter nor the associated carbon dioxide suppression system is in the scope of license renewal.As such, aging management of the carbon dioxide suppression system is not required and the associated facets of the site Fire Protection Program are not credited for license renewal." Parameters Monitored or Inspected, Detection of Aging Effects -Functional tests and inspections of the halon suppression system that are included in the Fire Protection Program are performed at an interval greater than biannually, which has been demonstrated to be adequate, based on the absence of any related problems as reported through the corrective action program.Aging Management Programs Page 8-108 January 2010 Aging Management Programs Page B-1 08 January 2010 B.2.25 Fire Protection Program Program Description Columbia Generating Station License Renewal Application Technical Information The Fire Protection Program is an existing program that is described in the Fire Protection Evaluation, Appendix F (Section F.5) of the FSAR, and which is credited with managing loss of material, cracking, delamination, separation, and change in material properties for susceptible components in the scope of license renewal that have a fire barrier function. Periodic visual inspections and functional tests are performed of fire . dampers, barrier walls, ceilings and floors, fire-rated penetration seals, fire wraps, fire proofing, and fire doors to ensure that functionality and operability are maintained. In addition, the Fire Protection Program supplements the Fuel Oil Chemistry Program and External Surfaces Monitoring Program through performance monitoring of the diesel-driven fire pump fuel oil supply components and testing and inspection of the halon suppression system, respectively. The Fire Protection Program is a condition monitoring program, comprised of tests and inspections in accordance with National Fire Protection Association (NFPA) recommendations. NUREG-1801 Consistency

• The Fire Protection Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as' described in NUREG-1801,
• Section XI.M26, "Fire Protection," with exceptions.

Exceptions to NUREG-1801 Program Elements Affected:

• Scope-A low pressure carbon dioxide (suppression) system automatically provides fire protection for the turbine generator exciter. housing, as described in ,FSAR Section F.2.4.5. However, neither the turbine generator exciter nor the associated carbon dioxide suppression system is in the scope of license renewal. As such, aging management of the carbon dioxide suppression system is not required and the associated facets of the site Fire Protection Program are not credited for license renewal.
• Parameters Monitored or Inspected, Detection of Aging Effects-Functional tests and inspections of the halon suppression system that are included in, the Fire Protection Program are performed at an interval greater than biannually, which has been demonstrated to be adequate, based on the absence of any related problems as reported through the corrective action program. Aging Management Programs Page 8-108 January 2010
• Columbia Generating StationLicense Renewal Application Technical Information Scope, Acceptance Criteria -The Fire Protection Program does not include specific confirmation of "no degradation in the fuel oil supply line for the diesel-driven fire pump." Rather, degradation noted for fuel oil supply components during periodic performance testing of the diesel-driven fire pumps through the Fire Protection Program, if any, is evaluated prior to loss of intended function.

In addition, the Chemistry Program Effectiveness Inspection characterizes the internal surface condition of the fuel oil supply line (tubing) for confirmation of the effectiveness of the Fuel Oil Chemistry Program.Required Enhancements None.Operating Experience A review of fire barrier, essential fire-rated penetration seal, fire wrap, fireproofing, fire door, diesel-driven fire pumps, and. halon suppression system inspections previously conducted at Columbia confirms the reasonableness and acceptability of the inspections and their frequency in that degradation of the subject components, although unrelated to aging, was detected prior to loss of function. These inspections have not found any age-related problems.The NRC presently conducts triennial fire protection team inspections at the Columbia site to assess whether an adequate fire protection program has been implemented andmaintained. The most recent of these inspections was conducted'in March of 2006 and is documented in Inspection Report 2006-008 for Docket 50-397. This inspection identified one non-significant, non-cited violation (related to electrical circuit vulnerabilities and deferred to allow industry evaluation of the issue), one finding of very low safety significance (related to multiple "hot" shorts in Reactor Protection System circuitry), and one unresolved item that was not related to the portions of the program credited for aging management. The inspection team verified that fire protection-related issues are entered into the corrective action program at an appropriate threshold forevaluation. The inspection team also reviewed the program for implementing compensatory measures in place for out-of-service, degraded, or inoperable fire protection, with no findings identified. The inspection provided verification that manualand automatic detection systems were installed, tested, and maintained in accordance with the NFPA code of record. The inspection team evaluated the adequacy of fire area barriers, penetration seals, fire doors, fire wraps, and fire-rated electrical cables. The team observed the material condition and configuration of the installed barriers, seals, doors, and cables.In addition, the team reviewed licensee documentation, such as NRC safety evaluation reports, and deviations from NRC regulations and the NFPA codes to verify that fire Aging Management Programs Page B-1 09 January 20.10* * * /. Columbia Generating Station License Renewal Application Technical Information

• Scope, Acceptance Criteria-The Fire Protection Program does not include specific ,confirmation of "no degradation in the fuel oil supply line for the diesel-driven fire pump." Rather, degradation note,d for fuel oil supply componerts' during periodic performance testing of the diE:lsel-driven fire pumps through the Fire Protection Program, if any, is evaluated prior to loss of intended function.

In addition, the Chemistry Program Effectiveness Inspection characterizes the internal surface condition of the fuel oil supply line (tubing) for confirmation of the effectiveness of the Fuel Oil Chemistry Program. Required Enhancements None. Operating Experience A review otfire essential fire-rated penetration seal, fire wrap, fireproofing, fire door, diesel-driven fire pumps, and. halon suppression system inspections previously conducted at Columbia confirms the reasonableness and acceptability of the inspections and their frE:lquency in that degradation of the subject components, although unrelated to aging, was detected prior to loss of function. These inspections have not found any age-related problems. The NRC presently conducts triennial fire protection team inspections at the Columbia site to assess whether an adequate fire protection program has been implemented and maintained. The most recent of these inspections was conducted)in March of 2006 and is documented in Inspection Report 2006-008 for Docket 50-397. This inspection identified one non-sig!1ificant, non-cited violation (related to electrical circuit vulnerabilities and deferred to allow industry evaluation of the issue), one finding of very low safety significance (related to multiple "hot" shorts in Reactor Protection System circuitry), and one unresolved item that was not related to the portions of the program credited for aging management. The inspection team verified that fire protection-related. issues are entered into the corrective action program at an appropriate threshold for evaluation. The inspection team also reviewed the progr,am for implementing compensatory measures in place for* out-of-service, degraded, or inoperable fire protection, with no findings identified. The inspection provided verification that manual and automatic detection systems were installed, tested, and maintained in accordance with the NFPA code of record. The inspection team evaluated the adequacy of fire area barriers, penetration sei;ils, fire doors, fire wraps, and fire-rated electrical cables. The' team observed the material condition and configuration of the installed barriers, seals, doors, and cables. In addition, the team reviewed licensee documentation, such as NRC safety evaluation reports, and deviations from NRC regulations and the NFPA codes to verify that fire Aging Management Programs Page 8-109 January 0 Columbia Generating Station License Renewal Application Technical Information protection features met license commitments. No findings of significance were found.Additionally, a past triennial NRC inspection of the Fire Protection Program, conducted in March-April of 2003 and documented in Inspection Report 50-397/2003-002, identified the same electrical circuit vulnerabilities that were deferred to allow industry evaluation and resolution, and are not related to the portions of the program credited with aging management. Otherwise, the conclusions of the 2003 inspection were similar to the results of the 2006 inspection. No NRC concerns or Columbia management concerns (through periodic audits, self-assessments, and health reports) were identified with respect to inspection, testing, and maintenance of the Fire Protection System.A search was performed of condition reports for the Fire Protection System. When conditions were found that requ~ired correction, they were evaluated in accordance with the corrective action program. Examples include degraded Darmatt fire barriers that were found during periodic surveillance activities and repaired. This review identified minor issues that did not affect the effectiveness of the Fire Protection Program or the aging effects under evaluation. Conclusion The Fire Protection Program will detect and manage loss of material, cracking, delamination, separation, and change in material properties for susceptible components. The Fire Protection Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-hO January2010 Aging Management Programs Page B-1 10 I January 2010 Cblumbia Generating Station License Renewal Application Technical Information protection features met license commitments. No findings of significance were found. Additionally, a past triennial NRC inspection of the Fire Protection Program, conducted in March-April of 2003 and documented in Inspection Report 50-397/2003-002, identified the same electrical circuit vulnerabilities that were deferred to allow industry evaluation and resolution, and are not related to the portions of the program credited with aging management. Otherwise, the conclusions of the 2003 inspection were similar to the results of the 2006 inspection. No NRC concerns or Columbia management concerns (through periodic audits, assessments, and health reports) were identified with respect to inspection, testing, and maintenance of the Fire Protection System. A search was performed of condition reports for the Fire Protection System. When conditions were found that requ,ired correction, they were evaluated in accordance with the corrective action program. Exanwles include degraded Darmatt fire barriers that were found during periodic surveillance activities and repaired. This review identified minor issues that did not affect the effectiveness of the Fire Protection Program or the aging effects under evaluation. Conclusion The Fire Protection Program will detect and manage loss of material, cracking, delamination, separation, and change in material properties for susceptible components. The Fire Protection Program provides reasonable assurance that the aging effects will be maJ1aged such that components subject to aging management review will ,?ontinue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-110 January 2010 ** **

• Columbia Generating Station License Renewal Application Technical Information B.2.26 Fire Water ProgramProgram Description The Fire Water Program (sub-program of the overall Fire Protection Program) is an existing program that is described in the Fire Protection Evaluation, Appendix F (Section F.5) of the FSAR, and which is credited with aging management of the water-based fire suppression components in the scope of license renewal.The Fire Water Program will manage loss of material due to corrosion, erosion, and macrofouling for all susceptible materials in the Fire Protection System, including water supply components, which are exposed to raw water. The program will also manage cracking due to SCC/IGA of copper alloy > 15% Zn components exposed to raw water.The Fire Water Program will manage loss of material due to selective leaching for the copper alloy > 15% Zn spray nozzles that are part of a wet-pipe sprinkler configuration that are exposed to raw water. The Selective Leaching Inspection will manage loss of material due to selective leaching of susceptible components other than the wet-pipespray nozzles.

The Fire Water Program is applicable to a variety of materials, including carbon steel, gray cast iron, copper alloy, copper alloy > 15% Zn and stainless steel, for piping and piping components such as valve bodies, tubing, strainer bodies, standpipes (piping), sprinklers (spray nozzles), pump casings, orifices, and hydrants. Periodic inspection and testing of water-based fire suppression systems provides reasonable assurance that the systems will remain capable of performing their intended function. Periodic inspection and testing activities include hydrant and hose station inspections, flushing, flow tests,. and spray and sprinkler system inspections. The Fire Water Program -is a condition monitoring program, comprised of tests and inspections generally in accordance with NFPA recommendations. Following receipt of the renewed license, and prior to the period of extended operation, the Fire Water Program will.be enhanced to incorporate sprinkler head sampling or replacements, in accordance with NFPA 25, and either ultrasonic testing or internal visual inspection of representative above ground portions of water suppression piping that are exposed to water.NUREG-1801 Consistency The Fire Water Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1 801, Section XI.M27, "Fire Water System." Aging Management Programs Page B-1 11 January 2010*

• B.2.26 Fire Water Program Program Description Columbia Generating Station License Renewal Application . Technical Information The Fire Water Program (sub-program of the overall Fire Protection Program) is an existing program that is described in the Fire Protection Evaluation, Appendix F (Section F.5) of the FSAR, and which is credited with aging management of the based fire suppression components in the scope of license renewal. The Fire Water Program will manage loss of material due to corrosion, erosion, and macrofouling for all susceptible materials in the Fire Protection System, including water supply components, which are exposed to raw water. The program will also manage cracking due to SCCIIGA of copper alloy > 15% Zn components exposed to raw water. The Fire Water Program will manage loss of material due to selective leaching for the copper alloy> 15% Zn spray nozzles that are part of a wet-pipe sprinkler configuration that are exposed to raw water. Selective Leaching Inspection will manage loss of material due to selective leaching of susceptible components other than the wet-pipe spray nozzles. . The Fire Water Program is applicable to a variety of materials, including carbon steel, gray cast iron, copper alloy, copper alloy> 15% Zn and stainless steel, for piping and piping components such as valve bodies, tubing, strainer bodies, standpipes (piping), sprinklers (spray nozzle!s), pump casings, orifices, and hydrants.

Periodic inspection and testing of water-based fire suppression systems provides reasonable assurance that the systems will remain capable of performing their intended function. Periodic inspection and testing activities include hydrant and hose station inspections, flushing, flow tests,. and spray and sprinkler system inspections. The Fire Water Program .is a condition monitoring program, comprised of tests and inspections generally in with NFPArecommendations. Following receipt of the renewed license, and prior to the period of extended operation, the Fire Water Program will. be enhanced to incorporate sprinkler head sampli*ng or replacements, in accordance with NFPA 25, and either ultrasonic testing or internal visual inspection of representative above ground portipns of water suppression piping that are exposed to water. . NUREG-1801 Consistency The Fire Water Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M27, "Fire Water System." Aging Management Programs Page 8-111 January 2010 Columbia Generating Station License Renewal Application Technical Information Exceptions to NUREG-1801 None.Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program element:* Parameters Monitored or Inspected, Detection of Aging Effects -Perform either ultrasonic testing or internal visual inspection of representative portions of above ground fire protection piping that are exposed to water, but do not normally experience flow, after the issuance of the renewed license, but prior to the end of the current operating term and at reasonable intervals thereafter, based on engineering review of the results.

• Detection of Aging Effects -Either replace sprinkler heads that have been -in place for 50 years or submit representative samples to a recognized laboratory for field service testing in accordance with NFPA 25 recommendations.

Perform subsequent replacement or field service testing of representative samples at 10-year intervals thereafter or until there are no sprinkler heads installed that will reach 50 years of service life during the period of extended operation. Acceptance Criteria -Perform hardness testing (or equivalent) of the sprinkler heads as part of their NFPA sampling, to determine whether loss of material due to selective leaching is occurring. Operating Experience Water-suppression portions (subsystems) of the Fire Protection System are inspected, tested, and maintained following NFPA recommendations and at the intervals recommended by the corresponding NFPA standards, or as evaluated and adjusted by Columbia. With one exception (a water hammer event in 1998 that led to a fire protection system valve rupture and subsequent flooding), the water-suppression systems have demonstrated reliable performance with no significant problems in the approximate 20 years since their installation. The water hammer issue (and valve failure) was not age-related. The NRC presently conducts triennial fire protection team inspections at the Columbia site to assess whether an adequate fire protection program has been implemented and Aging Management Programs Page B-1 12 January 2010 Columbia Generating Station License Renewal Application Technical Information Exceptions to NUREG-1801 None. Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program element:

• Parameters Monitored or Inspected, Detection of Aging Effects -Perform either ultrasonic testing or internal visual inspection of representative portions of above ground fire protection piping that are exposed to water, but do not normally experience flow, after the issuance of the renewed license, but prior to the end of the current operating term and at reasonable intervals thereafter, based on engineering review of the results.
• Detection of Aging Effects -Either replace sprinkler heads that have been *in place for 50 years or submit representative samples to a recognized laboratory for field service testing in accordance with NFPA 25 recommendations.

Perform subsequent replacement or field service testing of representative samples at 1 O-year intervals thereafter or until there are no sprinkler heads installed that will reach 50 years of service life during the period of extended operation.

• Acceptance Criteria -Perform hardness testing (or equivalent) of the sprinkler heads as part of their NFPA sampling, to determine whether loss of material due to selective leaching is occurring.

Operating Experience Water-suppression portions (subsystems) of the Fire Protection System are inspected, tested, and maintained following NFPA recommendations and at the intervals recommended by the corresponding NFPA standards, or as evaluated and adjusted by Columbia. With one exception (a water hammer event in 1998 that led to a fire protection system valve rupture and subsequent flooding), the water-suppression systems have demonstrated reliable performance with no significant problems in the approximate 20 years since their installation. The water hammer issue (and valve failure) was not age-related. The NRC presently conducts triennial fire protection team inspections at the Columbia site to assess whether an adequate fire protection program has been implemented and Aging Management Programs Page 8-112 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Informationmaintained. The most recent of these inspections was conducted in March of 2006 and is documented in Inspection Report 2006-008 for 'Docket 50-397. This inspection identified one non-significant, non-cited' violation (related to electrical circuit vulnerabilities and deferred to allow industry evaluation of the issue), one finding of very low safety significance (related to multiple "hot" shorts in Reactor Protection System circuitry), and one unresolved item that were not related to the portions of the program credited for aging management.

The inspection team verified that fire protection-related issues are entered into the corrective action program at an appropriate threshold for evaluation. With respect to fire suppression, the inspection team evaluated the adequacy of fire suppression and detection systems, including observation of the material condition and configuration of the installed fire suppression systems, with no findings identified. The inspection team also reviewed the program for implementing compensatory measures in place for out-of-service, degraded, or inoperable fire protection, with no findings identified. The inspection provided verification that manual and automatic detection systems were installed, tested, and maintained in accordance with the NFPA code of record. Additionally, a past triennial NRC inspection of the Fire Protection Program (including the Fire Water Program), conducted in March-April of 2003 and documented in Inspection Report No. 50-397/2003-002, identified the same electrical circuit vulnerabilities that were deferred to allow industry evaluation and resolution, and are not related to the portions of the program credited with aging management. Otherwise, the conclusions of the 2003 inspection were similar to the results of the 2006 inspection. No NRC concerns or Columbia management concerns (through periodic audits, self-assessments, and heath reports) were identified with respect to inspection, testing, and maintenance of water-suppression portions of the Fire Protection System.A search was performed of condition reports for the Fire Protection System. When conditions were found that required correction, they were evaluated in accordance with the corrective action program. A sampling of data forms for recording the results of thecredited surveillance and test procedures were reviewed for recent monthly, semiannual, annual, and refueling interval inspections, flushes, and flow tests. Data forms for surveillances and tests that have a periodicity of every three years were also reviewed to cover the two most recent surveillances. Any deviations from the acceptance criteria were evaluated and corrected in accordance with the corrective action program. This review identified only minor issues not related to the effectiveness of the Fire Water Program or the aging effects under evaluation. Aging Management Programs Page B-1 13 January 2010 e e* e " Columbia Generating Station License Renewal Application Technical Information maintained. The most recent of these inspections was conducted in March of 2006 and is documented in Inspection Report 2006-008 for 'Docket 50-397. This inspection identified one non-cited, violation (related to electrical circuit vulnerabilities and deferred to allow industry evaluation of the issue), one finding of very low safety significance (related to multiple "hot" shorts in Reactor Protection System circuitry), and one unresolved item that were not'related to the portions of the program for aging management. The inspection team verified that fire protection-related issues are entered (into the corrective action program at.an appropriate threshold for evaluation. With respect to fire suppression, the inspection team evaluated the adequacy of fire suppression and detection systems, including observation of the material condition and configuration of the installed fire suppression systems, with no findings identified. inspection team also reviewed the program for implementing compensatory measures in place for out-of-service, degraded, or inoperable* fire protection, with no findings identified. The inspection provided verification that manual and automatic detection systems were installed, tested, and maintained in accordance with the NFPAcode of record. Additionally, a past triehnial NRC inspection of the Fire Protection Program (including the Fire Water Program), conducted in March-April of 2003 and documented in Inspection Report No. 50-397/2003-002, identified the same electrical circuit vulnerabilities that were deferred to allow industry evaluation and resolution, and are not related to the portions of the program credited with aging management. Otherwise, the conclusions of the 2003 inspection were similar to the results of the 2006 inspection. No NRC concerns or Columbia management concerns (through periodic audits, assessments, and heath reports) were identified with respect to inspection, testing, and maintenance of water-suppression portions of the Fire Protection System. A search was performed of condition reports for the Fire Protection System. When conditions were found that required correction, they were evaluated in accordance with the corrective action program. A sampling of data forms for recording the results of the credited surveillance and test procedures were reviewed for reGent monthly, semiannual, annual, and refueling interval inspections, flushes, ahd flow tests. Data forms for surveillances and tests that have a periodicity of every three years were also reviewed to cover the two most recent surveillances. Any deviations fr9m the acceptance criteria were evaluated and corrected in accordance with the corrective action program. This review identified only minor issues not related to the effectiveness of the Fire WaterProgram or the aging effects under evaluation. Aging Management Programs Page 8-113 . January 2010 Columbia Generating Station License Renewal Application Technical Information Conclusion The Fire Water Program will detect and manage loss of material, as well as fouling, forsusceptible components. The Fire Water Program, with the required enhancements, provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-i 14 January 2010 Aging Management Programs Page B-1 14 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Conclusion The Fire Water Program Will detect and manage loss of material, as well as fouling, for susceptible components.

The Fire Water Program, with the required enhancements, provides reasonable assurance that the aging effects will be managed such that -components subject to aging management review will continue to perform their intended* functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-114 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information B.2.27 Flexible Connection Inspection Program Description The Flexible Connection Inspection is a new one-time inspection that will detect and characterize the material condition of elastomer components that are exposed to treated water, dried air, gas, and indoor air environments.

The inspection provides direct evidence as to whether, and to what extent, hardening and loss of strength due to thermal exposure and ionizing radiation has occurred or is likely to occur that couldresult in a loss of intended function of the elastomer components. Implementation of the Flexible Connection Inspection will ensure that the pressure boundary integrity of susceptible components is maintained consistent with the current licensing basis during the period of extended operation. NUREG-1801 Consistency The Flexible Connection Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection," with exceptions. Exceptions to NUREG-1801 Program Elements Affected: Parameters Monitored or Inspected,. Detection of Aging Effects -In addition to visual examination techniques, the Flexible Connection Inspection will include physical examination techniques, such as physical manipulation. and prodding.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program A representative sample of components at susceptible locations will be examined for evidence of hardening and loss of strength (due to thermal exposure and ionizing radiation), or to confirm a lack thereof.The Flexible Connection Inspection focuses on a limited but representative sample population of subject components at susceptible locations to be defined in the implementing documents, to include internal and external surfaces of flexible connections exposed to treated water, dried air, gas, and indoor air environments. The inspections performed will be used to provide symptomatic evidence of Aging Management Programs Page B-1 15 January 2010* 8.2.27 Flexible Connection Inspection Program Description Columbia Generating Station License Renewal Application Technical Information The Flexible Connection Inspection is a new one-time inspection that will detect and characterize the material condition of elastomer components that are exposed to treated water, dried air, gas, and indoor air environments. The inspection provides direct evidence as to whether, and to what extent, hardening and loss of strength due to thermal exposure and ionizing radiation has occurred or is likely to occur that could result in a loss of intended function of the elastomer components. Implementation of the Flexible Connection Inspection will ensure that the pressure boundary integrity of susceptible components is maintained consistent with the current licensing basis during the period of extended operation. NUREG-180f ConsistE!ncy The Flexible Connection Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1B01, Section XI.M32, "One-Time Inspection," with exceptions.

• Exceptions to NUREG-1801 Program Elements Affected:
• Parameters Monitored or Inspected, Detection of Aging Effects :.... In addition to visual examination techniques, the Flexible Connection Inspection will include physical examination techniques, such as physical manipulation and . prodding.

Aging Management Program Elements The results of an evaluation of each program element are provided below . * . Scope of Program A representative sample of components at susceptible locations will be examined for evidence of hardening and loss of strength (due to thermal exposure and ionizing radiation), or to confirm a lack thereof. The Flexible Connection Inspection focuses on a limited but representative sample population of subject components at susceptible locations to be defined in the implementing documents, to include internal and exterr:'al surfaces of flexible connections to treated water, dried air, gas, and indoor air environments. The inspections performed will be used to provide* symptomatic evidence of Aging Management Programs Page 8*115 January 2010 Columbia Generating Station License Renewal Application r Technical Informationhardening and loss of strength at the other susceptible, but possibly inaccessible, locations due to the similarities in materials and environmental conditions.

• Preventive Actions No actions are taken as part of the Flexible Connection Inspection to prevent aging effects or to mitigate aging degradation." Parameters Monitored or Inspected The parameters to be inspected by the Flexible Connection Inspection include visual evidence of surface degradation, such as cracking or discoloration, as well as physical manipulation and prodding, as measures of hardening and loss of strength.Inspections will be performed by qualified personnel using established techniques, such as NDE, consistent with the requirements of 10 CFR 50 Appendix B.* Detection of Aging Effects The Flexible Connection Inspection will use established visual examination techniques (such as equivalent to VT-1 or VT-3), as well as physical manipulation, performed by qualified personnel on a sample population of subject components to identify evidence of hardening and loss of strength.The sample population will be determined by engineering evaluation based on sound statistical sampling methodology, and, where practical, be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and design margins.The Flexible Connection Inspection will be conducted within the 10-year period prior to the period of extended operation.
• Monitoring and Trending This one-time inspection activity is used to characterize conditions and determine if, and to what extent, further actions may be required.

The activity includes provisions for increasing the inspection sample size and location if degradation is detected.The sample size will be determined by engineering evaluation of the materials of construction, the environment (i.e., service conditions), aging effects, and operating experience (e.g., time in-service, most susceptible locations, lowest design margins).Inspection findings that do not meet the acceptance criteria will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and for monitoring and trending of the results.* Acceptance Criteria Indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective Aging Management Programs Page B-1 16 January 2010, r Columbia Generating Station License Renewal Application . Technical Information hardening and loss of strength at the other susceptible, but possibly inaccessible, locations due to the similarities in materials and environmental conditions.

• Preventive Actions No actions are taken as part of the Flexible Connection Inspection to prevent aging effects or to mitigate aging degradation.
• Parameters Monitored or Inspected The parameters to' be inspected by the Flexible Connection Inspection include visual evidence of surface degradation, such as cracking or discoloration, as well as physical manipulation and prodding, as measures of hardening and loss of strength.

Inspections will be performed by qualified personnel using established techniques, such as NDE,consistent with the requirements of 10 CFR 50 Appendix B.

• Detection of Aging Effects The Flexible Connection Inspection will use established visual' examination techniques (such as equivalent to VT-1 or VT-3), as well as physical manipulation, performed by qualified personnel on a sample population of subject components to identify evidence of hardening and loss of strength.
• The sample population will be determined by engineering evaluation based on
• sound statistical sampling methodology, and, where practical, be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and design margins. . The Flexible Connection Inspection will be conducted within the 1 a-year period prior to the period of extended operation.
• Monitoring and Trending This one-time inspection activity is used to characterize conditions and determine if, and to what extent, further actions may be required.

The activity includes provisions for increasing the inspection sample size and location if degradation is detected. The sample size will be determined by engineering evaluation of the materials of construction, the environment (i.e;, service conditions), aging effects, and operating experience (e.g., time in-service, most susceptible locations, lowest design margins) .. Inspection findings that do not meet the acceptance criteria will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and for monitoring and trending of the results.

• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria.

If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective Aging Management Programs Page 8-116 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information action program to determine whether they could result in a loss of component intended function during the period of extended operation.

Corrective Actions This element is common to Columbia programs and activities that are aging management during the period of extended operation and is Section B.1.3.credited with discussed in* Confirmation Process This element is common to Columbia programs and aging management during the period of extended Section B.1.3." Administrative Controls This element is common to Columbia programs and aging management during the period of extended Section B.1.3.activities that are operation and is activities that are operation and is credited with discussed in credited with discussed in' Operating Experience The Flexible Connection Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effect. The activity provides confirmation of conditions where degradation is not expected, has not evidenced as a problem, or where -the aging mechanism is slow acting.NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience to date has identified no issues for the flexible connections in the systems within the scope of this inspection. However, tears have been found in several suction and discharge boots (flexible connections) on air-handling units of the HVAC systems. The tears were attributed to normal operational wear; the boots remained pliable (i.e., no hardening) and no operability issues were identified. These flexible connections are included in the scope of the External Surfaces Monitoring Program.The site corrective action program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for systems within the scope of this activity.Aging Management Programs Page B-1 17 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information action program to determine whether they could result in a loss of component intended function during the period of extended operation.
• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in* Section B.1.3. .
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience The Flexible Connection Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effect. The atCtivity provides confirmation of conditions where degradation is not expected, has not evidenced as a problem, or where the aging mechanism is slow acting. NUREG-1801 is based on industry operating experience through January 2005. Recent industry opelrating experience has been reviewed for applicability; none was identified.

Future operating experience is captured through the normal operating experience review prqcess, which will continue through the period of extended A review of Columbia operating experience to date has identified no issues for the flexible connections in the systems within the scope of this inspection. However, tears have been found in several suction and discharge boots (flexible connections) on air-handling units of the HVAC systems. The tec;lrs were attributed to normal operational wear; the boots remained pliable (Le., no hardening) and no operability issues were identified. These flexible connections are included in the scope of the External Surfaces Monitoring Program. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for systems within the scope of this activity . Aging Management Programs Page 8-117 January 2010 Columbia Generating Station License Renewal Application Technical Information Required Enhancements Not applicable, this is a new activity.Conclusion Implementation of the Flexible Connection Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions of the subject components will be maintained consistent with the current licensing basis during the period of extended operation. 0 S Aging Management Programs Page B-1 18 January2010 Columbia Generating Station License Renewal Application

• Technical Information Required Enhancements Not applicable, this is a new activity.

Conclusion Implementation of the Flexible Connection Inspection will verify that *there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to' ensure that the component intended functions of the subject components will be maintained consistent with the current licensing basis duririg the period of extended operation. Aging Management Programs Page 8-118 January' 2010 *

• lfý'Columbia Generating Station License Renewal Application Technical Information B.2.28 Flow-Accelerated Corrosion (FAC) Program Program Description The Flow-Accelerated Corrosion (FAC) Program will manage loss of material for steel and gray cast iron components located in the treated water environment (including steam, reactor coolant, closed cycle cooling water > 60C (140F), and treated water> 60C (140F)) of systems that are susceptible to flow-accelerated corrosion (FAC), also called erosion-corrosion.

The FAC Program is. a condition monitoring program that ensures the integrity of piping systems susceptible to FAC is maintained. The program was developed in response to NRC Bulletin 87-01, "Thinning of Pipe Walls in Nuclear Power Plants," and NRC GL 89-08, "Erosion/Corrosion Induced Pipe Wall Thinning." The program follows the guidance and recommendations of EPRI NSAC-202L, "Recommendations for an Effective Flow-Accelerated Corrosion. Program," and combines the elements of predictive analysis, inspections (to baseline and monitor wall-thinning), industry experience, station information gathering and communication, and engineering judgment to monitor and predict FAC wear rates.NUREG-1801 Consistency The FAG Program is an existing Columbia program that, with enhancement, will be consistent with the 10, elements of an effective aging management program as described in NUREG-1801, Section XI.M17, "Flow-Accelerated Corrosion." Exceptions to NUREG-1801 None.Required Enhancements Prior to the period of extended operation the enhancements listed below will be, implemented in the identified program element: , Scope -Add the Containment Nitrogen System components supplied with steam from the Auxiliary Steam System to the scope of the program.Add gray cast iron as a material identified as susceptible to FAC.Operating Experience The FAC Program is an ongoing program that has implemented the recommended actions of GL 89-08. The health of the program and corresponding systems are Aging Management Programs Page B-1 19 January2010

• *
• 8.2.28 Flow-Accelell"ated Corrosion (FAC) Program Program Description Columbia Generating Station License Renewal Application Technical Information The Flow-Accelerated Corrosion (FAC) Program will manage loss of material for steel and gray cast iron components located in the treated water environment (including steam, reactor coolant, closed cycle cooling water> 60C (140F), and treated water > 60C (140F)) of systems that are susceptible to flow-accelerated corrosion (FAC), also called erosion-corrosion.

The FAC Program a condition monitoring program that ensures the integrity of piping systems susceptible to FAC is maintainE;!d. The program was developed in response to NRC Bulletin 87-01, "Thinning of Pipe Walls in Nuclear Power Plants," and NRC GL 89-08, "Erosion/Corrosion Induced Pipe Wall Thinning." The program follows the guidance and recommendations of EPRI NSAC-202L, "Recommendations for an Effective Flow-Accele'rated Corrosion. Program," and combines the elements of predictive analysis, inspections (to* baseline and monitor wall-thinning), industry experience, station information gathering and communication, and engineering judgmentto monitor and predict FAC wear rates. ' NUREG-1801 Consisb:mcy The FAC Program is an existing Columbia program that, with enhancement, will be consistent with the 10, elements of an effectiv'e aging management program as described in NUREG-1801, Section XI.M17, "Flow-Accelerated Corrosion." Exceptions to NUREG-1801 None. Required Enhancements Prior to the period o'f extended operation the enhancements listed below will be \ ' implemented in the identified program element:

• Scope-Add the Containment Nitrogen System components supplied with steam from the Auxiliary Steam System to the scope of the program. Add gray cast iron as a material identified as susceptible to FAC. Operating ExperienCE!

The FAC Program is an ongoing prograrl) that has implemented the recommended actions of GL 89-08. The health of the program and corresponding systems are Aging Management Programs PageB-119 January 2010 Columbia Generating Station License Renewal Application Technical Information periodically reported, including material conditions. Industry operating experience has been, and continues to be, evaluated for impact to Columbia and for possible program enhancement. For example, based on review of INPO operating experience 14865, the program was enhanced to require evaluation of replacements for future inspection. Periodic self assessments are also conducted. Gaps identified during the most recent self assessment have all been closed; and the FAC program plan was recently updated, with the current revision addressing all issues identified by the self assessment. In the last benchmark assessment, performed in March 2007, no issues or weaknesses were identified. As a result, Columbia has programs and procedures in place, with operating experience demonstrating that the FAC Program is capable of detecting and managing loss of material due to FAC for susceptible components, and will continue to be an effective aging management program for the period of extended operation. A review of program health reports, recent self-assessment reports, and related condition reports, demonstrates that the FAC Program is effective in detecting loss of material due to FAC for susceptible components, and defining the corrective actions (e.g., repair or replacement) necessary to assure their continued operation in accordance with design requirements. Conclusion The FAC Program will detect and manage loss of material due to FAC for susceptible components. The FAC Program, with the required enhancements, provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-120 January 2010 Columbia Generating Station License Renewal Application

• Technical Information periodically reported, including material conditions

.. Industry operating experience has been, and continues to be, evaluated for impact to Columbia and for possible program enhancement. For example, based on review of INPO operating experience 14865, the program was enhanced to require evaluation of replacements for future inspection. Periodic self assessments are also conducted. Gaps identified during the most recent . self assessment have all been closed; and the FAC program plan was recently updated, with the current revision addressing all issues identified by the self assessment. In the last benchmark assessment, performed in March 2007, no issues or weaknesses were identified. As a result, Columbia has programs and procedures in place, with operating experience demonstrating that the FAC Program is capable of detecting and managing loss of material due to FAC for susceptible components, and will continue to be an effective aging management program for the period of extended operation.* . A review of program health reports, recent self-assessment reports, and related condition reports, demonstrates that the FAC Program is effective in detecting loss of material due to FAC for susceptible components, and defining the corrective actions (e.g., repair or replacement) necessary to assure their continued operation in accordance with design requirements. Conclusion The FAC Program will detect and manage loss of material due to FAC for susceptible. components. The FAC Program, with the required enhancements, provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. ( Aging Management Programs Page 8-120 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information B.2.29 Fuel Oil Chemistry Program Program Description The Fuel Oil Chemistry Program will mitigate the effects of aging for the storage tanks and associated components containing fuel, oil that are within the scope of license renewal by verifying and maintaining the quality of the fuel oil used in the emergency diesel generators and the diesel-driven fire pumps. The program manages the relevant conditions that could lead to the onset and propagation of a loss of material due to corrosion, or cracking due to SCC of susceptible copper alloys, through proper monitoring and control of fuel oil contamination consistent with plant Technical Specifications and American Society for Testing and Materials (ASTM) standards for fuel oil. The relevant conditions are specific contaminants such as water or microbiological organisms in the fuel oil that could lead to corrosion of susceptible materials.

Exposure to these contaminants is minimized by verifying the quality of new fuel oil before it enters the storage tanks and by periodic sampling to ensure the tanks are free of water and particulates. The Fuel Oil Chemistry Program is a mitigation program.The Fuel Oil Chemistry Program is supplemented by the Chemistry Program Effectiveness Inspection, which is a separate one-time inspection of representative areas of the diesel fuel oil system, such as low points where contaminants could accumulate. The one-time inspection provides further confirmation that loss of material, as well as cracking of susceptible copper alloys, is effectively mitigated or to detect and characterize whether, and to what extent, degradation is occurring. NUREG-1801 Consistency The Fuel Oil Chemistry Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M30, "Fuel Oil Chemistry," with exceptions. Exceptions to NUREG-1.801 Program Elements Affected:* Scope -The program does not include sampling or testing of new fuel for the diesel-driven fire pumps. Following the guidelines of ASTM standards, stored fuel is periodically sampled and tested.* Preventive Actlions -Preventive actions do not include the addition of biocides, stabilizers, or corrosion inhibitors to the fuel oil for the emergency diesel generators. The Aging Management Programs Page B-121 January 2010* *

• Fuel Oil Chemistry Program . Program Description Columbia Generating Station License Renewal Application Technical Information The Fuel Oil Chemistry Program will mitigate the effects of aging for the storage tanks and associated components containing fuel; oil that are within the scope of license renewal by verifying and maintaining the quality of the fuel oil used in the emergency diesel generators and the diesel-driven fire pumps. The program manages the relevant conditions that could lead to the onset and propagation of a loss of material due to corrosion, or cracking due to SCC of susceptible copper alloys. through proper monitoring and control of fuel oil contamination consistent with plant Technical Specifications and American Society for Testing and Materials (ASTM) standards for fuel oil. The relevant conditions are specific contaminants such as water or microbiological organisms in the fuel oil that could lead to corrosion of susceptible materials.

Exposure to these contaminants is minimized by verifying the quality of new fuel oil before it enters the storage tanks and by periodic sampling to ensure the tanks are free of water and particulates. The Fuel Oil Chemistry Program is a niitigation program. The Fuel Oil Chemistry Program is supplemented by the Chemistry Program Effectiveness Inspection, which is a separate one-time inspection of representative I areas of the diesel fuel oil system, such as low points where contaminants could accumulate. Theone-time inspection provides further confirmation that loss of material, as well as cracking of susceptible copper alloys, is effectively mitigated or to detect and characterize whether, and to what extent, degradation is occurring. NUREG-1801 Consistlmcy The Fuel Oil Chemistry Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in . . . NUREG-1801, Section XI.M30, "Fuel Oil Chemistry," with exceptions. Exceptions to NUREG-1.801 Program Elements Affected:

• Scope-The program d()es not include sampling or testing of new fuel for the driven fire pumps. Following the guidelines of ASTM standards, stored fuel is periodically sampled and tested.
• Preventive Actiions -Preventive actions do not include the addition of biocides, stabilizers, or corrosion inhibitors to the fuel oil for the emergency diesel generators.

The Aging Management Programs Page 8-121 January 2010 Columbia Generating Station License Renewal Application Technical Information combination of ensuring the specified physical and chemical properties of new fuel oil, and periodic cleaning and draining of the storage tanks mitigates corrosion inside the tanks.* Parameters Monitored and Inspected -The program does not include testing of the fuel oil used for the diesel-driven fire pumps for particulates. Sampling in accordance with ASTM standards D1796 and D4057 has proven adequate, based on the absence of related problems reported through the corrective action program." Detection of Aging Effects -Multi-level sampling of the fuel oil storage tanks is not performed; rather, a representative fuel stream sample is drawn from the flushing line during recirculation and transfer, consistent with ASTM D2276-93, step 4.3, laboratory filtration method.Required Enhancements None.Operating Experience The Fuel Oil Chemistry Program is an ongoing program that effectively incorporates the best practices and industry experience in controlling contaminant levels in fuel oil to minimize degradation. No instances of fuel oil system component failure due to contamination have been identified at Columbia.With respect to the fuel oil tanks for the emergency diesel generators, review of Columbia operating experience reveals that the Fuel Oil Chemistry Program is adequately preventing a loss of component function of subject components that contain fuel oil. Fuel oil delivered to the site is sampled and analyzed prior to addition to the fuel oil storage tanks for the emergency diesel generators. Stored fuel oil is periodically sampled and, analyzed for both the emergency and fire protection diesel generators. Water is removed from the stored fuel oil and particulates are filtered. In addition, visual and ultrasonic inspection of an emergency diesel generator fuel oil storage tank, as listed in FSAR Section 9.5.4.4.a, revealed acceptable conditions for the tank internal surfaces; that is, only light corrosion in previously identified areas with no material loss or obvious changes to the condition of the tank.The fuel oil tanks for the diesel-driven fire pumps are also periodically sampled and analyzed. Water is removed and particulates are filtered based on condition (e.g., when unacceptable levels during periodic sampling necessitate cleaning of the fuel oil).Review of Columbia operating experience reveals that the Fuel Oil Chemistry Program is adequately preventing a loss of component function of subject components that Aging Management Programs Page B-122 January 2010 I Columbia Generating Station License Renewal Application Technical Information combination of ensuring 'the specified physical and chemical properties of new fuel oil, and periodic .cleaning and draining of the storage tanks mitigates corrosion inside the tanks.

• Parameters Monitored and Inspected

-The program does not include testing of the fuel oil used for the diesel-driven fire pumps for particulates. Sampling in accordance with ASTM standards 01796 and 04057 has proven adequate, based on the absence of related problems reported through the corrective action program.

• Detection of Aging Effects-Multi-level sampling of the fuel oil storage tanks is not performed; rather, a representative fuel stream sample is drawn from the flushing' line during recirculation and transfer, consistent with ASTM 02276-93, step 4.3, laboratory filtration method. Required Enhancements None. Operating Experience The Fuel Oil Chemistry Program is an ongoing program that effectively incorporates the best practices and industry experience in controlling contaminant levels in fuel oil to minimize degradation.

No instances of fuel oil system component failure due to contamination have been identified at Columbia. -With respect to the fuel oil tanks for the emergency diesel generators, review of Columbia operating experience reveals that the Fuel Oil Chemistry Program is adequately preventing a loss of component function of subject components that contain fuel oil. Fuel oil delivered to the site is sampled and analyzed prior to addition to the fuel oil storage tanks for the emergency diesel generators. Stored fuel oil is periodically sampled and analyzed for both the emergency and fire protection diesel generators. Water is removed from the stored fuel oil and particulates are filtered. In addition, visual and ultrasonic inspection of an emergency diesel generator fuel oil storage tank, as listed in FSAR Section 9.5.4.4.a, revealed acceptable conditions for the tank internal surfaces; that is, only light corrosion in previously identified areas with no material loss or obvious changes to the condition of the tank. The fuel oil tanks for the diesel-driven fire pumps are also periodically sampled and arlalyzed. Water is removed and particulates are filtered based on condition (e.g., when unacceptable levels during periodic sampling necessitate cleaning of the fuel oil). Review of Columbia operating experience reveals that the Fuel Oil Chemistry program is adequately preventing a loss of component function of subject components that Aging Management Programs Page 8-122 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information contain fuel oil. Quarterly sampling of the fuel oil tanks for the diesel-driven fire pumps has been effective at identifying unacceptable levels of water and sediment prior to a loss of function.

Higher than expected amounts of water or sediment during periodic sampling has resulted in cleaning of the tanks and filtering of the fuel to restore acceptable conditions. The periodic cleaning and filtering has included the addition of a biocide due to evidence of biofouling. To meet new Environmental Protection Agency requirements, Columbia will be transitioning to Ultra-Low-Sulfur Diesel (ULSD) fuel prior to the period of extended operation. ULSD fuel and its possible adverse impacts on diesel performance are addressed in NRC Information Notice 2006-022. The impact of using ULSD fuel on the Columbia design and licensing basis has been evaluated, including the consideration of related operating experience from the industry, and corrective actions assigned to account for the future transition. Columbia will provide notification of any changes to the Fuel Oil Chemistry Program as a result of the transition to ULSD fuel.Conclusion The Fuel Oil Chemistry Program will manage loss of material and cracking for susceptible components through monitoring and control of contaminants in the fuel oil.The Fuel Oil Chemistry, Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis.for the period of extended operation. Aging Management Programs Page B-1 23 January 2010* *

• Columbia Generating Station License Renewal Application.

Technical Information contain fuel oil. Quarterly sampling of the fuel oil tanks for the diesel-driven fire pumps has been effective at identifying unacceptable levels of water and sediment prior to a loss of function. Higher than expected amounts of water or sediment during periodic* sampling has resulted in cleaning of the tanks and filtering of the fuel to restore acceptable conditions. The periodic cleaning and filtering has included the addition of a biocide due to evidence of biofouling. (> To meet new Environmental Protection Agency requirements, Columbia will be transitioning to Ultra-Low-Sulfur Diesel (ULSD) fuel prior to the period of extended operation. ULSD fuel and its possible adverse impacts on diesel performance are addressed in NRC Information Notice 2006-022. The impact of using ULSD fuel on the Columbia design and licensing basis has been evaluated, including the consideration of related operating experience from the industry, and corrective actions assigned to account for the future transition. Columbia will provide notification of any changes to the Fuel Oil Chemistry Pro£Iram as a result of the transition to ULSD fuel. Conclusion The Fuel Oil Chemistry Program will manage loss of material and cracking for susceptible components through monitoring and control of contaminants in the fuel oil. The Fuel Oil Chemistry Program provides reasonable assurance that the aging effects will be managed* such that components subject to aging management review will continue to perform thE!ir intended functions consistent with the current licensing basis for the period of extended operation . Aging Management Programs Page 8-123 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.30 Heat Exchangers Inspection Program Description The Heat Exchangers Inspection is a new one-time inspection that will detect and characterize the surface conditions with respect to fouling of heat exchangers and coolers that are in the scope of the inspection and exposed to indoor air or to water with the chemistry controlled by the BWR Water Chemistry Program or the Closed Cooling, Water Chemistry Program. The inspection provides direct evidence as to whether, and to what extent, a reduction of heat transfer due to fouling has occurred or is likely to occur on the heat transfer surfaces of heat exchangers and coolers.Implementation of the Heat Exchangers Inspection will provide assurance (and confirmation) that the heat transfer capabilities of heat exchangers and coolers in the scope of the inspection will be maintained consistent with the current licensing basis during the period of extended operation. NUREG-1801 ConsistencyThe Heat Exchangers Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The scope of the Heat Exchangers Inspection includes measures to verify that unacceptable reduction in heat transfer is not occurring for the stainless steel and copper alloy heat transfer surfaces of the following heat exchangers and coolers that are in the scope of license renewal, but are not cooled by raw water:* Diesel Cooling Water (DCW) lube oil coolers and jacket water heat exchangers

• Diesel (Engine) Exhaust (DE) turbocharger aftercooler
• Diesel Lubricating Oil (DLO) lube oil cooler* Fuel Pool Cooling (FPC) heat exchangers
• Reactor Core Isolation Cooling (RCIC) lube oil cooler Aging Management Programs Aging Management Programs Page B-124 January 2010 Page B-124 January 2010. Columbia Generating Station License Renewal Application
• Technical Information B.2.30 Heat Exchangers Inspection Program Description The Heat Exchangers Inspection is a new one-time inspection that will detect and characterize the surface conditions with respect to fouling of heat exchangers and, coolers that are in the scope of the inspection and exposed to indoor air or to water with the chemistry controlled by the BWR Water Chemistry Program or the Closed Cooling' Water Chemistry Program. The inspection provides direct evidence as to whether, and to what extent, a reduction of heat transfer due to fouling has occurred or is likely to occur on the heat transfer surfaces of heat exchangers and coolers. Implementation of the Heat Exchangers ,Inspection will provide assurance (and confirmation) that the heat transfer capabilities of heat exchangers and coolers in the scope of the inspection will be maintained consistent with the current licensing basis during the period of extended operation.

NUREG-1801 Consistency The Heat Exchangers Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection."

• Exceptions to NUREG-1801 None. Aging Management Program Elements The results of an evaluation of each program element are provided below.
• Scope of Program \ The scope of the Heat Exchangers Inspection includes measures to verify that unacceptable reduction in heat transfer is not occurring for the stainless steel and copper alloy heat transfer surfaces of the following heat exchangers and coolers that are in the scope of license renewal, but are not cooled by raw water:
• Diesel Cooling Water (DCW) lube oil coolers and jacket water heat exchangers
• Diesel (Engine) Exhaust (DE) turbocharger aftercooler
• Diesel Lubricating Oil (DLO) lube oil cooler
• Fuel Pool Cooling (FPC) heat exchangers
• Reactor Core Isolation Cooling (RCIC) lube oil cooler Aging Management Programs Page 8-124 January 2010
• Columbia Generating Station License Renewal Application Technical Information o Residual Heat Removal (RHR) heat exchanger* RHR pump seal coolers* Reactor Recirculation (RRC) pump seal coolers.* Radwaste Building Mixed Air (WMA) heat exchangers A representative sample of heat exchanger and cooler surfaces that are exposed to treated water, closed cooling water, and indoor air will be examined for evidence of a reduction in heat transfer capabilities due to fouling, or to confirm a lack thereof, with engineering evaluation of the results.* Preventive Actions No actions are taken as part of the Heat Exchangers Inspection to prevent aging effects or to mitigate aging degradation.
• Parameters Monitored or Inspected The parameters to be inspected by the Heat Exchangers Inspection include visual or volumetric evidence of surface fouling as a measure of reduction in heat transfer capabilities.

Inspections will be performed by qualified personnel using established NDE techniques.

• Detection of Aging Effects The Heat Exchangers Inspection will use visual examination techniques (VT-3 or equivalent) performed by qualified personnel on a sample population of the heat exchangers and coolers within the scope of the inspection to identify evidence of fouling on heat transfer surfaces, or to confirm a lack thereof: The sample population will be determined by engineering evaluation based on sound statistical sampling methodology, and, where practical, will be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and the lowest design margins with respect to heat transfer.The Heat Exchangers Inspection activities will be conducted within the 10-year period prior to the period of extended operation.

Monitoring and Trending This one-time inspection activity is used to characterize conditions and determine if, and to what extent, further actions may be required. The activity includes increasing the inspection sample size and location if degradation is detected.Sample size will be determined by engineering evaluation of the materials of construction, environment (i.e., service conditions), aging effects, and operating experience (e.g., time in-service, most susceptible locations, lowest design margins).Aging Management Programs Page B-125 January 2010* * *

• Residual Heat Removal (RHR) heat exchanger
• RHR pump seal coolers
• Reactor Recirculation (RRC) pump seal coolers. Columbia Generating Station License Renewal Application Technical Information
• Radwaste Building Mixed Air (WMA) heat exchangers

' A representative sample of heat exchanger and cooler surfaces that are exposed to treated water, closed cooling water, and indoor air will be examined for evidence .of a reduction in heat transfer capabilities due to fouling, or to confirm a lack thereof, with engineering evaluation of the results.

• Preventive Actions No actions are taken as part of the Heat Exchangers Inspection to prevent aging effects or to mitigate degradation.
• Parameters or Inspected The parameters to be inspected by the Heat Exchangers Inspection include visual or volumetric evidence of surface fouling as a measure of reduction in heat transfer capabilities.

Inspections will be performed by qualified personnel using established NDE techniques .

• Detection of Aging Effects The Heat Exchangers Inspection will use visual examirnation techniques (VT .. 3 or equivalent) perform l 9d by qualified personnel on a sample population of the heat exchangers and coolers within the scope of the inspection to identify evidence of fouling on heat transfer surfaces, or to confirm a lack thereof: The sample population will be determined by engineering evaluation on sound statistical sampling methodology, and, where practical, will be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and the lowest design margins with respect to heat transfer.

The Heat Exchangers . Inspection activities will be conducted within the 10-year period prior to the period of extended operation.

• Monitoring and Trending This one-time inspe'ction activity is used to characterize conditions and determine if, and to what extent, further actions may be required.

The activity includes increasing the inspection sample size and location if degradation is detected. Sample size will be determined by engineering evaluation of the materials of construction, environment (i.e., service conditions), aging effects, and operating experience (e.g., time in-service, most susceptible locations, lowest design margins) . Aging Management Programs Page 8 .. 125 January 2010 Columbia Generating Station License Renewal Application Technical Information Inspection findings that do not meet the acceptance criteria will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and for monitoring and trending of the results.Acceptance Criteria Indications or relevant conditions of degradation detected during the inspections will be compared to pre-determined acceptance criteria. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they 'could result in a loss of component intended function during the period of extended operation. Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3." Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3." Operating ExperienceThe Heat Exchangers Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effect.NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience to date has identified no issues for the heat exchangers in the systems within the scope of this inspection. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for systems within the scope of this activity.Aging Management Programs Page B-1 26 January 2010 Columbia Generating Station License Renewal Application ." Technical Information Inspection findings that do not meet the acceptance criteria will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and for monitoring and trending of the results.

• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspections will "be compared to pre-determined acceptance criteria.

If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they 'could result in a loss of component intended function during the period of extended operation.

• Corrective Actions This element is common to Columbia programs and that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. ,"
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Administrative Controls
• This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience The Heat Exchangers Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effect. 'NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability; none was, identified.

Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended I operation. A review of Columbia operating experience to date has identified no issues for the' heat exchangers in the systems within the scope of this inspection. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for systems within the scope of this" activity. Aging Management Programs Page 8-126 January 2010

• Columbia Generating Station License Renewal Application Technical Information Required Enhancements Not applicable, this is a new activity.Conclusion Implementation of the Heat Exchangers Inspection will verify that reduction in heat transfer does not require management for the subject components, or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation.

Aging Management Programs Page B-127 January 2010 Aging Management Programs Page B-127 January 2010* *

• Required Enhancements Not applicable, this is a new activity.

Conclusion Columbia Generating Station License Renewal Application Technical Information Implementation of the Heat Exchangers Inspection will verify that reduction in heat transfer does .not require management for the subject components, or will identify corrective actions, possibly including programmatic oversight; to be taken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation . Aging Management Programs Page 8*127 January 2010 r, Columbia Generating Station License Renewal Application Technical Information B.2.31 High-Voltage Porcelain Insulators Aging Management Program Program Description The High-Voltage Porcelain Insulators Aging Management Program will manage the build-up of contamination (hard water residue) deposited on the in-scope high-voltage insulators in the transformer yard by the vapor plume from the Circulating Water System cooling towers. This residue, in conjunction with unfavorable weather conditions (moisture from the plume and freezing temperatures), has caused electrical flashovers on the 500-kV bus pedestal insulators in the transformer yard.The High-Voltage Porcelain Insulators Aging Management Program is a preventive maintenance program consisting of activities to mitigate potential degradation of the insulation function due to hard water deposits.Note: There are no station post insulators in the 230-kV system located in the transformer yard.NUREG-1801 Consistency The High-Voltage Porcelain Insulators Aging Management Program is an existing Columbia program that is plant-specific. There is no corresponding aging management program described in NUREG-1801, therefore, the program elements are compared to the elements listed in Table A.1-1 of NUREG-1800. Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The High-Voltage Porcelain Insulators Aging Management Program is credited for managing the build-up of hard water residue on the in-scope high-voltage insulators (located in the transformer yard) deposited by the vapor plume from the Circulating Water System cooling towers.The High-Voltage Porcelain Insulators Aging Management Program involves the following equipment: The high-voltage station post insulators between the 115-kV backup transformer (E-TR-B) and circuit breaker E-CB-TRB.The 500-kV insulators, which experienced the flashover events in the past, are not within the scope of license renewal.Aging Management Programs Page B-128 January 2010 Columbia Generating Station License Renewal Application . Technical Information 8.2.31 High-Voltage Porcelain Insulators Aging Management Program Program Description The High-Voltage Porcelain Insulators Aging Management Program will manage the build-up of contamination (hard water residue) deposited on the in-scope high-voltage insulators in the transformer yard by the vapor plume from the Circulating Water System cooling towers. This residue, in conjunction with unfavorable weather conditions (moisture from the plume and freezing temperatures), has caused electrical flashovers on the SOO-kV bus pedestal insulators in the transformer yard. The High-Voltage Porcelain Insulators Aging Management Program is a preventive maintenance program consisting of activities to mitigate potential degradation of the insulation function due to hard water deposits. Note: There are no station post insulators in the 230-kV system located in the transformer yard. NUREG-1801 Consistency The High-Voltage Porcelain Insulators Aging Management Program is an existing Columbia program that is plant-specific. There is no corresponding aging management program described in NUREG-1801, therefore, the program elements are compared to the elements listed in Table A.1-1 of NUREG-1800. Aging Management Program Elements The results of an evaluation of each program element are provided below.

• Scope of Program The High-Voltage Porcelain Insulators Aging Management Program is credited for managing the build-up of hard water residue on the in-scope high-voltage insulators (located in the transformer yard) deposited by the vapor plume from the Circulating Water System cooling towers. The High-Voltage Porcelain Insulators Aging Management Program involves the following equipment:
• The high-voltage station post insulators between the 11S-kV backup transformer (E-TR-B) and circuit breaker E-CB-TRB.

The SOO-kV insulators, which experienced the flashover events in the past, are not within the scope of license renewal. Aging Management Programs . Page 8-128 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information" Preventive Actions The actions of the High-Voltage Porcelain Insulators Aging Management Program are a preventive maintenance activity that mitigates (retards) degradation of the insulation function.The High Voltage Porcelain Insulators Aging Management Program provides for either the periodic coating or cleaning of the applicable high-voltage insulators.

Cleaning every two years is performed to prevent the build-up of hard water residue on the insulator surface to a point that could cause an electrical flashover. Coating every 10 years prevents, the harmful effect of a hard water residue build-up on the insulators. Cleaning is not required if the insulator is coated." Parameters Monitored or Inspected The High-Voltage Porcelain Insulators Aging Management Program visually inspects coated insulators every two years for damage. Uncoated insulators are inspected every two years for any unusual conditions." Detection of Aging Effects The High-Voltage Porcelain Insulators Aging Management Program is a preventative maintenance program that does not have any specific steps to detect hard water residue on the insulators leading to flashover. The program assumes that the residue exists and takes steps to limit its effect (via coating) or to remove it (via cleaning). A visual inspection of the insulator is specified to note any excessive degradation -or excessive surface contamination. The in-scope insulators are inspected and cleaned every two years. Cleaning is not required if the insulators are coated. If insulators, are coated, the coating is performed every 10 years.." Monitoring and Trending The High-Voltage Porcelain Insulators Aging Management Program does not include trending actions. The High-Voltage Porcelain Insulators Aging Management Program is a preventive maintenance program that is performed at established intervals to coat or clean the in-scope insulators. If during the inspection of the coating or in preparation for cleaning uncoated high-voltage porcelain insulators, significant or unusual or unexpected hard water residue build-up is noted (i.e., excessive deposits), the inspection results will be evaluated through the corrective action program. The corrective action evaluation may result in analysis or further inspection, and a disposition is generated. This disposition may result in a change in the frequency of inspection." Acceptance Criteria The High-Voltage Porcelain Insulators Aging Management Program is a preventive maintenance activity that is periodically performed on specific in-scope equipment. There are no defined acceptance criteria; hard water deposits are assumed to occurand the activity is designed to limit their impact on the insulators. For the visual Aging Management Programs Page B-129 January 2010* * *

• Preventive Actions Columbia Generating Station License Renewal Application Technical Information The actions of the High-Voltage Porcelain Insulators Aging Management Program are a preventive maintenance activity that mitigates (retards) degradation of the insulation function.

The High Voltage Porcelain Insulators Aging Management Program provides for either the periodic coating or cleaning of the applicable high-voltage insulators. Cleaning every two years is performed to prevent the build-up of hard water residue on the insulator surface to a point that could' cause an electrical flashover. Coating every 10 years prevents, the harmful effect of a hard water residue build-up on the insulators. Cleaning is not required if the insulator is coated.

• Parameters Monitored or Inspected The High-Voltage Porcelain Insulators Aging Management Program visually inspects 'coated insulators every two years for damage. Uncoated insulators are inspected every two years for any unusual conditions.
• Detection of Aging Effects The High-Voltage Porcelain Insulators Aging Management Program is a preventative maintenance program that does not have any specific steps to detect hard water residue on the insulators leading to flashover.

The program assumes that the residue exists and takes steps to limit its effect (via. coating) or to remove it (via cleaning). A visual inspection of the insulator is specified to note any excessive degradation' or exc:essive surface contamihation. The in-scope insulators are inspected and cleaned every two years. Cleaning is not required if the insulators are coated. If insulators. are coated, the coating is performed every 10 years ..

• Monitoring and Trending The High-Voltage Porcelain Insulators Aging Management Program does not include trending actions. The High-Voltage Porcelain Insulators Aging Management Program is a preventive maintenance program that is performed at established, intervals to coat or clean the in-scope insulators.

If during the inspection of the coating or in prepclration for cleaning uncoated high-voltage porcelain insulators, significant or unusual or unexpected hard water residue build-up is noted (Le., excessive deposits), the inspection results will be evaluated through the corrective action program. The corrective action evaluation may result in analysis or further inspection, and a disposition is generated. This disposition may result in a change in the frequency of inspection. . /

• Acceptance Criteria The High-Voltage Porcelain Insulators Aging Management Program is a preventive maintenance activity that is periodically performed on specific in-scope equipment.

There are no defined acceptance criteria; hard water deposits are assumed to occur and the activity is designed to limit their impact on the insulators. For the visual 1 Aging Management Programs Page 8-129 January 2010 . Columbia Generating Station License Renewal Application Technical Information inspection of the insulators, excessive surface contamination that does not wash off (i.e., obvious degradation on the insulator) is unacceptable. Such degradation is not expected to be seen on the porcelain material.

• Corrective Actions This element is common to Columbia programs and activities that are aging management during the period of extended operation and is Section B.1.3.* Confirmation Process This element is common to Columbia programs and activities that are aging management during the period of extended operation and is Section B.1.3." Administrative Controls This element is common to Columbia programs and activities that are aging management during the period of extended operation and is Section B.1.3.credited with discussed in credited with discussed in credited with discussed in Operating Experience The elements that comprise the High-Voltage Porcelain Insulators Aging Management Program are consistent with industry practice and have proven effective in maintaining the high-voltage porcelain insulators free from the adverse effects of hard water residue build-up.A review of the most recent operating experience for the high-voltage porcelain insulator inspections reveals that the inspections are performed in accordance with procedure, the results are documented and retrievable, and if any abnormalities are identified during inspection, corrective actions are taken. A review of plant-specific operating experience for the most recent five-year period,. through a search of condition reports, revealed that no 115-kV or 230-kV output breakers tripped as a result of high currents created when a porcelain insulator in the transformer yard shorted to ground.The incidents which alerted the plant to the hard water deposition on the 500-kV insulators are described in Licensee Event Reports 89-002-00 and 90-031. It is noted that these events 'occurred almost 20 years ago. There is industry operating experience of similar flashover events occurring at plants on the ocean affected by salt spray (Brunswick, Crystal River 3, and Pilgrim), and also plants affected by heavy fog and contamination deposits on high-voltage insulators (River Bend).Required Enhancements None.0 Aging Management Programs Page B-1 30 January 2010 Columbia Generating Station License Renewal Application Technical Information inspection of the insulators, excessive surface contamination that does not wash off (i.e., obvious degradation on the insulator) is unacceptable.

Such degradation is not expected to be seen on the porcelain material.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is in Section B.1.3.
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience
• The elements that comprise the High-Voltage Porcelain Insulators Aging Management Program are consistent with industry practice and have proven
• effective in maintaining the high-voltage porcelain insulators free from the adverse effects of hard water residue build-up.

A review of the most recent operating experience for the high-voltage porcelain insulator inspections reveals that the inspections are performed in accordance with procedure, the results are documented and retrievable, and if any abnormalities are identified during inspection, corrective actions are taken. A review of plant-specific operating experience for the most recent five-year period,. through a search of . condition reports, revealed that no 115-kV or 230-kV output breakers tripped as a result of high currents created when a porcelain insulator in the transformer yard shorted to ground. The incidents which alerted the plant to the hard water deposition on the 500-kV insulators are described in Licensee Event Reports 89-002-00 and 90-031. It is noted that these events 'occurred almost 20 years ago. There is industry operating experience of similar flashover events occurring at plants on the ocean affected by salt spray (Brunswick, Crystal River 3, and Pilgrim), and also plants affected by heavy fog and contamination deposits on high-voltage insulators (River Bend). Required Enhancements None. Aging Management Programs Page 8-130 January 2010

• Columbia Generating Station License Renewal Application Technical Information Conclusion The High-Voltage Porcelain Insulators Aging Management Program will manage the hard water residue build-up on the in-scope high-voltage insulators in the transformer yard. The continued implementation of the High-Voltage Porcelain Insulators Aging Management Program provides reasonable assurance that the effects of aging will be managed such that components subject to aging management will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation.

Aging Management Programs Page B-1 31 January 2010* *

• Conclusion

.. Columbia Generating Station License Renewal Application Technical Information The High-Voltage Porcelain Insulators Aging Management Program will manage the hard water residue build-up on in-scope high-voltage insulators in the transformer yard. The continued implementation of the High-Voltage Porcelain Insulators Aging Management Program provides reasonable assurance that the effects of aging will be managed such that components subject to aging management will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation . Aging Management Programs Page 8-131 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.32 Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements ProgramProgram Description The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will manage the aging of inaccessible medium-voltage electrical cables that are not environmentally qualified and subject to wetting within the scope of license renewal. The program provides for the periodic testing of non-environmentally qualified inaccessible medium-voltage electrical cables, in order to determine if age-related degradation is occurring, and includes a provision for the inspection of associated manholes to identify any collection of water. The program will provide reasonable assurance that the electrical components will continue to perform their intended functions for the period of extended 6peration. Energized medium-voltage cables (defined as 2kV to 35kV) that are exposed to wetting (standing water or condensation) in inaccessible locations are vulnerable to loss of dielectric strength and a degradation mechanism known as water treeing. The formation of water trees (gradients or tracks in the insulation) can lead to electrical failure. An inaccessible location may be a conduit, a cable trench, a duct bank, an underground vault, or a direct-buried installation. The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR50.49 EQ Requirements Program is a new aging management program that will be-implemented prior to the period of extended operation, with the cable testing portion to be performed every 10 years thereafter, and the manhole inspection portion to be performed at least every two years thereafter. NUREG-1801 Consistency The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program is a new Columbia program that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.E3, "Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 Environmental Qualification Requirements". Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Aging Management Programs IPage B-1 32 January 2010 Columbia Generating Station License Renewal Application Technical Information 8.2.32 Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program Program Description The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will manage the aging of inaccessible medium-voltage electrical cables that are not environmentally qualified and subject to wetting within the scope of license renewal. The program provides for the periodic testing of non-environmentally qualified inaccessible medium-voltage electrical cables, in order to determine if related degradation is occurring, and includes a provision for the inspection of associated manholes to identify any collection of water. The program will provide reasonable assurance that the electrical components will continue to perform their intended functions for the period of extended operation. Energized medium-voltage cables (defined as 2kV to 35kV) that are exposed to wetting (standing water or condensation) in inaccessible locations are vulnerable to loss of dielectric strength and a degradation mechanism known as water treeing. The formation of water trees (gradients or tracks in the insulation) can lead to electrical failure. An. location may be a conduit, a cable trench, a duct bank, an underground vault, or a direct-buried installation. The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program is a new aging management program that will be-implemented prior to period of extended operation, with the cable testing portion to be performed every 10 years thereafter, and the manhole inspection portion to be performed at least every two years thereafter . . NUREG-1801 Consistency The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program is a new Columbia program that will be consistent with the 10 elements of an effective aging managetnent program as described in NUREG-1801, Section XI.E3, "Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 Environmental Qualification Requirements". Exceptions to NUREG-1801 None. Aging Management Program Elements The results of an evaluation of each program element are provided below. Aging Management Programs Page 8-132 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Scope of Program The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements' Program involves two parts: first, the actions to inspect the plant manholes (and to drain them, if necessary) on a periodic basis; and second, the development of a testing program to confirm that the conductor insulation on the cables is not degrading.

This program applies to medium-voltage cables within the scope of license renewal that meet the criteria of an inaccessible location, exposure to wetting, and exposure to significant voltage. Significant moisture is defined as periodic exposure to moisture that lasts more than a few days (e.g., cables in standing water). Periodic exposure to moisture that lasts less than a few days (i.e., normal rain and drain) isnot significant. Significant voltage exposure is defined as being subject to system voltage for more than twenty-five percent of the time." Preventive Actions The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR50.49 EQ Requirements Program will include periodic preventive actions to inspect for water collection in electrical manholes, and to remove water (as necessary).

• Parameters Monitored or Inspected The specific type o1 test to be utilized in the Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will be determined prior to the initial test. The implementing documents will specify a proven test (such as power factor, partial discharge, or polarization index, as described in EPRI TR-103834-P1-2) for detecting the deterioration of the insulation system due to wetting(and energization), and will reflect the actual test methodology prior to the initial performance of the cable testing. In addition, the provisions for inspecting and draining (if necessary) the electrical manholes will be described in the implementing documents.
• Detection of Aging Effects The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will provide for the testing of in-scope medium-voltage cables to detect degradation of the conductor insulation.

The program will utilize a proven test for detecting deterioration of the cable insulation due to wetting (andenergization). The program will also conduct inspections of the electrical manholes to detect water collection and to drain the manholes (if necessary). The cable testing will be performed at least once every 10 years, with the first test to occur during the 10-year period prior to the end of the current operating license. The inspections for water collection will be performed based on actual plant operating experience with water accumulation in the manholes. However, the inspection Aging Management Programs Page B-1 33 January 2010* * *

• Scope of Program Columbia Generating Station License Renewal Application Technical Information The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements' Program involves two parts: first, the actions to inspect the plant manholes (and to drain them, if necessary) on a periodic basis; and second, the development of a program to confirm that the conductor insulation on the cables is not degrading.

J This program applies to medium-voltage cables withih the scope of license renewal that meet the criteria of an inaccessible location, exposure to wetting, and exposure to significant voltage. Significant moisture is defined as periodic exposure to moisture that lasts more than a few days (e.g" cables in standing water). Periodic exposure to moisture that lasts less than a few days (i.e., normal rain and drain) is not significant. Significant voltage exposure is defined as being subject to system voltage for more than twenty-five percent of the time.

• Preventive Actions The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will include periodic preventive actions to inspect for water collection in electrical manholes, and to remove water (as necessary).
• Parameters Monitored or Inspected The specific type of test to be utilized in the Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will be determined prior to . the initial test. The implementing documents will specify a proven test (such as power factor, partial discharge, or polarization index, as described in EPRI TR .. 1 03834-P1-2) for detecting the deterioration of the insulation system due to wetting (and energization), and will reflect the actual test methodology prior to the initial performance of the cable testing. In addition, the provisions for inspecting and draining (if necessary) the electrical manholes will be described in the implementing documents.
• Detection of Aging Effects The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will provide for the testing of in-scope medium-voltage cables to detect degradation of the conductor insulation.

The program will utilize a proven test for detecting deterioration of the cable insulation due to wetting (and energization). The program will also conduct inspections of the electrical manholes to detect water collection and to drain the manholes (if necessary). The testing will be performed at. least once every 10 years, with the first test to occur during the 1 O-year period prior to the end of the current operating license. The inspections for water collection will be performed based on actual plant operating experience with water accumulation in the manholes. However, . the inspection Aging Management Programs Page 8-133 January 2010 Columbia Generating Station License Renewal Application Technical Information frequency will be at least once every two years. The first inspections will occur during the 10-year period prior to the end of the current operating license.Monitoring and Trending The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will not include trending actions. If anomalies are found during the testing, they will be addressed at that time under the corrective action program. The results of the manhole inspections will be recorded such that increasing water levels, or the need for more frequent performance of draining, can be identified.

• Acceptance Criteria The acceptance criteria for each test in the Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will be defined by the specific type of test to be performed. The type of test will be determined prior to the initial utilization of the program. The implementing documents will contain specific information on the acceptance criteria for each test.* Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in.Section B. 1.3.In addition, for the Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program, an engineering evaluation is performed when the test acceptance criteria are not met in order to ensure that the intended functions of the electrical cables can be maintained consistent with the current licensing basis.Such an evaluation will consider the significance of the test results, the operability of the component, the reportability of the event, the extent of the concern, the potential root causes for not meeting the test acceptance criteria, the corrective actions required, and the likelihood of recurrence.

When an unacceptable condition or situation is identified, a determination will be made as to whether the same condition or situation is applicable to other inaccessible, in-scope medium-voltage cables." Confirmation Process This element is common to Columbia programs and activities that are credited with.aging management during the period of extended operation and is discussed in Section B.1.3.* Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Aging Management Programs Page B-134 January 2010 Columbia Generating Station License Renewal Application Technical Information frequency will be at least once every two years. The first inspections will occur , during the 1 a-year period prior to the end of the current operating license. '

• Monitoring and Trending The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EO Requirements Program will not include trending actions. If anomalies are found during the testing, they will be addressed at that time under the corrective action program. The results of the manhole inspections will be recorded such that increasing water levels, or the need for more frequent performance of draining, can be identified.
• Acceptance Criteria The acceptance criteria for each test in the Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EO Requirements Program will be defined by the specific type of test to be performed.

The type of test will be determined prior to the initial utilization of the program. The implementing documents will contain specific information on the acceptance criteria for each test.

• Corrective Actions This element is common to Columbia programs and activities that are credited with
• aging management during the period of extended operation and is discussed in
• Section B.1.3. In addition, for the Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EO Requirements Program, an engineering evaluation is performed when the test acceptance criteria are not met in order to ensure that the intended functions of the electrical cables can be maintained consistent with the current licensing basis. Such an evaluation will consider the significance of the test results, the operability of the component, the reportability of the event, the extent of the concern, the potential root causes for not meeting the test acceptance criteria, the corrective actions required, and the likelihood of recurrence.

When an unacceptable condition or situation is identified, a determination will be made as to whether the same condition or situation is applicable to other inaccessible, in-scope medium-voltage cables.

• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. Aging Management Programs Page 8-134 January 2010
• Columbia Generating Station License Renewal Application Technical Information Operating Experience The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program is a new program for which there is no site-specific operating experience.

Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation.Plant operating experience has shown that the corrective action program hasaddressed issues of' cable degradation in recent years. Control cables, instrument cables, and low-voltage power cables have been identified with degraded insulation, primarily as a result of exposure to excessive localized overheating. There have been no failures of cables directly attributed to water treeing. Columbia has not experienced any degradation failures of medium-voltage cables. However, two 480-V power cables have failed due to damage incurred during installation and subsequent moisture intrusion. One medium-voltage cable failed because it exceeded its ampacity rating.Recent inspections of medium-voltage manholes identified two manholes adjacent to the cooling towers with standing water. The source of water has not been determined. This is a current licensing basis issue, and the corrective action program will be used to determine the source, to correct or mitigate the problem, and to determine the future inspection frequency needed based on the cause and the corrective actions taken. A search of plant operating experience identified no other cases of medium-voltage manholes having water intrusion. Industry operating experience will be considered in the development of this program.Required Enhancements Not applicable, this is a new program.Conclusion The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will manage degradation of conductor insulation for inaccessible, non-environmentally qualified medium-voltage cables. The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EQ Requirements Program will provide reasonable assurance that the aging effects will be managed such that the inaccessible, non-environmentally qualified medium-voltage cables subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-1 35 January 2010* * *

• Operating Experience Columbia Generating Station License Renewal Application Technical Information The Inaccessible Medium-Voltage Cables Not Subject t01 0 CFR 5.0.49 EO Requirements Program is a new program for which there is no site-specific.aperatin.g experience.

Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Plant operating experience has shown that the corrective action program has addressed issues of' cable degradation in recent years. Control cables, instrument cables, and low-voltage power cables have been identified with degraded insulation, primarily as a result of exposure to excessive localized overheating. There have been no failures of cables directly attributed to water treeing. Columbia has not experienced any degradation failures of medium-voltage cables. However, two 480-V power cables have failed due to damage incurred' during installation and subsequent moisture intrusion. One medium-voltage cable failed . because it exceeded its Recent inspections of medium-voltage manholes identified two manholes adjacent to the cooling towers with standing water. The source of water has not been determined. This is a current licensing basis issue, and the corrective action program will be used to determine the source, to correct or mitigate the problem, and to determine the future inspection frequency needed based on the cause and the corrective actions taken. A search of plant operating experience identified no other cases of medium-voltage manholes having water intrusion. Industry operating experience will bec(:msidered in the development of this program. Required Enhancemelnts Not applicable, this is a new program. Conclusion The Inaccessible Cables Not Subject to 10 CFR 50.49 EO Requirements Program will manage degradation of conductor insulation. for inaccessible, non-environmentally qualified medium-voltage cables. The Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EO Requirements Program will provide reasonable assurance that the aging effects will be managed such that the inaccessible, non-environmentally qualified medium-voltage cables subject to aging management review will continue to perform their intended functions consistent with current licensing basis for the period of .extended operation . Aging Management Programs Page 8-135 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.33 Inservice Inspection (ISI) Program Program Description The Inservice Inspection (ISI) Program manages cracking due to SCC/IGA and flaw growth of reactor coolant system pressure boundary components made of nickel alloy, stainless steel (including cast austenitic stainless steel), and steel (including steel with stainless steel cladding), including the reactor vessel, a limited number of internals components, and the reactor coolant system pressure boundary. The Inservice Inspection (ISI) Program also manages loss of material due to corrosion for reactor vessel internals components and reduction of fracture toughness due to thermal embrittlement of cast austenitic stainless steel pump casings and valve bodies.The Columbia Inservice Inspection (ISI) Program meets the requirements of ASME Section XI. The Columbia Inservice Inspection (ISI) Program details the requirements for the examination, testing, repair, and replacement of components specified in ASME Section Xl for Class 1, 2, or 3 components. The Columbia Inservice Inspection (ISI)Program complies with the ASME Code requirements, and is therefore consistent with the NUREG-1801 program. The program is described in FSAR Section 5.2.4 and is implemented by various plant procedures. The Columbia program scope has been augmented to include additional requirements, and components, beyond the ASME requirements. Examples include the augmentation of ISI to expanded reactor vessel feedwater nozzle examinations, examinations of high energy line piping systems that penetrate containment, and examinations per Generic Letter 88-01. Such augmentation is consistent with the ISI program description in NUREG-1801, Section XI.M1.The Columbia Inservice Inspection (ISI) Program contains a Risk-Informed Inservice Inspection (RI-ISI) program for Class 1 piping, based on EPRI Topical Report TR-1 12657 Revision B-A, which has been approved by the. NRC staff. The RI-ISI provides alternate inspection requirements for a subset of Class 1 piping welds. The staff's review of the RI-ISI program for the third ISI 10-year interval concluded that the program is an acceptable alternative to the current ISI program based on the American Society of Mechanical Engineers Boiler and Pressure Vessel Code, Section Xl requirements for Class 1, non-socket Category B-J welds. While this varies from the ASME Code, it represents a modernization of the Code that has been accepted by theNRC for use at. many nuclear power plants, including Columbia. Because of the widespread NRC acceptance of Risk-Informed ISI, this is not considered an exceptionto NUREG-1801. Evaluation of flaws in accordance with established site procedures using ASME Code and BWRVIP requirements may result in re-inspection or sample expansion. Aging Management Programs Page B-1 36 January 2010 8.2.33 Inservice Inspection (151) Program Program Description Columbia Generating Station License Renewal Application Technical Information The Inservice Inspection (lSI) Program manages cracking due to SCCIIGA and flaw growth of reactor coolant system pressure boundary components made of nickel alloy, stainless steel (including cast austenitic stainless steel), and steel (including steel with stainless steel cladding), including the reactor vessel, a limited number of* internals components, and the reactor coolant system pressure boundary. The Inservice Inspection (lSI) Program also manages loss of material due to corrosion for reactor vessel internals components and reduction of fracture toughness due to thermal embrittlement of cast austenitic stainless steel pump casings and valve bodies. The Columbia Inservice Inspection (lSI) Program meets the requirements of ASME Section XI. The Columbia In service Inspection (lSI) Program details the requirements for the examination, testing, repair, and replacement of components specified in ASME Section XI for Class 1, 2, or 3 components. The Columbia Inservice Inspection (lSI) Program complies with the ASME Code requirements, and is therefore consistent with the NUREG-1801 program. The program is described in FSAR Section 5.2.4 and is implemented by various plant procedures. The Columbia program scope has been augmented to include additional requirements, and components, beyond the ASME requirements. Examples include the augmentation of lSI to expanded reactor vessel feedwater nozzle examinations, examinations of high energy line piping systems that penetrate containment, and examinations per Generic Letter 88-01. Such augmentation is consistent with the lSI program description in . NUREG-1801, Section XI.M1. The Columbia Inservice Inspection (lSI) Program contains a Risk-Informed Inservice Inspection (RI-ISI) program for Class 1 piping, based on EPRI Topical Report TR-112657 Revision B-A, which has been approved by the NRC staff. The RI-ISI provides alternate inspectio"n requirements for a subset of Class 1 piping welds. The staff's review of the RI-ISI program for the third lSI 10-year interval concluded that the program is an acceptable alternative to the current lSI program based on the American Society of Mechanical Engineers Boiler and Pressure Vessel Code, Section XI requirements for Class 1, non-socket Category B-J welds. While this varies from the ASME Code,it represents a modernization of the Code that has been accepted by the NRC for use at many nuclear power plants, including Columbia. Because of the wiqespread NRC acceptance of Risk-Informed lSI, this is not considered an exception to NUREG-1801. Evaluation of flaws in accordance with established site procedures using ASME Code and BWRVIP requirements may result in re-inspection or sample expansion. Aging Management Programs Page 8-136 January 2010 *

• Columbia Generating Station License Renewal Application Technical Information The Columbia Inservice Inspection (ISI) Program evaluates examination results in accordance with the requirements of Section XI, IWB-3000, Standards for Examination Evaluations.

Acceptance of components for continued service is in accordance with the ASME Code or the BWRVIP program guidance, as applicable. The Columbia program sizes cracks in accordance with the requirements of the ASME Code, Section XI. Additionally, BWRVIP documents, such as BWRVIP-1,4, BWRVIP-59; and BWRVIP-60, are used for crack growth, where appropriate. Inspection results are recorded every operating cycle and provided to the NRC after each refueling outage via the Owner's Reports, prepared by the ISI program coordinator. NUREG-1801 ConsistencyThe Inservice Inspection (ISI) Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M1, "ASME Section XI Inservice Inspection, Subsections IWB, IWC, and IWD." Exceptions to NUREG-1801 None.Required Enhancements None.Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Industry Experience: NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability. Future, operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Review of recent License Renewal Applications shows that other applicants are using standard ISI inspection techniques and finding and repairing indications prior to any loss of intended function.Aging Management Programs Page B-1 37 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information The Columbia Inservice Inspection (lSI) Program evaluates examination results in accordance with the requirements of Section XI, IWB-3000, Standards for Examination Evaluations.

Acceptance of components for continued service is in accordance with the ASME Code or the BWRVIP program guidance, as applicable. . The Colunibia program sizes cracks in accordance with the requirements of the ASME Code, Section XI. Additionally, BWRVIP documents, . such as BWRVIP-1,4, BWRVIP-59; and BWRVIP-60, are used for crack growth, where appropriate. Inspection results are recorded every operating cycle and provided to the NRC after each refueling outage via the Owner's Reports, prepared by the lSI program coordinator. NUREG-1801 ConsistE!ncy The Inservice Inspection (lSI) Program is an existing Columbia program that is consistent with the 1 () elements of an effective aging management program as described in NUREG-'j 801, Section XI.M1, "ASME Section XI Inservice Inspection, Subsections IWB, IWC,and IWO." Exceptions to NUREG-1801 None. Required Enhancements None. Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Industry Experience: NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability. Future, operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Review of recent License Renewal Applications shows that other applicants are using standard lSI inspection techniques and finding and repairing indications prior to any loss of intended function . Aging Management Programs Page 8-137 January 2010 Columbia Generating Station License Renewal Application Technical Information Columbia operating experience: Recent Columbia' operating experience related to inservice inspection is documented in Inservice Inspection Outage Summary Reports. Specific examples of ISI findings are also documented in condition reports. Columbia operating experience is consistent with industry experience; a large number of examinations are being performed, and indications are found and resolved. An occasional repair is being performed prior to loss of intended function. The extensive site-specific operating experience with the ASME Inservice Inspection program provides assurance that the program is effective in managing the effects of aging so that components crediting this program can perform their intended functions consistent with the current licensing basis during the period of extended operation. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program remains effective in managing the identified aging effects.Conclusion The Inservice Inspection (ISI) Program manages cracking for components of the reactor coolant pressure boundary, including the reactor vessel, vessel internals, piping, and valves, manages reduction of fracture toughness of cast austenitic stainless steel pump casings and valve bodies, and manages loss of material for components of the vessel internals. The Inservice Inspection (ISI) Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management.Programs Page B-138 January 2010 Aging Management. Programs Page B-1 38 January 2010 Columbia operating experience: Columbia Generating Station License Renewal Application Technical Information Recent Columbia' operating experience related to inservice inspection is documented in Inservice Inspection Outage Summary Reports. Specific examples of lSI findings are also documented in condition reports. Columbia operating experience is consistent with industry experience; a large number of examinations are being performed, and indications are found and resolved. An occasional repair is being performed prior to loss of intended function. The extensive site-specific operating experience with the ASME Inservice Inspection program provides assurance that the program is effective in managing the effects of aging so that components crediting this program can perform their intended functions consistent with the current licensing basis during the period of extended operation. . The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program remains effective in managing the identified aging effects. Conclusion

• The Inservice Inspection (lSI) Program manages cracking for components of the reactor coolant pressure boundary, including the reactor vessel, vessel internals, piping, and valves, manages reduction of fracture toughness of cast austenitic stainless steel pump
• casings and valve bodies, and manages loss of material for components of the vessel internals.

The Inservice Inspection (lSI) Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to p.erform their intended functions consistent with the current licensing basis for the period of extended operation.

• Aging ManagementPrograms Page 8-138 January 2010 Columbia Generating StationLicense Renewal Application Technical .Information B.2.34 Inservice Inspection (ISI) Program -IWE Program Description The Inservice Inspection (ISI) Program -IWE establishes responsibilities and requirements for conducting IWE inspections as required by 10 CFR 50.55a. The ISI Program -IWE includes visual examination of all accessible surface areas of the steel containment and its integral attachments and containment pressure-retaining bolting in accordance with the requirements of the ASME Code, Section Xl, 2001 Edition through 2003 Addenda for Subsection IWE.The in-service examinations conducted throughout the service life of Columbia will comply with the requirements of the ASME Code Section Xl Edition and Addenda incorporated by reference in 10 CFR 50.55a(b) 12 months prior to the start of the inspection interval, subject to prior approval of the edition and addenda by the NRC.This is consistent with NRC statements of consideration associated with the adoption of new editions and addenda of the ASME Code in 10 CFR 50.55a.TheISI Program -IWE provides reasonable assurance that the effects of aging are adequately managed to assure that the Primary Containment intended function is performed consistent with the current licensing basis for the period of extended operation.

NUREG-1801 Consistency The ISI Program -IWE is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.S1, "ASME Section Xl, Subsection IWE".The ISI Program -IWE is performed under the Columbia Inservice Inspection (ISI)program. The ISI program is implemented largely to meet the rules and requirements of the ASME Section Xl Code. The NUREG-1801 XI.S1 aging management program evaluation has specifically included the Code year (e.g., 2001 edition including the 2002and 2003 Addenda), as endorsed by the NRC in 10 CFR 50.55a.Exceptions to NUREG-1801 None.Required Enhancements None.Aging Management Programs Aging Management Programs Page B-139 January 2010 Page B-1 39 January 2010* *

• 8.2.34 Inservice Inspection (151) Program -IWE ,Program Description Columbia Generating Station License Renewal Application Technical Information The Inservice Inspection (lSI) Program -IWE establishes responsibilities and requiremeots for conducting IWE inspections as required by 10 CFR 50.55a. The lSI, Program -IWE includes visual examination of all accessible surface areas of the steel containment and its integral attachments and containment pressure-retaining bolting in accordance with the requirements of the ASME Cqde, Section XI, 2001 Edition through 2003 Addenda for Subsection IWE. The in-service examinations conducted throughout the service life of Columbia will comply with the requirements of the ASME Code Section XI Edition and Addenda incorporated by reference in 10 CFR 50.55a(b) 12 months prior to the start of the inspection interval, subject to prior approval of the edition and addenda by the NRC. This is consistent with NRC statements of consideration associated with adoption of new editions and addenda of the ASME Code in 10 CFR 50.55a. The .ISI Program -IWE provides reasonable assurance that the effects of aging are adequately managed to assure that the Primary Containment intended function is ,performed consistent with the current licensing basis for the period of extended operation.

NUREG*1801 ConsistEmcy The lSI Program -IWE is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG*1801, ' Section XI.S1, "ASME Section XI, Subsection IWE". The lSI Program -IVVE is performed un.der the Columbia Inservice Inspection (lSI) program. The lSI program is implemented largely to meet the rules and requirements of the ASME Section XI Code. The NUREG-1801 XI.S1 aging management program' evaluation has specifically included the Code year (e.g., 2001 edition including the 2002 and 2003 Addenda), as, endorsed by the NRC in 10 CFR 50.55a. Exceptions to NUREGi*1801 None. Required Enhancements None . Aging Management Programs Page 8-139 January 2010 Columbia Generating Station License Renewal Application Technical InformationOperating Experience Columbia containment examinations and tests required by the ISI Program -IWE have been implemented in accordance with the established schedule. All the examinations scheduled for the first and second inspection ISI intervals have been completed. All of these examinations and tests performed to date have satisfied the acceptance standards contained within Article IWE-3000, without exception. Currently, there are no containment surfaces or components requiring designation as augmented examination areas. Columbia's Mark II containment is inerted with nitrogen, which provides an atmosphere that is not conducive to corrosion of containment interior surfaces. ISI third interval first period Refueling Outage 18 (R18) also satisfied the acceptance standards contained within Article IWE-3000. Two bolting related defects were found during the IWE inspection and were reported in the R18 IS[ summary report, one was related to a bolt for the drywell head and the other for a bolt on the equipment hatch. Both bolt and nut sets were replaced and subsequently pressure tested to confirm pressure boundaryintegrity of the joint. Inservice inspection records are maintained in accordance with Article IWA 6340 and are maintained in the permanent plant file storage.The health of the ISI program is reported periodically in terms of performance indicators. The program health reports for 2007 and 2008 indicated no age-related concerns for systems and components within the scope of the ISI Program -IWE. Review of plant operating experience did not reveal containment integrity issues with regards to containment components pertaining to ASME Section Xl, Subsection IWE.The suppression pool wetted surfaces of the submerged areas were examined and found acceptable. The NRC issued a request for additional information (RAI) on drywell degradation to Columbia in December 1987, since it is the only Mark II plant design with a steel containment and because design features, which contribute to drywell shell corrosion in Mark I containments appear to exist at Columbia. Degradation of the drywell for Mark I containments, due to moisture or water in the sand pockets, is the topic of Generic Letter 87-05. For license renewal, this same topic is the subject of interim staff guidance, with respect to the considerations for aging management during the period of extended operation. Columbia provided a response to the above RAI in February 1988.This response described the pathways through which water could enter the air gapbetween the steel containment and the shield building, the compressible materials separating the containment and shield wall, and the assessment of the conditions of the containment annulus sand pocket and associated draining system.Due to the possibility of containment Shell degradation from corrosion induced by a moist environment in the sand pocket region, Columbia has committed to monitor humidity levels in this region. Columbia has implemented a procedure to survey the relative humidity of air drawn from within the containment annulus sand pocket region.Review of past inspection results revealed that inspections performed were satisfactory Aging Management Programs Page B-140 January 2010 Operating Experience Columbia Generating Station License Renewal Application Technical Information Columbia containment examinations and tests required by the lSI Program -IWE have been implemented in accordance with the established schedule. All the examinations scheduled for the first and second inspection lSI intervals have been completed. All of these examinations and tests performed to date have satisfied the acceptance standards contained within Article IWE-3000, without exception. Currently, there are no containment surfaces or components requiring designation as augmented examination areas. Columbia's, Mark II containment is inerted with nitrogen, which provides an atmosphere that is not conducive to corrosion of containment interior surfaces. lSI third interval first period Refueling Outage 18 (R 18) also satisfied the acceptance standards contained within Article IWE-3000. Two bolting related defects were found during the IWE inspection and were reported in the R 18 lSI summary report, one was related to a bolt for the drywell head and the other fora bolt on the equipment 'hatch. Both bolt and nut sets were replaced and subsequently pressure tested to confirm pressure boundary integrity of the joint. Inservice inspection records are maintained in accordance with Article IWA 6340 and are maintained in the permanent plant file storage.

• The health of the lSI program is reported periodically in terms of performance indicators.

The program health reports for 2007 and 2008 indicated no age-related concerns for systems and components within the scope of the lSI Program -IWE. Review of plant operating experience did not reveal containment integrity issues with regards to

• containment components pertaining to ASME Section XI, Subsection IWE. The suppression pool wetted surfaces of the submerged areas were examined and found acceptable.

The NRC issued a request for additional information (RAI) on drywell degradation to Columbia in December 1987, since it is the only Mark II plant design' with a steel containment and because design features, which contribute to drywell shell corrosion in Mark I containments appear to exist at Columbia. Degradation of the drywell for Mark I containments, due to moisture or water in the sand pockets, is the topic of Generic Letter 87-05. For license renewal, this same topic is the subject of interim staff guidance, with respect to the 'considerations for aging management during the period of extended operation. Columbia provided a response to the above RAI in February 1988. This response described the pathways through which water could enter the air gap between the steel containment and the shield building, the compressible materials separating the containment and shield wall, and the assessment of the conditions of the containment annulus sand pocket and associated draining system. Due to the possibility of containment shell degradation from corrosion induced by a moist environment in the sand pocket region, Columbia has committed to monitor humidity levels in this region. Columbia has implemented a procedure to survey the relative humidity of air drawn from within the containment annulus sand pocket region. Review of past inspection results' revealed that inspections performed were satisfactory Aging Management Programs Page 8-140 January 2010

• Columbia Generating Station License Renewal Application Technical Information and surveillances since late 1989 indicate no water has been detected; and that there is no evidence of leakage into the sand pocket region. Measurement of sand pocket area humidity provides assurance that water is not accumulating in the sand pocket area, which could cause corrosion of the outer containment shell.The ISI Program -IWE has been effective in managing the identified aging effects. The site corrective action program and ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects.Conclusion The Inservice Inspection (ISI) Program -IWE will be capable of detecting and managing loss of material for the steel surfaces of the containment.

The continued implementation of the Inservice Inspection (ISI) Program -IWE provides reasonable assurance that the aging effects will be managed such that the structures and components will continue to perform their intended function consistent with the current licensing basis for the period of extended operation. Aging Management Programs Aging Management Programs Page B-141 January 2010 Page B-141 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information and surveillances since late 1989 indicate no water has been detected; and that there is no evidence of leakage into the sand pocket region. Measurement of sand pocket area humidity provides assurance that water is not accumulating in the sand pocket area, which could cause corrosion of the outer containment shell. The lSI Program -IWE has been effective in managing the identified aging effects. The site corrective action program and ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects. . Conclusion The Inservice Inspection (lSI) Program -IWE will be capable of detecting and managing loss of material for the steel surfaces of the containment.

The continued implementation of the Inservice Inspection (lSI) Program -IWE provides reasonable assurance that the aging effects will be managed such that the structures and components will continue to perform their intended function consistent with the current licensing basis for the period of extended operation . Aging Management Programs Page 8-141 . January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.35 Inservice Inspection (ISI) Program -IWF Program Description The Inservice Inspection (ISI) Program -IWF establishes responsibilities and requirements for conducting IWF inspections as required by 10 CFR 50.55a. The ISI Program -IWF includes visual examination for supports based on sampling of the total support population. The sample size varies depending on the ASME Class. The largest sample size is specified for the most critical supports (ASME Class 1 and those other than piping supports (Class 1, 2, 3, and MC)). The sample size decreases for the less critical supports (ASME Class 2 and 3). Discovery of support deficiencies during regularly scheduled inspections triggers an increase of the inspection scope, in order to ensure that the full extent of deficiencies is identified. The primary inspection method employed is visual examination. Degradation that potentially compromises supportfunction or load capacity is identified for evaluation. IWF specifies acceptance criteria and corrective actions. Supports requiring corrective actions are re-examined during the next inspection period in accordance with the requirements of the ASME Code, Section Xl, 2001 Edition through 2003 Addenda for Subsection IWF.The in-service examinations conducted throughout the service life of Columbia will comply with the requirements of the ASME Code Section Xl, Edition and Addenda incorporated by reference in 10 CFR 50.55a(b) 12 months prior to the start of the inspection interval, subject to prior approval of the edition and addenda by the NRC.This is consistent with NRC statements of consideration associated with the adoption of new editions and addenda of the ASME Code in 10 CFR 50.55a.The ISI Program -IWF provides reasonable assurance that the effects of aging are adequately managed to assure that the Class 1, 2, and 3 component supports intended function is performed consistent with the current licensing basis for the period of extended operation. NUREG-1801 Consistency The ISI Program -IWF is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.S3, "ASME Section XI, Subsection IWF".The ISI Program -IWF is performed under the Columbia Inservice Inspection (ISI)program. The ISI program is implemented largely to meet the rules and requirements of the ASME Section XI Code. The NUREG-1801 XI.S3 aging management program evaluation specifically includes the Code year (e.g., 2001 edition including the 2002 and 2003 Addenda), as endorsed by the NRC in 10 CFR 50.55a.Aging Management Programs Page B-142 January 2010 Aging Management Programs Page B-142 January 2010 Columbia Generating Station License Renewal Application

• Technical Information 8.2.35 Inservice Inspection (151) Program -IWF . Program Description The Inservice Inspection (lSI) Program -IWF establishes responsibilities and requirements for conducting IWF inspections as required by 10 CFR 50.55a. The lSI Program -IWF includes visual examination for supports based on sampling of the total support population.

The sample size varies depending on the ASME Class. The largest sample size is specified for the most critical supports (ASME Class 1 and those other than piping supports (Class 1, 2, 3, and MC)). The sample size decreases for the less critical supports (ASME Class 2 and. 3). Discovery of support deficiencies during regularly scheduled inspections triggers an increase of the inspection scope, in order to ensure that the full extent of deficiencies is identified. The primary inspection method employed is visual examination. Degradation that potentially compromises support function or load capacity is identified for evaluation. IWF specifies acceptance criteria and corrective actions. Supports requiring corrective actions are re-examined during the next inspection period in accordance with the requirements of the ASME Code, Section XI, 2001 Edition through 2003 Addenda for Subsection IWF. The examinations conducted throughout the service life of Columbia will comply with the requirements of the ASME Code Section XI, Edition and Addenda incorporated by reference in 10 CFR 50.55a(b) 12 months prior to the start of the

• inspection interval, subject to prior approval of the edition and addenda by the NRC. This is consistent with NRC statements of consideration associated with the adoption of new editions and addenda of the ASME Code in 10 CFR 50.55a. The lSI Program -IWF provide's reasonable assurance that the effects of aging are adequately to assure that the Class 1, 2, and 3 component supports intended function is performed consistent with the current licensing basis for the period of extended operation.

NUREG-1801 Consistency The lSI Program -IWF is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.S3, "ASME Section XI, Subsection IWF". The lSI Program -IWF is performed under the Columbia Inservice Inspection (lSI) program. The lSI program is implemented largely to meet the rules and requirements of the ASME Section XI Code. The NUREG-1801 XI.S3 aging management program evaluation specifically includes the Code year (e.g., 2001 edition including the 2002 and 2003 Addenda), as endorsed by the NRC in 10 CFR 50.55a. Aging Management Programs Page 8-142 January 2010 o.

• Columbia Generating Station License Renewal Application Technical Information Exceptions to NUREG-1801 None.Required Enhancements None.Operating Experience The ISI Program -IWF refueling outage 18 (R-18) inspection identified non aging-related degradation such as a spring can setting out of tolerance.

This deficiency was further evaluated and accepted in accordance with the ISI program. Another deficiency found was one of the 1/2 inch bolts holding the installed shims in place sheared at a reactor pressure vessel (RPV) stabilizer. An engineering evaluation determined that the condition of the RPV stabilizer is acceptable. A condition report documents the discovery of this sheared bolt. Only one of the two 1/2 inch diameter bolts provided for shim restraint on each side is damaged (i.e., the upper bolt on the right hand side) and the associated shims are not dislodged, the condition does not affect the overall functionality of the RPV stabilizer. The damaged bolt was replaced during refueling outage 19 (R-19).Examinations were conducted of 100 percent of the locations specified in the program.There were two Code-related successive inspections required to be performed per Subsection IWF during the third interval first inspection period. These inspections, one on a snubber and one on a spring support, were performed during the R-19 outage andthe results were acceptable.The health of the ISI program is reported periodically in terms of performance indicators. The program health reports for 2007 and 2008 indicated no age-related concerns for systems and components within the scope of the ISI Program -IWF. Review of the three previous Refueling Outage (R-18, R-17, and R-16) ISI summary reports and plant operating experience did not reveal age-related issues with regards to ASME Class 1,2, 3, and MC supports pertaining to ASME Section Xl, Subsection IWF.The ISI Program -IWF has been effective in managing the identified aging effects. The site corrective action program and ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects.Aging Management Programs Page B-143 January 2010* *

• Exceptions to NUREG-1801 None. Required Enhancements None. -" Operating Experience Columbia Generating Station license Renewal Application Technical Information The lSI Program -IWF refueling outage 18 (R-18) inspection identified non aging-. I ' related degradation such as a spring can setting out of tolerance, This deficiency was further evaluated and accepted in accordance with the lSI program. Another deficiency found was one of the 1/2 inch bolts holding .the installed shims in place sheared at a reactor pressure vessel (RPV) stabilizer.

An engineering evaluation determined that the condition of the RPV stabilizer is acceptable. A condition report documents the discovery of this sheared bolt. Only one of the two 1/2 inch diameter bolts provided for shim restraint on each side is damaged (i.e., the upper bolt on the right hand side) and the associated shims are not dislodged, the condition does not affect the overall functionality of the RPV stabilizer. The damaged bolt was replaced during refueling outage 19 (R-19) . Examinations were conducted of 100 percent of the locations specified in the program. There were two Code-related successive inspections required to be performed per Subsection IWF during the third interval first inspection period. These inspections, one on a snubber and one on a spring support, were performed during the R-19 outage and the results were acceptable. The health of the lSI program is reported periodically in terms of performance indicators. The program health reports for 2007 and 2008 indicated no concerns for systems and components within the scope of lSI Program -IWF. Review of the three previous Refueling Outage (H-18, R-17, and R-16) lSI summary reports and plant operating experience did not reveal age-related issues with regards to ASME Class 1, 2, 3, and MC supports pertaining to ASME Section XI, Subsection IWF. The lSI Program -IWF has been effective in managing the identified aging effects. The site corrective action program and ongoing review of industry operating experience will be used to ensu're that the program continues to be effective in managing the identified aging effects, Aging Management Programs Page 8-143 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Conclusion The Inservice Inspection (ISI) Program -IWF will be capable of detecting and managing loss of material and cracking for ASME Class 1, 2, and 3 component supports. The continued implementation of the Inservice Inspection (ISI) Program -IWF provides reasonable assurance that aging effects will be managed such that the structures and components will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-144 January 2010 Aging Management Programs Page B-144 January 2010 Conclusion Columbia Generating Station License Renewal Application Technical Information Thelnservice Inspection (lSI) Program -IWF will be capable of detecting and managing loss of material and cracking for ASME Class 1, 2, and 3 component supports. The continued implementation of the Inservice Inspection (lSI) Program -IWF provides reasonable assurance that aging effects will be managed such that the structures and components will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-144 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information B.2.36 Lubricating Oil Analysis Program Program Description The Lubricating Oil Analysis Program will mitigate the effects of aging for plant components that are within the scope of license renewal and exposed to a lubricating oil environment. The program ensures that the oil environment in the mechanical systems is maintained to the required quality. The program manages the relevant conditions that could lead to the onset and propagation of a loss of material due to crevice, galvanic, general, or pitting corrosion or selective leaching, or reduction in heat transfer due to ,fouling, through monitoring of the lubricating oil consistent with manufacturer's recommendations and industry standards.

The relevant conditions are specific parameters including particulate and water content, viscosity, neutralization number, and flash point that are indicative of conditions that could lead to age-related degradation of susceptible materials. The Lubricating Oil Analysis Program is a mitigation program.The Lubricating Oil Analysis Program is supplemented by a one-time inspection of representative areas of lubricating oil systems under the Lubricating Oil Inspection to provide confirmation that loss of material and fouling are effectively mitigated. NUREG-1801 Consistency The Lubricating Oil Analysis Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M39, "Lubricating Oil Analysis." Exceptions to NUREG-1801 None.Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program element: Scope -Include the following Fire Protection System components that are exposed to lubricating oil within the scope of the program: (1) fire protection diesel engine heat exchangers (lube oil coolers), (2) fire protection diesel engine lube oil piping, and (3) fire protection diesel engine lube oil pump casings.Aging Management Programs Aging Management Programs Page 8-145 January 2010 Page B-145 January 2010* 8.2.36 Lubricating Oil Analysis Program Program Description Columbia Generating Station License Renewal Application Technical Information The Lubricating Oil* Analysis Program will mitigate the effects of aging for plant components that are within the scope of license renewal and exposed to a lubricating oil environment. The program ensures that the oil environment in the mechanical systems is maintained to the required quality. The program manages the relevant conditions that could lead to the onset and propagation of a loss of material due to crevice, galvanic, general, or pitting corrosion or selective leaching, or reduction in heat transfer due to fouling, through monitoring of the lubricating oil consistent with manufacturer's recommendations and industry standards. The relevant conditions are specific parameters including particulate and water content, viscosity, neutralization number, and flash point that are indicative of conditions that could lead to age-related degradation of susceptible materials. The Lubricating Oil Analysis Program is a mitigation program. The Lubricating Oil Analysis Program is supplemented by a one-time inspection of representative areas of lubricating oil systems under the Lubricating Oil Inspection to provide confirmation that loss of material and fouling are effectively mitigated.

• NUREG*1801 Consisbmcy
• The Lubricating Oil Analysis Program is an existing Columbia program that, with enhancement, will be c()nsistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M39, "Lubricating Oil Analysis." Exceptions to NUREG*1801 None. Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program element:
• Scope-Include the following Fire* Protection System components that are exposed to lubricating oil within the scope of the program: (1) fire protection diesel engine heat exchangers (lube oil coolers), (2) fire protection diesel engine lube oil piping, and (3) fire protection diesel engine lube oil pump casings . Aging Management Programs Page 8-145 January 2010 Columbia Generating Station License Renewal Application Technical Information Operating Experience The Lubricating Oil Analysis Program is, an ongoing program that effectively incorporates the best practices of the industry.

Manufacturer recommendations and industry standards are used to establish quality requirements for lubricating oil. The program incorporates the results of operating experience from Columbia and from other utility and industry sources. The program has been, and continues to be, subject to periodic internal and external assessment of the performance to identify strengths and areas for improvement. Review of Columbia operating experience did not reveal a loss of component intended function for components exposed to lubricating oil that could be attributed to an inadequacy of the Lubricating Oil Analysis Program. Abnormal lubricating oil conditions are promptly identified, evaluated, and corrected. For example, lubricating oil in the feedwater turbine has previously been found contaminated with water. The Lubricating Oil Analysis Program evaluated the condition, determined the source of the waterthrough sampling and analysis, and initiated corrective action. The lubricating oil was replaced and the source of the water leakage was repaired. In addition, levels of lead in emergency diesel generator lube oil have been found that exceeded the specified limits and showed an increasing trend. The evaluation determined the source to be soldered joints on the lube oil coolers. A planned replacement of the oil coolers with a different design was already in place at the time the source was determined, and the coolers have since been replaced.Conclusion The Lubricating Oil Analysis Program will manage loss of material and reduction in heat transfer for susceptible components in lubricating oil, through monitoring of the relevant parameters. The Lubricating Oil Analysis Program, with the required enhancements, and supplemented by the Lubricating Oil Inspection prior to entering the period of extended operation provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-146 January 2010 Aging Management Programs Page B-146 January 2010 Columbia Generating Station License Renewal Applicatio.n

• . Technical Information Operating Experience The Lubricating Oil Analysis Program is, an ongoing program that effectively incorporates the best practices of the industry.

Manufacturer recommendations and industry standards are used to establish quality requirements for lubricating oil. program incorporates the results of operating experience from Columbia and from other utility and industry sources. The program has been, and continues to be, subject to periodic internal and external assessment of the performance to identify strengths and areas for improvement. Review of Columbia operating experience did not reveal a loss of component intended function for components exposed to lubricating oil that could be attributed to an inadequacy ot the Lubricating Oil Analysis Program. Abnormal lubricating oil conditions are promptly Identified, evaluated, and corrected. For example, lubricating oil in the feedwater turbine has previously been found contaminated with water. The Lubricating Oil Analysis Program evaluated the condition, determined the source of the water through sampling and analysis, and initiated corrective action. The lubricating oil was replaced and the source of the water leakage was repaired. In addition, levels of lead in emergency diesel generator lube oil have been found that exceeded .the specified limjts and showed an increasing trend. The evaluation determined the source to be soldered joints on the lube oil coolers. A replacement of the oil coolers with a different

• design was already in place at the time the source was determined, and the coolers have since been replaced.

Conclusion The Lubricating Oil Analysis Program will manage loss of material and reduction in heat transfer for susceptible components in lubricating oil, through monitoring of the relevant parameters. The Lubricating Oil Analysis Program, with the required enhancements, and supplemented by the Lubricating Oil Inspection prior to entering the period of extended operation provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-146 January 2010

• Columbia Generating Station License Renewal Application Technical Information B.2.37 Lubricating Oil Inspection Program Description The Lubricating Oil Inspection is a new one-time inspection that will detect and characterize the condition of materials in systems and components for which the Lubricating Oil Analysis Program (a mitigation program) is credited with aging management.

The inspection provides direct evidence as to whether, and to what extent, a loss of material due to crevice, galvanic, general, or pitting corrosion or selective leaching, or reduction in heat transfer due to fouling, has occurred on surfaces exposed to lubricating oil.Implementation of the Lubricating Oil Inspection will provide additional confirmation of Lubricating Oil Analysis Program effectiveness and further assurance that the intended functions of susceptible components will be maintained consistent with the current licensing basis during the period of extended operation. NUREG-1801 Consistency The Lubricating Oil Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management, program as described in NUREG-1801, Section Xl. M32, "One-Time Inspection." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The scope of the Lubricating Oil Inspection includes the oil-wetted surfaces of aluminum, aluminum alloy, copper alloy, copper alloy > 15% Zn, steel,, gray cast iron, and stainless steel components in the following license renewal systems:* Control Rod Drive (CRD) System* Control Room Chilled Water (CCH) System* Diesel Cooling Water (DCW) System* Diesel Engine Starting Air (DSA) System* Diesel Exhaust (DE) System* Diesel Generators (DG) System Aging Management Programs Page B-147'January 2010* *

• B.2.37 Lubricating Oil Inspection Program Description Columbia Generating Station License Renewal Application Technical Information The Lubricating Oil Inspection is a new one-time inspection that will detect and characterize the condition of materials in systems and components for which the Lubricating Oil Analysis Program (a mitigation program) is credited with aging management.

The inspection provides direct evidence as to whether, and to what extent, a loss of material due to crevice, galvanic, general, or pitting corrosion or selective leaching, or reduction in heat transfer due to fouling, has occurred on surfaces exposed to lubricating oil. Implementation of the Lubricating Oil Inspection will provide additional confirmation of Lubricating Oil Analysis Program effectiveness and further assurance that the intendeq functions of susceptible components will be maintained consistent with the current licensing basis during the period of extended operation. NUREG--1801 ConsistEtncy The Lubricating Oil Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management* program as described in NUREG-1 1301, Section XI. M32, Inspection." Exceptions to NUREG-1801 None. Aging Management Plrogram Elements The results of an evaluation of each program element are provided below.

• Scope of Program The scope of the Lubricating Oil Inspection includes the oil-wetted surfaces of aluminum, aluminum alloy, copper alloy, copper alloy> 15% Zn, steel" gray cast iron, and stainless s,teel components in the following license renewal systems:
• Control Rod Drive (CRD) System
• Control Room Chilled Water (CCH) System
• Diesel Cooling Water (DCW) System
• Diesel Engine Starting Air (DSA) System
• Diesel Exha.ust (DE) System
• Diesel Generators (DG) System Aging Programs Page 8-147 . January 2010 Columbia Generating Station License Renewal Application Technical Information
• Diesel Lubricating Oil (DLO) System* Fire Protection (FP)

System' Low Pressure Core Spray (LPCS) System* Reactor Core Isolation Cooling (RCIC) System* Standby Service Water (SW) System A representative sample of components, with special 'emphasis on locations that may be susceptible to the collection of entrained water, will be examined for evidence of loss of material (due to crevice, galvanic, general, or pitting corrosion or selective leaching) or reduction in heat transfer due to fouling, or to confirm a lack thereof, and the results applied to all of the systems and components within the scope of the inspection, based on engineering evaluation.

• Preventive Actions No actions are taken as part of the Lubricating Oil Inspection to prevent aging effects or to mitigate aging degradation.
• Parameters Monitored or Inspected The parameters to be inspected by the Lubricating Oil Inspection include wall thickness and visual evidence of internal or external surface degradation as measures of a loss of material or fouling. Inspections will be performed by qualified personnel using established NDE techniques." Detection of Aging Effects The Lubricating Oil Inspection will use a combination of established volumetric and visual examination techniques and nondestructive methods performed by qualified personnel on a sample population of subject components to identify evidence of loss of material or fouling or to confirm a lack thereof.The sample population will be determined by engineering evaluation based on sound statistical sampling methodology, and, where practical, will focus on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and design margins.The Lubricating Oil Inspection will be conducted within the 10-year period prior to the period of extended operation.

Monitoring and Trending No actions are taken as part of the Lubricating Oil Inspection to monitor or trend inspection results. This is a one-time inspection activity used to determine if, and to what extent, further actions, including monitoring and trending, may be required. Aging Management Programs Page B-148 January 2010* Diesel Lubricating Oil (OLD) System

• Fire Protection (FP) System
• Low Pressure Core Spray (LPCS) System
• Reactor Core Isolation Cooling (RCIC) System
• Standby Service Water (SW) System Columbia Generating Station License Renewal Application Technical Information A representative sample of components, with special 'emphasis on locations that may be susceptible to the collection of entrained water, will be examined for evidence of loss of material (due to crevice, galvanic, general, or pitting corrosion or selective leaching) or reduction in heat transfer due to fouling, or to confirm a lack thereof, and the results applied to all of the systems and components within the scope of the inspection, based on engineering evaluation.
• Preventive Actions No actions are taken as part of the Lubricating Oil Inspection to prevent aging effects or to mitigate aging degradation. .
• Parameters Monitored or Inspected
• The parameters to be inspected by the Lubricating Oil Inspection include wall
• thickness and visual evidence of internal or external surface degradation as measures of a loss of material or fouling. Inspections will be performed by qualified personnel using established NDE techniques.
• Detection of Aging Effects The Lubricating Oil Inspection will use a combination of established volumetric and visual examination techniques and nondestructive methods performed by qualified personnel on a sample population of subject components to identify evidence of loss of material or fouling or to confirm a lack thereof.

The sample population will be determined by engineering evaluation. based on sound statistical sampling methodology, and, where practical, will focus on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and design margins. The Lubricating Oil Inspection will be conducted within the 1 O-year period prior to the period of extended operation.

• Monitoring and Trending No actions are taken as part of the l:ubricating Oil Inspection to monitor or trend inspection results. This is a one-time inspection activity used to determine if, and to what extent, further actions, including monitoring and trending, may be required.

Aging Management Programs Page 8-148 January 2010

• Columbia Generating Station License Renewal Application Technical Information Sample size will be determined by engineering evaluation, as described for the Parameters Monitored or Inspected element above. Results of inspection activities that require further evaluation and resolution (e.g., if degradation is detected), if any, will be evaluated using the Columbia corrective action process, including expansion of the sample size and inspection locations to determine the extent of the degradation.

Acceptance Criteria Indications or relevant conditions of degradation detected'during the inspections will be compared to pre-determined acceptance criteria. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Operating Experience The Lubricating Oil Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effects. The activity provides confirmation of conditions where degradation is not expected, has not evidenced as a problem, or where the aging mechanism is slow acting. Inspection methods are to be consistent with accepted industry practices.

NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience to date has identified no instances ofage-related degradation in lubricating oil environments. The site corrective action Aging Management Programs Page B-149 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information Sample size will be determined by engineering evaluation, as described for the Parameters or Inspected element above. Results of inspection activities that require further evaluation and resolution (e.g., if degradation is detected), if any, will be evaluated using the Columbia corrective action process, including expansion of the sample SiZE! and inspection locations to determine the e'xtent of the deg radation.
• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspections will be compared to pre-determined acceptance criteria.

If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. .
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Administrative Controls . This element is common to Columbia programs and activities that are credited with . aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience The Lubricating Oil Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effects. The activity provides confirmation of conditions where degradation is not expected, has not evidenced as a problem, or where the aging mechanism is slow acting. Inspection methods are to be consistent with accepted industry practices.

NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience to' date has identified no instances of age:-related degradation in lubricating oil The site corrective action Aging Management Programs Page 8-149 January 2010 Columbia Generating Station License Renewal Application Technical Information program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for systems within the scope of this activity.Required Enhancements Not applicable, this is a new activity.Conclusion Implementation of the Lubricating Oil Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page B-1 50 January 2010 Columbia Generating Station License Renewal Application

• Technical Information program and an ongoing review of industry operating experience will be used to ensure that a one-time inspection activity remains the appropriate method for managing the effects of aging for systems within the scope of this activity.

Required Enhancements Not applicable, this is a new activity. Conclusion Implementation of the Lubricating Oil Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page 8-150 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information B.2.38 Masonry Wall InspectionProgram Description The Masonry Wall Inspection is an existing condition monitoring program consisting of inspection activities to detect aging and age-related degradation for masonry walls identified as performing intended functions in accordance with 10 CFR 54.4., Masonry walls that perform a fire barrier intended function are also managed by the FireProtection Program.

The Masonry Wall Inspection is implemented as part of the Structures Monitoring Program conducted for the Maintenance Rule.Aging effects identified within the scope of the MasonryWall Inspection are detected by visual inspection of external surfaces prior to the loss of the structure's or component's intended functions. Masonry walls are visually examined at a frequency selected to ensure there is no loss of intended function between inspections and that the evaluation basis established for each masonry wall within the scope of license renewal remains valid through the period of extended operation. NUREG-1801 Consistency The Masonry Wall Inspection is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.S5, "Masonry Wall Program." Exceptions to NUREG-1801 None.Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program elements: Parameters Monitored or Inspected, Acceptance Criteria -Specify that for each masonry wall, the extent of observed masonry cracking or degradation of steel edge supports and bracing are evaluated to ensure that the current evaluation basis is still valid. Corrective action is required if the extent of masonry cracking or steel degradation is sufficient to invalidate the evaluation basis. An option is to develop a new evaluation basis that accounts for the degraded condition of the wall (i.e., acceptance by further evaluation). Aging Management Programs Page B-1 51 January 2010* *

• 8.2.38 Masonry Wall Inspection Program Description " Columbia Generating Station License Renewal Application Technical Information The Masonry Wall Inspection is an existing condition monitoring program consisting of inspection activities to detect aging and age-related degradation for masonry walls identified as performing intended functions in accordance with 10 CFR 54.4.. Masonry walls that perform a fire barrier intended function are also managed by the Fire Protection Program. The Masonry Wall Inspection is implemented as part of the Structures Monitoring Program conducted for the Maintenance Rule. Aging effects identified within the scope of the Masonry'Wall Inspection are detected by visual inspection of surfaces prior to the loss of the structure's or component's intended functions.

Masonry walls are visually examined .at a frequency selected. to ensure there is no loss of intended function between inspections and that the evaluation basis established for each masonry wall within the scope of license renewal remains valid through the period of E1xtended operation. NUREG-1801 ConsistEmcy Masonry Wall Inspection is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1 1301, Section XI.S5, "Masonry Wall Program." Exceptions to NUREG-1801 None. Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program elements: .

• Parameters Monitored or Inspected, Acceptance Criteria -Specify that for each masonry wall, the extent of observed masonry cracking or degradation of steel edge supports and bracing are evaluated to ensure that the' current evaluation basis is still valid. Corrective action is required if the extent of masonry cracking or steel degradation is sufficient to invalidate the' evaluation basis. An option is to develop a new evaluation basis that accounts for the degraded condition of the wall (Le., acceptance by further evaluation) . Ag,i,ng Management Programs Page 8-151 January 2010 Columbia Generating Station License Renewal Application Technical Information Operating Experience The Masonry Wall Inspection includes all masonry walls identified in accordance with 10 CFR 54.4. This includes masonry walls in the Circulating Water Pump House, Turbine Generator Building, and the NSR portion of the Radwaste Control Building.There are no safety-related masonry walls at Columbia.

Some removable shielding block walls.are installed between steel plates in the proximity of Class 1 piping in the Reactor Building. These shield walls have been evaluated to assure that they could withstand a combination dead load plus seismic load resulting from a safe shutdown earthquake. The Masonry Wall Inspection has been effective in managing the identified aging effects. Visual examinations conducted by the Masonry Wall Inspection, as implemented by the Structures Monitoring Program, have not found any age-related problems or degraded conditions for masonry walls that could affect their intended function.Therefore the Masonry Wall Inspection, as implemented by the Structures Monitoring Program, has provided reasonable assurance that aging effects are being managed.The site corrective action program and ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects.Conclusion The Masonry Wall Inspection with enhancement, as part of .the Structures Monitoring Program, will be capable of detecting and managing aging effects for the masonry walls within the scope of license renewal. The continued implementation of the Masonry Wall Inspection, with the required enhancement, provides reasonable assurance that the effects of aging will be managed so that components subject to aging management review will continue to perform their intended functions, consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-152 January 2010 , Operating Experience Columbia Generating Station License Renewal Application Technical Information The Masonry Wall Inspection includes all masonry walls identified in accordance with 10 CFR 54.4. This includes masonry walls in the Circulating Water Pump House, Turbine Generator Building, and the NSR portion of the Radwaste Control Building. There are no safety-related masonry walls at Columbia. Some removable shielding block walls .are installed between steel plates in the proximity of Class 1 piping in the Reactor Building. These shield walls have been evaluated to assure that they could withstand a combination dead load plus seismic load resulting from a safe shutdown , earthquake. The Masonry Wall Inspection has been effective in managing the identified aging effects. ' Visual examinations conducted by the Masonry Wall Inspection, as by the Structures Monitoring Program, have not found any age-related problems or degraded conditions for masonry walls that could affect their intended function. Therefore the Masonry Wall Inspection, as implemented by the Structures Monitoring Program, has provided reasonable assurance that aging effects are being managed.

• The site corrective action program and ongoing review of industry operating experience will' be used, to ensure that the program continues to be effective in managing the .' identified aging effects. Conclusion The Masonry Wall Inspection with enhancement, as part of .the Structures Monitoring Program, will be capable of detecting and managing aging effects for the masonry walls within the scope of license renewal. The continued implementation of the Masonry Wall Inspection, with the required enhancement, provides reasonable assurance that the effects of aging will be managed so that components subject to aging management review will continue to perform their intended functions.

consistent with the current licensing basis for the period of extended operation. Aging Management Programs PageB-152 January 2010 .

• Columbia Generating StationLicense Renewal Application Technical Information B.2.39 Material Handling System Inspection Program Program Description The Material Handling System Inspection Program is credited with managing loss of material for cranes (including bridge, trolley, rails, and girders), monorails, and hoists within the scope of license renewal. The Material Handling System Inspection Program is based on guidance contained in ANSI B30.2 for overhead and gantry cranes, ANSI B30.11 for monorail systems and underhung cranes, and ANSI B30.16 for overhead hoists. The inspections monitor structural members for signs of corrosion and wear.The inspections are performed periodically for installed cranes and hoists (e.g., annually for the reactor building crane, other NUREG-0612 heavy load handling systems and the refueling platform).

The Material Handling System Inspection Program provides reasonable assurance that the effects of aging are adequately managed for Columbia cranes (including bridge, trolley, rails, and girders), monorails, and hoists and that their intended function will continue to be performed consistent with the current licensing basis for the period of extended operation. NUREG-1801 Consistency The Material Handling System Inspection Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M23, "Inspection of Overhead Heavy Load and Light Load (Related to Refueling) Handling Systems." Exceptions to NUREG-1801 None.Required Enhancements Prior to the period of extended operation the enhancement listed below will be implemented in the identified pro'ram element:* Detection of Aging Effects-Ensure jib cranes and electrically operated hoists are visually inspected for corrosion. Operating Experience! A review of crane and hoist inspections previously conducted at Columbia and of industry operating experience confirms the acceptability of the inspections and their-Aging Management Programs Page B-1 53 January 2010* *

• 8.2.39 Material Handling System Inspection Program Program Description Columbia Generating Station License Renewal Application Technical Information The Material Handling System Inspection Program is credited with managing loss of material for cranes (including bridge, trolley, rails, and girders), monorails, and hoists within the scope of license renewal. The Material Handling System Inspection Program is based on guidance contained in ANSI 830.2 for overhead and gantry cranes, ANSI 830.11 for monorail systems and underhung cranes, and ANSI 830.16 for overhead hoists. The inspections monitor structural members for signs of corrosion and wear. The inspections are performed periodically for installed cranes and hoists (e.g., annually for the reactor building crane, other NUREG-0612 heavy load handling systems and the refueling platform).

The Material Handling System Inspection Program provides reasonable assurance that the effects of aging are adequately managed for Columbia cranes (including bridge, trolley, rails, and girders), monorails, and hoists and that their intended function will continue to be performed consistent with the current licensing basis for the period of extended operation. . NUREG-1801 ConsistEmcy The Material Handling System Inspection Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M23, "Inspection of Overhead Heavy Load and Light Load (Related to Refueling) Handling Systems." . Exceptions to NUREG,-1801 , None. Required Enhancements prior to the period of extended operation the enhancement listed below will be implemented in the identified program element: .* Detection of Aging Effects -Ensure jib cranes and electrically operated hoists are visually for corrosion. Operating ExperienCE! A review of crane and hoist inspections previously conducted at Columbia and of industry operating experience confirms the acceptability of the inspections and their' Aging Management Programs PageB-153 January 2010 Columbia Generating Station License Renewal Application Technical Information frequency in that degradation of cranes (including bridge, trolley, rails, and girders), monorails, and hoists was detected prior to loss of function. Related crane and hoist inspections have found no age-related degradation problems.The health of the Material Handling System Inspection Program is reported periodically in terms of performance indicators. The program health reports for 2007 and 2008 noted no age-related improvements for the program.The Material Handling System Inspection Program has been effective in managing the identified aging effects. The site corrective action program and ongoing review of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects.Conclusion The Material Handling System Inspection Program will be capable of detecting and managing loss of material for cranes (including bridge, trolley, rails, and girders), monorails, and hoists within the scope of license renewal. The continued implementation of the Material Handling System Inspection Program, with the required enhancement, provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue 'to perform their intended functions consistent with the current licensing basis for the period of extended operation. 0 Aging Management Programs PageB1-154 January 2010 Columbia Generating Station License Renewal Application Technical Information frequency in that degradation of cranes (including bridge, trolley, rails, and girders), monorails, and hoists was detected prior to loss of function. crane and hoist inspections have found no age-related degradation problems. The health of the Material Handling System Inspection Program is reported in terms of performance indicators. The program health reports for 2007 and 2008 noted no age-related improvements for the program. The Material Handling System Inspection Program has been effective in managing the identified aging ,effects. The site corrective action program and ongoing reviE;!w of industry operating experience will be used to ensure that the program continues to be effective in managing the identified aging effects. Conclusion

• The Material Handling System Inspection Program will be capable of detecting and managing loss of material for cranes (including bridge, trolley, rails, and girders), monorails, and hoists within the scope of license renewal. The continued.

implementation of the Material Handling System Inspection Program, with the required enhancement, provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue *to perform their intended functions consistent with the current licensing basis for the period of

• extended operation. .
• Aging Management Programs Page 8-154 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.40 Metal-Enclosed Bus Program Program Description The Metal-Enclosed Bus Program will manage the aging of metal-enclosed bus within the scope of license renewal. The program provides for the periodic visual inspection ofmetal-enclosed bus, along with the use of thermography, in order to determine if age-related degradation is occurring.

The program will provide reasonable assurance that the electrical components will perform their intended functions for the period of extended operation. The Metal-Enclosed Bus Program is a new aging management program that will be implemented prior to the period of extended operation, with the first inspection to be completed prior to the end of the current operating license, and with both the thermography portion and the visual inspection portion to be performed every 10 years thereafter. The metal-enclosed bus addressed by this program includes the non-segregated bus associated with transformer E-TR-S (the 230-kV startup auxiliary power transformer). NUREG-1801 Consistency The Metal-Enclosed Bus Program is a new Columbia program that will be consistent with the 10 elements of an effective aging management program, as described in NUREG-1801, Section XI.E4, "Metal-Enclosed Bus," with an exception. Exceptions to NUREG-1801 Program Elements Affected: Parameters Monitored or Inspected The Metal-Enclosed Bus Program will perform the inspection of the various bus joints, seals, and gaskets when the bus assembly covers are removed for inspection of the internal components, rather than the Structures Monitoring Program (as listed in NUREG-1801 item VI.A-12). The Structures Monitoring Program will perform the inspection of the bus assembly external surfaces and the bus assembly structural supports.Aging Management Program Elements The results of an evaluation of each program element are provided below.* Scope of Program Aging Management Programs Page B-155 January 2010* *

• B.2.40 Metal-Enclosed Bus Program Program Description Columbia Generating Station License Renewal Application Technical Information The Metal-Enclosed Bus Program will manage the aging of bus within the scope of license renewal. The program provides for the periodic visual inspection of metal-enclosed bus, along with the use of thermography, in order to determine if related degradation is occurring.

The program will provide reasonable assurance that the electrical components will perform their intended functions for the period of . extended operation. The Metal-Enclosed Bus Program is a new aging management program that will be implemented prior to the period of extended operation, with the first inspection to be completed prior to the end of the current operating license, .and with both the thermography portion a.nd the visual inspection portion to be performed every 10 years

• thereafter.

The metal-enclosed bus addressed by this program includes the non-segregated bus. associated with transformer E-TR-S (the 230-kV startup auxiliary power transformer). NUREG-1801 Consistency The Metal-Enclosed Bus Program is a new Columbia program that will be* consistent with the 10 elements of an effective aging management program, as described in NUREG-1801, Section XI.E4, "Metal-Enclosed Bus," with an exception. Exceptions to NUREGi-1801 Program Elements Affected:

• Parameters Monitored or Inspected The Metal-Enclosed Bus Program will perform the inspection of the various bus jOints, seals, and gaskets when the bus assembly covers are removed for inspection of the internal components, rather than the Structures Monitoring Program (as listed in NUREG-1801 item VI.A-12).

The Structures Monitoring Program will perform the inspection of the bus assembly external surfaces and the bus assembly structural supports. Aging Management Program Elements The results of an evaluation of each program element are provided below.

• Scope of Program Aging Management Programs Page 8-155 January 2010 .

Columbia Generating Station License Renewal Application Technical Information The Metal-Enclosed Bus Program is credited with detecting aging effects for in-scope metal-enclosed bus. The in-scope bus is limited to non-segregated metal-enclosed bus in the 6.9-kV and 4.16-kV electrical systems associated with the off-site power supply (via transformer E-TR-S).* Preventive Actions The Metal-Enclosed Bus Program is an inspection program; no actions are taken to prevent or mitigate aging degradation." Parameters Monitored or Inspected The Metal-Enclosed Bus Program will inspect bus insulation for anomalies, such as embrittlement,. cracking, melting, swelling, or discoloration, which may indicate overheating or aging degradation. The internal bus enclosure will be inspected for cracks, corrosion, foreign debris, excessive dust buildup, and evidence of water intrusion. The internal bus supports (i.e., internal to the enclosure) will be inspected for structural integrity and any sign of cracks.The Metal-Enclosed Bus Program will inspect a sample of bus bolted connections via thermography for signs of loose connections. The in-scope bus will be checked from the exterior with the bus energized to provide gross detection of circuit hot spots.The Metal-Enclosed Bus Program will inspect the bus joints, seals, and gaskets when the assembly covers are removed for inspection of the internal components. Detection of Aging Effects The Metal-Enclosed Bus Program will utilize thermography to check the bolted connections in the non-segregated metal-enclosed bus that is within the license renewal scope. The thermography inspection will be performed for representative portions of the in-scope non-segregated metal-enclosed bus.The Metal-Enclosed Bus Program also includes visual inspection of the internal bus enclosure, bus insulation, and internal bus supports. The bus enclosure will be inspected for cracks, corrosion, foreign debris, excessive dust buildup, and evidence of water intrusion. The bus insulation will be inspected for anomalies, such as signs of embrittlement, cracking, melting, swelling, or discoloration, which may indicate overheating or aging degradation. The internal bus supports (internal to the enclosure) will be inspected for structural integrity and signs of cracking. The elastomers used to seal the bus enclosure assembly will be inspected for embrittlement, cracking, loosening, flaking, peeling, and other indications of aging degradation. Both the thermography inspection and the visual inspections will be performed at least once every 10 years, with the first inspections to be completed within the 10-year period prior to the end of the current operating license.Aging Management Programs Page B-1 56 January 2010 Columbia Generating Station License Renewal Application Technical Information The Metal-Enclosed Bus Program is credited with detecting aging effects for scope metal-enclosed bus. The in-scope bus is limited to non.:.segregated enclosed bus in the 6.9:..kV and 4.16-kV electrical systems associated with the site power supply (via transformer E-TR-S) . *

• Preventive Actions The Metal-Enclosed Bus Program is an inspection program; no actions are taken to prevent or mitigate aging degradation.
• Parameters Monitored or Inspected The Metal-Enclosed Bus Program will inspect bus insulation for anomalies, such as embrittlement, cracking, melting, swelling, or discoloration, which may indicate overheating or aging degradation.

The internal bus enclosure will be inspected for cracks, corrosion, foreign debris, excessive dust buildup, and evidence of water intrusion. The intl?rnal bus supports (i.e., internal to the enclosure) will be inspected for structural integrity and any sign of cracks. . The Metal-Enclosed Bus Program will inspect a sample of bus bolted connections via thermography for signs of loose connections. The in-scope bus will be checked from the exterior with the bus energized to provide gross detection of circuit hot spots. The Metal-,Enclosed Bus Program will inspect the bus joints, seals, and gaskets when the assembly covers are removed for inspection of the internal co.mponents.

• Detection of Aging Effects The Metal-Enclosed Bus Program will utilize thermography to check the bolted connections in the* non-segregated metal-enclosed bus that is within the license scope. The thermography inspection will be performed for representative portions of the in-scope non-segregated metal-enclosed bus. The Metal-Enclosed Bus Program also includes visual inspection of the internal bus enclosure, bus insulation, and internal bus supports.

The bus enclosure will be inspected for cracks, corrosion, foreign debris, excessive dust buildup, and evidence of water intrusion. The bus insulation will be inspected for anomalies, such as sigris of embrittlement, cracking, melting, swelling, or discoloration, which may indicate overheating or aging degradation. The internal, bus supports (internal to the enclosure) will be inspected for structural integrity and signs of cracking. The elastomers used to seal the bus enclosure assembly will be inspected for embrittlement, cracking, loosening, flaking, peeling, and other indications of aging degradation. Both the thermography inspection and the visual inspections will be performed at least once every 10 years, with the first inspections to be completed within the 10-year period prior to the end of the current operating license. Aging Management Programs Page 8-156 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information The external surfaces of the bus assemblies and the external bus enclosure supports (the structural supports for the entire bus assembly) will be inspected under the Structures Monitoring Program.Monitoring and Trending The Metal-Enclosed Bus Program will not include trending actions. If anomalies are found during the inspection process, they will be addressed at that time through the corrective action program.Acceptance Criteria The acceptance.

criteria for the thermography portion of the Metal-Enclosed Bus Program will be based on acceptance criteria already used in the thermography process at Columbia. The acceptance criteria for the visual inspection portion (of the bus enclosure) will be that the metal-enclosed bus conductor insulatioh is free from unacceptable visual indications of surface anomalies, such as embrittlement, cracking, melting, swelling, and discoloration, and that the metal-enclosed bus is also free from unacceptable indications of corrosion, cracking, foreign debris, excessive dust buildup, or evidence of moisture intrusion. In addition, theelastomers used to seal adjacent bus enclosures (exterior) are to be free from indications of aging degradation, such as embrittlement, cracking, loosening, flaking, and peeling. The seal cover gaskets will be inspected when the bus assembly covers are removed for inspection of the internal components. The seal cover gaskets (elastomers),,are to be free from indications of aging degradation, such as embrittlement, cracking, loosening, flaking, and peeling.The external surfaces of the bus assemblies and the external bus enclosure supports (the structural supports for the entire bus assembly) will be inspected under the Structures Monitoring Program.* Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.In addition, for the Metal-Enclosed Bus Program, further.investigation and evaluation are performed when the acceptance criteria are not met. Corrective actions may include (but are not limited to) cleaning, drying, an increased inspection frequency, replacement, or repair of the affected metal-enclosed bus components. If an unacceptable condition or situation is identified, a determination is made as to whether the 'same condition or situation is applicable to other accessible or inaccessible metal-enclosed bus.Aging Management Programs Page B-1 57 January 2010 , Columbia Generating Station License Renewal Application Technical Information The external surfaces of the bus assemblies and the external bus enclosure supports (the structural supports for the entire bus assembly) will be inspected under the Structures Monitoring Program. .

• Monitoring and Trending The Metal'-Enclosed Bus Program will not include trending actions. If anomalies are found during the inspection process, they will be addressed at that time through the corrective action
• Acceptance Criteria The acceptance.

criteria for the thermography portipn of the Metal-J=nclosed Bus Program will be based on acceptance criteria already used in the thermography process at Columbia. The acceptance criteria for the visual inspection portion (of the bus enclosure) will be that the metal-enclosed bus conductor insulation is free from unacceptable visual indications of surface anomalies, such as embrittlement, cracking, melting, swelling, and discoloration, and that the metal-enclosed bus is also free from unacceptable indications of corrosion, cracking, foreign debliis, excessive dust buildup, or evidence of moisture intrusion. In addition, the elastomers used to seal adjacent bus enclosures (exterior) are to be free from indications of aging degradation, such as embrittlement, cracking, loosening, flaking, and peeling. The seal cover gaskets will be inspected when the bus assembly covers are removed for inspection of the internal components. The seal cover gaskets (elastomers)\are to be free from indications of aging degradation, such embrittlement, cracking, loosening, flaking, and peeling. The external surfaces of the bus assemblies and the external bus enclosure supports (the structural supports for the ,entire bus assembly) will be inspected under the Structures Monitoring Program.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. In addition, forthe Metal-Enclosed Bus Program, further,investigation and evaluation are performed when the acceptance criteria are not met. Corrective actions may include (but are not limited to) cleaning, drying, an inspection frequency, replacement,or repair of the affected metal-enclosed' bus components.

If an ' unacceptable condition or situation is identified, a determination' is made as to whether the 'same condition or situation is applicable to other accessible or ' inaccessible metal-enclosed bus. Aging Management Programs Page 8-157 JanLiary 2010 Columbia Generating Station License Renewal Application Technical Information

• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Operating Experience The Metal-Enclosed Bus Program is a new program for which there is no direct site-specific operating experience.

Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Plant operating experience has shown that the corrective action program has addressed issues related to bus and bus enclosure degradation in recent years. For example, corrosion was identified on insulators used to support bus associated with the unit normal auxiliary transformer (which is not in scope for license renewal). In addition, the corrective action program noted that the use of thermography would provide an improvement to the bus preventive maintenance program. Industry '0 operating experience will be included in the development of this program.Required Enhancements Not applicable, this is a new program.Conclusion The Metal-Enclosed Bus Program will manage aging degradation for metal-enclosed bus. The Metal-Enclosed Bus Program will provide reasonable assurance that the aging effects will be managed such that metal-enclosed bus subject to aging management review will continue to perform its intended functions consistent with the current licensing basis for the period of extended operation. <*Aging Management Programs Page B-1 58 January 2010* Confirmation Process Columbia Generating Station License Renewal Application Technical Information This element is-common to Columbia programs and activities that are credited with aging management during the period of .extended operation and is discussed in Section B.1.3.

• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating E?<perience The Metal-Enclosed Bus Program is a new program for which there is no direct specific operating experience.

Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation. Plant operating experience has shown that the corrective action program has addressed issues related to bus and bus enclosure degradation in recent years. For example, corrosion was identified on insulators used to support bus associated with the unit normal auxiliary transformer (which is not in scope for license renewal). In addition, the corrective action program noted that the use of thermography would provide an improvement to the bus preventive maintenance program. Industry operating experience will be included in the development of this program. Required Enhancements Not applicable, this is a new program. Conclusion The Metal-Enclosed Bus Program will manage aging degradation for bus. The Metal-Enclosed Bus Program will provide reasonable assurance that the aging effects will be managed such that metal-enclosed bus subject to aging management review will continue to perform its intended functions consistent with the current licensing basis for the period of extended operation: Aging Management Programs ( Page 8-158 January 2010

• Columbia Generating Station License Renewal Application Technical Information B.2.41 Monitoring and Collection Systems Inspection Program Description The Monitoring and Collection Systems Inspection is a new one-time inspection that will detect and characterize the conditions on the internal surfaces of subject mechanical components that are exposed to equipment and area drainage water and other potential contaminants and fluids. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to crevice, galvanic, general, or pitting corrosion, erosion, or MIC has occurred.

The inspection also provides direct evidence as to whether, and to what extent, cracking' due to SCC of susceptible materials in susceptible locations has occurred., Implementation of the Monitoring and Collection Systems Inspection will provide assurance (and confirmation) that the pressure boundary of susceptible safety-related components is maintained consistent with the current licensing basis during the period of extended operation. Implementation of the inspection will also provide assurance (and confirmation) that the structural integrity of susceptible NSR components will be maintained such that spatial interactions (e.g., leakage) will not result in the loss of any safety-related component intended functions during the period of extended operation. NUREG-1801 Consistency The Monitoring and Collection Systems Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The scope of the Monitoring and Collection Systems Inspection includes the internal surfaces of subject mechanical components in the following plant drainage and collection systems that are exposed to potentially radioactive drainage water (untreated water), and in systems with other potential contaminants and fluids during normal plant operations:

• Equipment Drains Radioactive (EDR) System* Floor Drains (FD) System I Aging Management Programs Aging Management Programs Page B-159 January 2010 Page B-1 59 January 2010'. 8.2.41 Monitoring and Collection Systems Inspection Program Description Columbia Generating Station License Renewal Application Technical Information The Monitoring and Collection Systems Inspection is a new one-time inspection that will detect and characterizE!

the conditions on the internal surfaces of subject mechanical components that are exposed to equipment and area drainage water and other potential contaminants and fluids. The inspection provides direct evidence as to whether, and to what extent, a loss of material due to crevice, galvanic, general, or pitting corrosion, erosion, or MIC has occurred. The inspection also provides direct evidence as to whether, and to what extent, cracking' due t6 SCC of susceptible materials in susceptible locations has occurred. , Implementation of the Monitoring and Collection Systems Inspection will provide assurance (and confirmation) that the pressure boundary of susceptible safety-related components is maintained consistent with the current licensing basis during the period of extended operation. Implementation of the inspection will also provide assurance (and confirmation) that the structural integrity of susceptible NSR components will be maintained such that spatial interactions (e.g., leakage) will not result in the loss of any safety-related component intended functions during the perio,d of extended operation.

• NUREG-1801 ConsistEmcy
• The Monitoring and Collection Systems Inspection is a 'new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None. Aging Management P"ogram Elements The results of an evaluation of each program element are provided below.
• Scope of Program The scope of the Monitoring and Collection Systems Inspection includes the internal surfaces of subject mechanical components in the following plant drainage and collection systems that are exposed to potentially

'radioactive drainage, water (untreated water), and in systems with other potential contaminants and fluids during normal plant operations:

• Equipment Drains Radioactive (EDR) System
• Floor Drains (FD) System , Aging Management Programs Page 8-159 January 2010 Columbia Generating StationLicense Renewal Application Technical Information
• Floor Drains Radioactive (FDR) System* Fuel Pool Cooling (FPC) System* Miscellaneous Waste Radioactive (MWR) System* Plant Sanitary Drains (PSD) System* Process Sampling Radioactive (PSR) System* Reactor Closed Cooling (RCC)

Water System A representative sample of components in these systems, to be defined in the implementing documents, and to include containment isolation piping and valve bodies, will be examined for evidence of a loss of material (due to crevice, galvanic, general, or pitting corrosion, erosion, or MIC), or to confirm a lack thereof, and the results applied to all of the systems and components within the scope of the inspection, based on engineering evaluation. In addition, the representative sample will include stainless steel components exposed to temperatures greater than 140 OF that will be examined for evidence of cracking due to SCC." Preventive Actions No actions are taken as part of the Monitoring and Collection Systems Inspection to prevent aging effects or to mitigate aging degradation.

• Parameters Monitored or Inspected The parameters to be inspected by the Monitoring and Collection Systems Inspection include wall thickness or visual evidence of internal surface degradation, as measures of a loss of material or cracking in susceptible materials.

Inspections will be performed by qualified personnel using established NDE techniques.

• Detection of Aging Effects The Monitoring and Collection Systems Inspection will use a combination of established volumetric and visual examination techniques (such as equivalent to VT-1 or VT-3) performed by qualified personnel on a sample population of subject components to identify, evidence of loss of material or cracking in susceptible materials or to confirm a lack thereof on the susceptible internal surfaces of the components.

The sample population will be determined by engineering evaluation based on sound statistical sampling methodology, and, where practical, will be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and the lowest design margins.The sample population will include at least one location for containment isolation components. Aging Management Programs Page B-160 January 2010 Columbia Generating Station License Renewal Application

• Technical Information
• Floor Drains Radioactive (FDR) System
• Fuel Pool Cooling (FPC)

System

• Miscellaneous Waste Radioactive (MWR) System
• Plant Sanitary Drains (PSD) System
• Process Sampling Radioactive (PSR) System
• Reactor Closed Cooling (RCC) Water System A representative sample of components in these systems, to be defined in the implementing documents, and to include containment isolation piping and valve bodies, will be examined for evidence of a loss of material (due to crevice, galvanic, general, or pitting corrosion, erosion, or MIC), or to confirm a lack thereof, and the results applied to all of the systems and components within the scope of the inspection, based on engineering evaluation.

In addition, the representative sample will include stainless steel components exposed to temperatures greater than 140 OF that will be examined for evidence of cracking due to SCC.

• Preventive Actions No actions are taken as part of the Monitoring arid Collection Systems Inspection to prevent aging effects or to mitigate aging degradation.
• Parameters Monitored or Inspected The parameters to be inspected by the Monitoring and Collection Systems Inspection include wall thickness or visual evidence of internal surface degradation, as measures of a loss of material or cracking in susceptible materials.

Inspections will be performed by qualified personnel using established NDE techniques.

• Detection of Aging Effects The Monitoring and Collection Systems Inspection will use a combination of established volumetric and visual examination techniques (such as equivalent to VT-1 or VT-3) performed by qualified personnel on a sample population of subject components to identify, evidence of loss .of material or cracking in susceptible materials or to confirm a lack thereof on the susceptible internal surfaces of the components. , . The sample population will be determined by engineering evaluation based on sound statistical sampling methodology, and, where practical, will be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and the lowest design margins. The sample population will include at least one location for containment isolation components.

Aging Management Programs Page 8-160 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information The Monitoring and Collection Systems Inspection activities will be conducted within the 10-year period prior to the period of extended operation.

Monitoring and Trending This one-time inspection activity is used to characterize conditions and determine if, and to what extent, further actions may be required. The activity includes provisions for increasing the inspection sample size and location if degradation is detected.The sample size will be determined by engineering evaluation of the materials of construction, environment (i.e., service conditions), aging effects, and operating experience (e.g., time in-service, most susceptible locations, lowest design margins).Inspection findings that do not meet the acceptance criteria will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and for monitoring and trending of the results.* Acceptance Criteria Indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation.

• Corrective Actions This element is common to Columbia programs and activities that are aging management during the period of extended operation and is Section B.1.3.credited with discussed in* Confirmation Process This element is common to Columbia programs and aging management during the period of extended Section B.1.3." Administrative Controls This element is common to Columbia programs and aging management during the period of extended Section B.1.3.activities that are operation and is credited with discussed in activities that are credited with operation and is discussed inOperating Experience The Monitoring and Collections Systems Inspection is a new one-time inspectionactivity for which plant operating experience has not shown the need to manage the aforementioned aging effects for the in-scope systems. The inspection provides for confirmation of material conditions near the period of extended operation.

The elements comprising the inspection activity are to be consistent with industry practice.Aging Management Programs Page B-161 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information The Monitoring and Collection Systems Inspection activities will be conducted within the 1 O-year period prior to the period of extended operation

..

• Monitoring and Trending This one-time inspection activity is used to characterize conditions and determine if, and to what extent, further actions may be required.

The activity includes provisions for increasing the inspection sample size and location if degradation is detected. The sample size will be determined by engineering evaluation of the materials of construction, environment (i.e., service conditions), aging effects, and operating experience (e.g., time in-service, most susceptible locations, lowest design margins). Inspection findings that do not meet the acceptance criteria will be evaluated using the Columbia corrective action process to determine the need for subsequent aging management activities and for monitoring and trending of the results.

• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria.

If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation .

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended o'peration and is discussed in Section 8.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience The Monitoring and Collections Systems Inspection is a new one-time inspection activity for which plant operating experience has not shown the need to manage the aforementioned aging effects for the in-scope systems. The inspection provides for confirmation of material conditions near the period of extended operation.

The elements comprising the inspection activity are to be consistent with industry practice . Aging Management Programs Page 8-161 January 2010 Columbia Generating Station License Renewal Application Technical Information NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating, experience to date identified an occurrence of loss of material due to corrosion within the FDR System in 2003. The susceptible FDR piping and valves were subsequently re-designed to eliminate standing water and replaced with a corrosion resistant, stainless steel, material in 2005. No additional instances of corrosion have occurred in the FDR System since the. implementation of the modification.The site corrective action program, and an ongoing review of industry operating experience, will be used to ensure that the identified aging effects do not require management for the systems within the scope of this activity.Required Enhancements Not applicable, this is a new activity.Conclusion Implementation of the Monitoring and Collection Systems Inspection will verify that there are no aging effects requiring management for the subject components, or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation, and that spatial interactions (e.g., leakage) will not result in loss of safety-related component intended functions during the period of extended operation. Aging Management Programs Page B-16.2 January 2010 Columbia Generating Station

• License Renewal Application Technical Information NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability; none was identified.

Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating, experience to date identified an occurrence of loss of material due to corrosion within the FOR System in 2003. The susceptible FOR piping and valves were subsequently re-designed to eliminate standing water 'and replaced with a corrosion resistant, stainless steel, material in 2005. No additional instances of corrosion have occurred in the FOR System since the implementation of the modification. The site corrective action program, and an ongoing review of industry operating experience, will be used to ensure that the identified aging effects do not require management for the systems within the scope of this activity. \ Required Enhancements Not applicable, this is a new activity. Conclusion Implementation of the Monitoring and Collection Systems Inspection will verify that there are no aging effects requiring management for the subject components, or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation, and 'that spatial interactions (e.g., leakage) will not result in loss of safety-related component intended functions during the period of extended operation. Aging Management Programs Page 8-162 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information B.2.42 Open-Cycle Cooling Water ProgramProgram Description The Open-Cycle Cooling Water Program manages loss of material due to crevice, galvanic, general, pitting, and MIC, and erosion for components located in the Standby Service Water and Plant Service Water systems, and components connected to or serviced by those systems, and in the Tower Makeup Water and Circulating Water systems. The program also manages fouling due to particulates (e.g., corrosion products) and biological material (micro- and macro-organisms) resulting in reduction in heat transfer for heat exchangers within the scope of the program. In addition, the program manages cracking for copper alloy > 15% Zn components in the Process Sampling System and for aluminum components in the HVAC systems that are subject to condensation.The Open-Cycle Cooling Water Program consists of inspections, surveillances, and testing to detect the presence, and assess the extent, of fouling, loss of material, and cracking, combined with chemical treatments and cleaning activities to minimize fouling, loss of material, and cracking. The existing program is a combination condition monitoring and mitigation program that implements the recommendations of NRC GL 89-13, "Service Water System Problems Affecting Safety-Related Equipment." NUREG-1801 Consistency The Open-Cycle Cooling Water Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801 Section XI.M20, "Open-Cycle Cooling Water System," with exceptions..Exceptions to NUREG-1801 Program Elements Affected:* Preventive Actions -NUREG-1801 states that system components are lined or coated to protect underlying metal surfaces from being exposed to aggressive cooling water environments.

Protective coatings on the inner walls are not used in the service water systems that are within the scope of license renewal at Columbia.Monitoring and Trending -NUREG-1801 states that testing and inspections are performed annually andduring refueling outages. Inspection frequencies for the Open-Cycle Cooling Water Program are based on operating conditions and past history; flow rates, water quality, lay-up, and heat exchanger design.Aging Management Programs Aging Management Programs Page B-163 January2010 Page B-163 I January 2010* *

• 8.2.42 Open-Cycle Cooling Water Program Program Description Columbia Generating Station License Renewal Application Jechnicallnformation The Open-Cycle Cooling Water Program manages loss of material due to crevice, galvanic, general, pitting, and MIC, and erosion for components located in the Standby Service Water and Plant Service Water systems, and components connected to or serviced by those systems, and in the Tower Makeup Water and Circulating Water systems. The program also manages fouling due to particulates (e.g., corrosion products) and biological material (micro-and macro-organisms) resulting in reduction in heat transfer for heat exchangers within the scope of the program. In addition, the program manages cracking for copper alloy > 15% Zn components in the Process Sampling System and for aluminum components in the HVAC systems that are subject to condensation.

The Open-Cycle Cooling Water Program consists of inspections, surveillances; and testing to detect the presence, and assess the extent, of fouling, loss of material, and cracking, combined with chemical treatments and cleaning activities to minimize fouling, loss of material, and cracking. The existing program is a combination condition monitoring and mitigation program that implements the recommendations of NRC GL 89-13, "Service Water System Problems Affecting Safety-Related Equipment." NUREG-1801 Consistency The Open-Cycle Cooling Water Program is an eXisting Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801 Section XI.M20, "Open-Cycle Cooling Water System," with exceptions. Exceptions to NUREG-1801 Program Elements Affected:

• Preventive Actions -NUREG-1801 states that system components are lined or coated to protect . underlying metal surfaces from being exposed to aggressive cooling water environments

.. Protective coatings on the inner walls are not used in the service water systems that are within the scope of license renewal at Columbia.

• Monitoring and Trending -NUREG-1801 states that testing and inspections are performed annually and during refueling outages. Inspection frequencies for the Open-Cycle Cooling Water Program are based on operating conditions and past history; flow rates, water quality, lay-up, and heat exchanger design . Aging Management Programs Page 8-163 J January 2010 Columbia Generating Station License Renewal Application Technical Information Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program element: " Scope -Address loss of material due to cavitation erosion (for the Standby Service Water (SW), Circulating Water (CW), Plant Service Water (TSW), and Tower Make-Up (TMU) systems) with activities such as opportunistic inspections of portions of the systems that have had indications of cavitation erosion in the past.* Scope -Include the NSR components within the license renewal scope in the SW, CW, TSW, and TMU systems, and the NSR components served by or connected to the TSW System that are in the following plant systems:* Process Sampling (PS) System* Process Sampling Radioactive (PSR) System* Radwaste Building Mixed Air (WMA) System 0 Radwaste Building Return Air (WRA) System* Reactor Building Return Air (RRA) System* Reactor Closed Cooling Water'(RRC)

System Operating-Experience The Open-Cycle Cooling Water Program is an ongoing program that has implemented the recommended actions of NRC GL 89-13 and has justified any alternatives to those recommendations. The health of the program and corresponding systems are periodically reported, including chemistry trends and material conditions. Industry operating experience is evaluated for impact to Columbia, and periodic self assessments are conducted. As a result, Columbia has programs in place with operating experience to demonstrate that the effects of aging on the service water systems, and on the safety-related heat exchangers that they serve, as well as on the plant service water systems and NSR heat exchangers they serve, will be effectively managed during the period of extended operation. In addition, annual ultimate heat sink and spray pond performance, as well as related GL 89-13 systems, components, and controls, is a subject of NRC integratedinspection. In recent years, reviews were performed by NRC inspectors to verify the acceptability of test methods and conditions, acceptance criteria, use of instrument Aging Management Programs Aging Management Programs Page 8-164 January 2010 Page B-1 64 January 2010 Required Enhancements Columbia Generating Station License Renewal Application Technical Information Prior to the period of extended operation the enhancements listed below will be implemented in the identified program element:

• Scope-Address loss of material due to cavitation erosion (for the Standby Service Water (SW), Circulating Water (CW), Plant Service Water (TSW) , and Tower Make-Up (TMU) systems) with activities such as opportunistic inspections of portions of the systems that have had indications of cavitation erosion in the past.
• Scope-Include the NSR components within the license renewal scope in the SW, CW, TSW, and TMU systems, and the NSR components served by or connected to the TSW System that are in the following plant systems:
• Process Sampling (PS) System
• Process Sampling Radioactive (PSR) System
• Radwaste Building Mixed Air (WMA) System
• Radwaste Building Return Air (WRA) System
• Reactor Building Return Air (RRA) System
• Reactor Closed Cooling Water '(RRC) System Operating Experience The Open-Cycle Cooling Water Program is an ongoing program that has implemented the recommended actions of NRC GL 89-13 and has justified any alternatives to those recommendations.

The health of the program and corresponding systems are periodically reported, including chemistry trends and material conditions. Industry operating experience is evaluated for impact to Columbia, and periodic self assessments are conducted. As a result, Columbia has programs in place with operating experience to demonstrate that the effects of aging on the service vyater systems, and on the safety-related heat exchangers that they serve, as well as on the plant service yvater systems and NSR heat exchangers they serve, will be effectively managed during the period of extended operation. In addition, annual ultimate heat sink and spray pond performance, as well as related GL 89-13 systems, components, and controls, is a subject of NRC integrated inspection. In recent years, reviews were performed* by NRC inspectors to verify the acceptability of test methods and conditions, acceptance criteria, use of instrument Aging Management Programs Page 8-164 January 2010 ** *

• Columbia Generating Station License Renewal Application Technical Information uncertainties, frequency of testing, biofouling controls, -compliance with design parameters, and the extrapolation of test data to design conditions.

No findings of significance with respect to the effectiveness of the existing program were identified during these integrated inspections. Furthermore, a review of plant-specific operating experience has identified several instances of damage due to erosion, designated as cavitation erosion. There have been repeated instances of leaks and failures in the SW System, which were cavitation-related. The design and operational adjustments have not fully precluded subsequent cavitation-related failures. That is, design and operational adjustments have corrected the issues sufficient to support continued operation of the plant, but have not fully eliminated the occurrence of cavitation erosion in the service water or attached systems. Therefore, in the course of normal operation during the period of extended operation, it is plausible that cavitation erosion could have the same effect as other forms of erosion (e.g., particulate) in the raw water environment of the service water and attached systems.Conclusion The Open-Cycle Cooling Water Program will detect and manage loss of material and reduction in heat transfer for susceptible components in raw water envir6nments. The Open-Cycle Cooling Water Program, with the required enhancements, provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-165 January 2010 Aging Management Programs Page B-165 January 2010* *

• Columbia Generating Station License Renewal Application Technical*lnformation uncertainties, frequency of testing, biofouling controls, 'compliance with design parameters, and the extrapolation of test data to design conditions.

No findings of significance with respect to the effectiveness of the existing program were identified during these integrated inspections. Furthermore, a review of plant-specific operating experience has identified several instances of damage due to erosion, designated as cavitation erosion. There have been repeated instances of leaks and failures in the SWSystem, which were related. The design and operational adjustments have not fully precluded subsequent cavitation-related failures. That is, design and operational adjustments have corrected the issues sufficient to support continued operation of the plant, but have not fully eliminated. the occurrence of cavitation erosion in the service* water or attached systems. Therefore, in the course of normal operation during the period of extended operation, it is plausible that cavitation erosion could have the same effect as other forms of erosion (e.g., particulate) in the raw water environment of the service water and attached systems. Conclusion The Open-Cycle Cooling Water Program will detect and manage loss of material and reduction in heat transfer for susceptible components in raw water environments. The Open-Cycle Cooling Water Program, with the required enhancements, provides reasonable assurance that the aging effects will be managed such that components subject to aging review will continue to peiiorm their intended functions consistent with the licensing basis for the period of extended operation . Aging Management Programs Page 8-165 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.43 Potable Water Monitoring Program Program Description The Potable Water Monitoring Program mitigates damage due to loss of material due to corrosion and erosion for components that contain potable water and are within the scope of license renewal to ensure that the integrity of piping and components is maintained. The Potable Water Monitoring Program is an existing mitigation program that is comprised of water treatment activities, including flocculation, sedimentation, filtration, and chemical addition.Prior to the period of extended operation, the Potable Water Monitoring Program will be enhanced to include periodic inspection activities to provide additional confirmation that the integrity of piping and components will be maintained for the period of extended operation. As such, the Potable Water Monitoring Program will be a combination mitigation and condition monitoring program. At least one inspection will be conducted within the 10-year period prior to the period of extended operation. NUREG-1801 Consistency The Potable Water Monitoring Program is an existing Columbia program, with required enhancements, that is plant-specific. There is no corresponding aging management program described in NUREG-1801. Aging Management Program Elements The results of an evaluation of each program element are provided below.* Scope of Program The Potable Water Monitoring Program is credited for managing loss of material for aluminum, copper alloy, copper alloy > 15% Zn, gray cast iron, and steel components that are exposed to potable water in the following systems:* Reactor Building Outside Air (ROA) System* Potable Cold Water (PWC) System* Potable Hot Water (PWH) System* Preventive Actions The Potable Water Monitoring Program is an existing mitigation program comprised of water treatment activities, including flocculation, sedimentation, filtration, and chemical addition.Aging Management Programs Page B-166 January 2010 Aging Management Programs Page B-166 January 2010 8.2.43 Potable Water Monitoring Program Program Description Columbia Generating Station License Renewal Application Technical Information The Potable Water Monitoring Program mitigates damage due to loss of materia I due to corrosion and erosion for components that contain potable water and are within the scope of license renewal to ,ensure that the integrity of piping and components is maintained. The Potable Water Monitoring Program is an existing mitigation program that is comprisedbf water treatment activities, including flocculation, sedimentation, filtration, and chemical addition. Prior to the period of extended operation, the Potable Water Monitoring Program will be enhanced to include periodic inspection activities to provide additional confirmation that the integrity of piping and components will be maintained for the period of extended operation. As such, the Potable Water Monitoring Program will be a combination mitigation and condition monitoring program. At least one inspection will be conducted within the 10-year period prior to the period of extended operation. NUREG-1801 Consistency The Potable Water Monitoring Program is an existing Columbia program, with required

• enhancements, that is plant-specific.

There is no corresponding aging management

• ) program described in NUREG-1801.

Aging Management Program Elements The results of an evaluation of each program element are provided below.

• Scope of Program . The Potable Water Monitoring Program is credited for managing loss of material for aluminum, copper alloy, copper alloy > 15% Zn, gray cast iron, and steel components that are exposed to potable water in the following systems:
• Reactor Building Outside Air (ROA) System
• Potable Cold Water (PWC) System
• Potable Hot Water (PWH) System
• Preventive Actions The Potable Water Monitoring Program is an existing mitigation program comprised of water treatment activities, including flocculation, sedimentation, filtration, and chemical addition.

Aging Management Programs Page 8-166 January 2010

• Columbia Generating Station License Renewal Application Technical Information
• Parameters Monitored or Inspected The Potable Water Monitoring Program monitors the water treatment plant performance and the overall status of the potable water system, including water quality." Detection of Aging Effects The Potable Water Monitoring Program will be enhanced to use a combination of established volumetric and visual examination techniques performed by qualified personnel on locations within the PWC, PWH, and ROA systems, as determined by engineering evaluation, to identify evidence of a loss of material, or to confirm a lack thereof. At least one inspection will be conducted Within the 10-year period prior to the period of extended operation.

Based on operating experience, it is necessary that inspections be conducted at least once every five years, and include components of the PWC and PWH systemsthat are located in the Reactor Building, and components associated with the ROA\ air washer (ROA-AW-1), inclubing the air washer housing.* Monitoring and Trending The Potable Water Monitoring Program monitors the water treatment plant performance and the overall status of the potable water system, including water, quality, and the results are recorded and trended.* Acceptance Criteria The acceptance criteria for potable water system inspections are: indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation. Acceptance criteria have been established for potable water quality, which minimizes the presence of impurities that could cause degradation. Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Aging Management Programs Page B-167 January 2010 Aging Management Programs Page B-167 January 2010* * *

• Parameters Monitored or Inspected The Potable Water Monitoring Program performance and the overall status of the quality. Columbia Generating Station License Renewal Application Technical Information monitors the water treatment plant potable water system, including water
• Detection of Aging Effects _ _ The Potable Water Monitoring Program will be enhancecj to use a combination of established volumetric and visual examination techniques performed by qualified personnel on locations within the PWC, PWH, and ROA systems, as determined by* engineering evaluation, to identify evidence of a loss of material, or to confirm a lack thereof. At least one inspection will be conducted within the 10-year period prior to the period of extended operation.

Based on operating experience, it is necessary that inspections be conducted at least once every five years, and include components of the PWC and PWH systems that are located in the Reactor Building, and components associated with the ROA \ air washer (ROA-AVV-1), incluCting the air washer housing.

• Monitoring and Trending The Potable Water Monitoring Program monitors the water treatment plant performance and the overall status of the potable water system, including water quality, and the results are recorded and trended.
• Acceptance Criteria The acceptance criteria for potable water system inspections are: indications or relevant conditions of degradation detected during the inspection will be compared to pre-determined acceptance criteria.

If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective action program to determine whether they could result in a loss of component intended function during the period of extended operation. Acceptance criteria have been established for potable water quality, which minimizes the of impurities that could cause degradation.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management:

during the period of extended operation and is discussed in Section B.1.3.

• Confirmation Process element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3 .. Aging Management Programs Page 8-167 January 2010 Columbia Generating StationLicense Renewal Application Technical Information Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Operating Experience As revealed by the operating experience review, corrosion and subsequent system leakage has been a recurring problem in the Columbia potable water systems.These problems have been detected, and components have been isolated and repaired or replaced in a timely manner, in accordance with the corrective action program. None of the system leakage problems have occurred in portions of the systems that are within the Reactor Building where they could affect safety-related equipment due to leakage or spray. The majority of the leaks have been in the yardloop piping which is external to the power block structures and is buried. This piping is PVC material which makes it susceptible to leaks due to changes in temperature related to location and environment.

The piping in the Reactor Building is not exposed to the same environment (i.e., indoor air 'not soil) and is not of the same material (i.e., is metallic not PVC).Required Enhancements Prior to the period of extended operation the enhancements listed below will be implemented in the identified program element: Detection of Aging Effects -Include periodic inspection activities. Based on operating experience, it is necessary that inspections be conducted at least once every five years, and include components of the PWC and PWH systems that are located in the Reactor Building, and components associated with the ROA air washer (ROA-AW-1), including the air washer housing.Conclusion The Potable Water Monitoring Program, supplemented by at least one inspection prior to entering the period of extended operation, and with the required enhancements, provides reasonable assurance that the aging effects will be managed such that.components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-168.January 2010 i

• Administrative Controls.

Columbia Generating Station License Renewal Application Technical Information This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.

• Operating Experience As revealed by the operating experience review, corrosion and subsequent system leakage has been a recurring problem in the' Columbia potable water systems. These problems have been detected, and components have been isolated and repaired or replaced in a timely manner, in accordance with the corrective action program. None of the system leakage problems have occurred in portions of the systems that are within the Reactor Building where they could affect safety-relate(j equipment due to leakage or spray. The majority of the leaks have been in the yard loop piping which is external to the power block structures and is buried. This piping is PVC material which makes it susceptible to leaks due to changes in temperature related to location and environment.

The piping in the Reactor Building is not exposed to the same environment (i.e., indoor air not soil) and IS not of the same material (i.e., is metallic not PVC). Required Enhancements

• Prior to the period of extended operation the enhancements listed below will be
• implemented in the identified program element:
• Detection of Aging Effects -Include periodic inspection activities.

on operating experience, it is necessary that inspections be conducted at least once every five years, and include components of the PWC and PWH systems that are located in the Reactor Building, and components associated with the ROA air washer (ROA-AW-1), including the air washer housing. . Conclusion The Potable Water Monitoring Program, supplemented by at least one inspection prior to entering the period of extended operation, and with the required enhancements, provides reasonable assurance that the aging effects will be managed such that , components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-168 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information B.2.44 Preventive Maintenance

-RCIC Turbine Casing Program Description The Preventive Maintenance -RCIC Turbine Casing manages loss of material due to general corrosion on the internal surfaces of the Reactor Core Isolation Cooling (RCIC)pump turbine casing..and associated piping and piping components downstream from the steam admission valve. Preventive Maintenance -RCIC Turbine Casing is acondition monitoring activity comprised of periodic inspection and surveillance activities to detect aging and age-related degradation. NUREG-1801 Consistency Preventive Maintenance -RCIC Turbine Casing is an existing Columbia program that is plant-specific. There is no corresponding aging management program described in NUREG-1 801.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program Preventive Maintenance -RCIC Turbine Casing is credited for managing loss of material due to general corrosion on the internal steel surfaces in the RCIC pump turbine casing and the in-scope piping and piping components in steam lines downstream~from the steam admission valve. These components are exposed to steam during RCIC system operation and testing and to an ambient air internal environment during normal plant operation. The ambient (untreated, moist) air internal environment is a result of steam having either condensed and drained to the barometric condenser or vented to the suppression chamber (drywell). Inspections are focused on the casing with the results applying to the other associated components because of the similarities in materials and environment. For example, if inspection results indicate an absence of general corrosion on the turbine casing, then general corrosion would not be expected on any of the other susceptible components. Preventive Actions Preventive Maintenance -RCIC Turbine Casing does not include.any actions to prevent or mitigate the effects of aging.Parameters Monitored or Inspected Preventive Maintenance -RCIC Turbine Casing inspects the internal steel surfaces of the RCIC pump turbine casing for signs of degradation (leakage, pitting, corrosion, etc.) that might be indicative of loss of material.Aging Management Programs Page B-169 January 2010* *

• 8.2.44 Preventive Maintenance

-RCIC Turbine Casing. Program Description Columbia Generating Station License Renewal Application . Technical Information The Preventive Maintenance -RCIC Turbine Casing manages loss of material due to general corrosion on internal surfaces of the Reactor Core Isolation Cooling (RCIC) pump turbine casing .. and associated piping and piping components downstream from the steam admission valve. Preventive Maintenance -RCIC Turbine Casing is a condition monitoring activity comprised of periodic inspection and surveillance activities to detect aging and age-related degradation: NUREG-1801 ConsistE!ncy Preventive -RCIC Turbine Casing is an existing Columbia program that is plant-specific. There is no corresponding aging management program described in NUREG-1801. Aging Management Program Elements The results of an evaluation of each program element are provided below .

• Scope of Program Preventive Maintenance

-RCIC Turbine Casing is credited for managing loss of material due to general corrosion on the internal steel surfaces in the RCIC pump turbine casing and the in-scope piping and piping components in steam lines downstream' from the steam admission valve. These components are exposed to steam during RCIC system operation and testing and to an ambient air internal environment during normal plant operation. The ambient (untreated, moist) air internal environment is a result of steam having either condensed and drained to the barometric condenser or vented to the suppression chamber (drywell). Inspections are focused on the casing with the results applying to the other associated components because of the similarities in materials and environment. For example, if inspection results indicate an absence of general corrosion on the turbine casing, then general corrosion would not be expected on any of the other susceptible components.

• Preventive Actions Maintenance

-RCIC Turbine Casing does not include any actions to prevent or mitigate the effects of aging. . .

• Parameters Monitored or Preventive Maintenance

-RCIC Turbine Casing inspects the internal steel surfaces . of the RCIC pump turbine casing for signs of degradation (leakage, pitting, corrosion, etc.) thatmight be indicative of loss of material. I Aging Management Programs . Page 8-169 January 2010 Columbia Generating Station License Renewal Application Technical Information

• Detection of Aging Effects In accordance with the information provided in the Monitoring and Trending element, Preventive Maintenance

-RCIC Turbine Casing detects loss of material prior to any loss of component intended function.* Monitoring and Trending Preventive Maintenance -RCIC Turbine Casing is a condition monitoring activity that is performed by qualified individuals at established intervals to identify. internal degradation of the turbine casing through visual inspection. If unacceptable deterioration is noted during the internal inspection of the turbine casing, the inspection results will be evaluated through the corrective action program.* Acceptance Criteria The acceptance criteria for Preventive Maintenance -RCIC Turbine Casing are no unacceptable visual indications of loss of material. Unacceptable indications are those that are determined by engineering evaluation to degrade the components to such an extent that they may not be capable of performing their intended function (pressure boundary integrity) until the next scheduled inspection." Corrective Actions This element is common to Columbia programs and aging management during the period of extended.Section B.1.3.* Confirmation Process This element is common to Columbia programs and aging management during the period of extended Section B.1.3." Administrative Controls This element is common to Columbia programs and aging management during the period of extended Section B.1.3.activities that are credited with operation and is discussed in activities that are credited with operation and is discussed in activities that are credited with operation and is discussed in Operating Experience The elements that comprise Preventive Maintenance -RCIC Turbine Casing are consistent with industry practice and have proven effective in maintaining the material condition of the RCIC pump turbine, including the casings.A review of the most recent work order documentation for the turbine internalinspections reveals that RCIC turbine casing inspections are performed in accordance with procedure, results are documented and retrievable, and that, if degradation is indicated, corrective actions are taken. A review of the most recent plant-specific operating experience, through a search of condition reports, revealed Aging Management Programs Page B-170 January 2010 Columbia Generating Station License Renewal Application , Technicallnformation

• Detection of Aging Effects , In accordance with the information provided in the Monitoring and Trending element, Preventive Maintenance

-RCIC Turbine Casing detects loss of material prior to any loss of component intended function.

• Monitoring and Trending Preventive Maintenance

-RCIC Turbine Casing is a condition monitoring activity that is performed by qualified individuals at established intervals to identify. internal degradation of the turbine casing through visual inspection. If unacceptable deterioration is noted during the internal inspection of the turbine casing, the inspection results will be evaluated through the corrective action program.

• Acceptance Criteria The acceptance criteria for Preventive Maintenance

-RCIC Turbine Casing are no unacceptable visual indications of loss of material. Unacceptable indications are those that are determined by engineering evaluation to degrade the components to such an extent that they may not be capable of performing their intended function (pressure boundary integrity) until the next scheduled inspection.

• Corrective Actions
• This element is common to Columbia programs and activities that are credited with
• aging management during the period of extended.

operation and is discussed in Section 8.1.3.

• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. .
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience The elements that comprise Preventive Maintenance

-RCIC Turbine Casing are consistent with industry practice and have proven effective in maintaining the material condition of the RCIC pump turbine, including the casings. A review of the most recent work order documentation for* the turbine internal inspections reveals that RCIC turbine casing inspections are' performed in accordance with procedure, results are documented and retrievable, and that, if degradation is indicated, corrective actions are taken. A review of the most recent plant-specific operating experience, through a search of condition reports, revealed Aging Management Programs Page 8-170 January 2010

• Columbia Generating Station License Renewal Application Technical Information that no loss of pressure boundary integrity has occurred that was, or could, have been, attributed to the aging effects that are in the scope of the program. Some minor leakage was identified that was corrected and the material condition was monitored, as indicated in the system health reports for 2007, to ensure that no further degradation or loss of function occurred.

Other issues in the system health reports for 2008 involve valve seat and packing leakage, which are issues that are not within the scope of license renewal.Required Enhancements None.Conclusion Preventive Maintenance -RCIC Turbine Casing will detect and manage loss of material. The continued implementation of Preventive Maintenance -RCIC Turbine Casing provides reasonable assurance that the effects of aging will be managed such that components subject to aging management will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Aging Management Programs Page 8-171 January 2010 Page B-171 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information that no loss of pressure boundary integrity has occurred that was, or could have been, attributed to the aging effects that are in the scope of the' program. Some minor leakage was identified that was corrected and the material condition was monitored, as indicated in the system health reports for 2007, to ensure that no further degradation or loss of funct.ion occurred.

Other issues in the system health reports for 2008 involve valve seat and packing leakage, which are issues that are not within the scope of license renewal. Required Enhancements None. Conclusion Preventive Maintenance -RCIC Turbine Casing will detect and manage loss of material. The continued implementation of Preventive Maintenance -RCIC Turbine Casing provides reasonable assurance that the effects of aging will be managed such that components subject to aging management will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. \ Aging Management Programs Page 8-171 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.45 Reactor Head Closure Studs Program Program Description The Reactor Head Closure Studs Program manages cracking due to SCC and loss of material due to corrosion for the reactor head closure stud assemblies (studs, nuts, washers, and bushings.) The Reactor Head Closure Studs Program examines reactor vessel stud assemblies in accordance with the examination and inspection requirements specified in Table IWB-2500-1. The program includes visual and volumetric examinations in accordance with the general requirements of Subsection IWA-2000. Inspections include VT-1 visual examination of the nuts, washers, and bushing and volumetric examination of studs and threads. VT-2 inspections for leak detection are performed during system pressure tests. The inspection of the reactor vessel closure studs, performed in accordance with ASME-Code, Section XI, Subsection IWB, Table IWB 2500-1 (2003 addenda), includes volumetric examinations rather than the surface examinations called out in paragraphNB-2545 or NB-2546 of Section III of the ASME Code.The ultimate tensile stress for the Columbia studs and nuts (SA-540 Grade B23 or B24)is less than the 170 ksi limitation in Regulatory Guide 1.65 and are therefore bounded by the NUREG-1801 program. There are no metal platings applied to the Columbia closure studs, nuts, or washers. A phosphate coating is applied to threaded areas of studs and nuts and bearing areas of nuts and washers to act as a rust inhibitor and to assist in retaining lubricant on these surfaces.The Reactor Head Closure Studs Program includes the preventive measures of RG 1.65 to mitigate cracking, including the use of a stable lubricant. The Reactor Head Closure Studs Program credits portions of the Inservice Inspection (ISI) Program.NUREG-1801 Consistency The ReactorHead Closure Studs Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M3, "Reactor Head Closure Studs." Exceptions to NUREG-1801 None.Required Enhancements None.Aging Management Programs Page B-1 72 January 2010 Columbia Generating Station License Renewal Application

• Technical Information 8.2.45 Reactor Head Closu're Studs Program Program Description The Reactor Head Closure Studs Program manages cracking due to SCC and loss of material due to corrosion for the reactor head closure stud assemblies (studs, nuts, washers, and bushings.)

The Reactor Head Closure Studs Program examines reactor vessel stud assemblies in accordance with the examination and inspection requirements specified in Table IWB-2500-1. The program includes visual and volumetric examinations in accordance with the general requirements of Subsection IWA-2000. Inspections include VT-1 visual examination of the nuts, washers, and bushing and volumetric examination of studs and threads. VT-2 inspections for leak detection are performed during system pressure tests. The inspection of the reactor vessel closure studs, performed in accordance with ASME'Code, Section XI, Subsection IWB, Table IWB 2500-1 (2003 addenda), includes volumetric examinations rather than the surface examinations called out in paragraph NB-2545 or NB-2546 of Section III of the ASME Code. The ultimate tensile stress for the Columbia studs and nuts (SA-540 Grade B23 or B24) is less than the 170 ksi limitation in Regulatory Guide 1.65 and are therefore bounded by the NUREG-1801 program. There are no metal platings applied to the Columbia

• closure studs, nuts, or washers. A phosphate coating is applied to threaded areas of studs and nuts and bearing areas of nuts and washers to act as a rust inhibitor and to assist in retaining lubricant on these surfaces.

The Reactor Head Closure Studs Program includes the preventive measures of RG 1.65 to mitigate cracking, including the use of a stable lubricant. The Reactor Head Closure Studs Program credits portions of the Inservice Inspection (lSI) Program. NUREG-1801 Consistency The Reactor, Head Closure Studs Program is an existing Columbia program that is consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M3, "Reactor Head Closure Studs." Exceptions to NUREG-1801 None. Required Enhancements None. Aging Management Programs Page 8-172 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation.

Industry operating experience: NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Stress corrosion cracking has occurred in other BWR reactor head closure studs as described in a GE service information letter.The Reactor Head Closure Studs Program detects aging effects using nondestructive examination (NDE) visual, surface and volumetric techniques to detect and characterize flaws. These techniques are widely used and have been demonstrated effective at detecting aging effects during inspections performed to meet ASME Section Xl Code requirements. A review of operating experience in recently submitted License Renewal Applications includes the following.

• Surface examination of RPV studs and nuts in 2001 at Cooper Nuclear Station during RE20 identified a recordable indication for RPV nuts, two non-recordable indications for RPV studs and a non-recordable for RPV washers.The recordable indication was evaluated as satisfactory.
• Duane Arnold Energy Center has had no recordable indications reported for the RPV stud and nut inspections as required by the ASME Section XI." Crystal River reports no cracking or loss of material for the Unit 3 Closure Head Stud Assembly. There have been no aging effects identified that have been attributed to wear, loss of material or stress-corrosion cracking.* Palo Verde reported no cracking due to SCC or IGSCC for PVNGS reactorvessel studs, nuts, flange stud holes, or washers.Industry operating experience will be considered when implementing this program.

Plant operating experience for this program will be gained as it is implemented during the period of extended operations, and will be factored into the program. As such, operating experience assures that implementation of the Reactor Head Closure Studs Program will manage the effects of aging such that applicable components will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-173 January 2010* *

• Operating Experience Columbia Generating Station License Renewal Application Technical Information Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation.

Industry operating experience: NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Stress corrosion cracking has occurred in other BWR reactor head closure studs as described in a GE service information letter. The Reactor Head Closure Studs Program detects aging effects using nondestructive examination (NDE) visual, surface and volumetric techniques to detect and characterize flaws. These techniques are widely used and have been demonstrated effective at detecting aging effects during inspections performed to meet ASME Section XI Code requirements. A review of operating experience in recently submitted License Renewal Applications includes the following. . * . Surface examination of RPV studs and nuts in 2001 at Cooper Nuclear Station RE20 identified a recordable indication for RPV nuts, two recordable indications for RPV studs and a non-recordable for RPV washers. The recordable indication was evaluated as satisfactory.

• Duane Arnold Energy Center has had no recordable indications reported for the RPV stud and nut inspections as required by the ASME Section XI.
• Crystal River reports no cracking or loss of material for the Unit 3 Closure Head Stud Assembly.

There have been no aging effects identified that have been attributed to wear, loss of material or stress-corrosion*cracking.

• Palo Verde reported no cracking due to SCC or IGSCC for PVNGS reactor vessel studs, nuts, flange stud holes, or washers. Industry operating experience will be considered when implementing this program. Plant operating experience for this program will be gained as it is implemented during the period of extended operations, and will be factored into the program. As such, operating experience assures that implementation of the Reactor Head. Closure Studs Program will manage the effects of aging such that applicable components will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation . Aging Management Programs Page 8-173 . January 2010 Columbia Generating Station License Renewal Application Technical Information Columbia operating experience:.

Review of Columbia operating experience (condition reports, work orders, etc.) has not revealed any reactor head closure stud cracking or loss of material. The existing program is adequately managing the aging of the reactor head closure studs to maintain the intended function, and will continue to do so for the period of extended operation. The Reactor Head Closure Studs Program has been developed based on relevant plant and industry operating experience. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the new program is effective in managing the identified aging effects.Conclusion The Reactor Head Closure Studs Program manages cracking and loss of material for the reactor head closure stud assemblies. The Reactor Head Closure Studs Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-174 I January 2010 Columbia Generating Station License Renewal Application

• Technical Information Columbia operating experience:.

Review of Columbia operating experience (condition reports, work orders, etc.) has not revealed any reactor head closure stud cracking or loss of material. The existi(lg program is adequately managing the aging of the reactor head closure studs to maintain the intended function, and will continue to do so for the period of extended operation. The Reactor Closure Studs Program has been developed based on relevant plant and industry operating experience. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the new program is effective in managing the identified aging effects. Conclusion The Reactor Head Closure Studs Program manages cracking and loss of material for the reactor head closure stud assemblies. The Reactor Head Closure Studs Program provides reasonable assurance that the aging will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page 8-174 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information B.2.46 Reactor Vessel Surveillance ProgramProgram Description The Reactor Vessel Surveillance Program manages the reduction of fracture toughness due to radiation embrittlement for the low alloy steel reactor vessel shell and welds in the beltline region. The! Reactor Vessel Surveillance Program is a condition monitoring program developed in response to 10 CFR 50 Appendix H.The Columbia program is part of the BWRVIP Integrated Surveillance Program (ISP)that includes multiple BWR vessels. The BWRVIP ISP is an NRC-approved program that appropriately implements the requirements of Appendix H to 10 CFR Part 50.Testing and reporting done by the BWRVIP ISP is performed in accordance with the requirements of ASTM E 185 (1982). The NRC has approved the use of the BWRVIP ISP in place of a unique plant program for Columbia.

The BWRVIP ISP has been revised for License Renewal; as documented in BWRVIP-116, to ensure representative capsules are irradiated to fluence levels corresponding to the end of the period of extended operation. The BWRVIP ISP uses material surveillance capsules in BWR plants, as well as supplemental capsules irradiated in host plants, to provide data which bounds all operating BWR plants. No surveillance capsules from Columbia are included in the BWRVIP ISP; however, the Columbia surveillance, capsules will continue to be maintained in the reactor vessel in standby (deferred) status as required by the ISP.Capsules from host plants will be removed and tested in accordance with the ISP implementation plan defined in BWRVIP-86-A. Results from these tests that are applicable to Columbia will provide the necessary data to monitor embrittlement for the Columbia reactor pressure vessel (RPV). EN will apply the results of the ISP capsule testing to Columbia.The neutron fluence values used for the projections of neutron embrittlement effects are determined using NRC.-approved methodology. The exposure conditions of the reactor vessel are monitored to ensure that they continue to be consistent with those used to project the effects of embrittlement to the end of the license term. If the reactor vessel exposure conditions (neutron flux, spectrum, irradiation temperature, etc.) are altered, then the basis for the projection to 60 years is reviewed; and, if deemed appropriate, arevised fluence projection is prepared and the effects of the revised fluence analysis on neutron embrittlement calculations will be evaluated.The determination of neutron embrittlement effects for Columbia fully complies with NRC Regulatory Guide 1.99, Revision 2. Projections for neutron embrittlement effects have been adjusted to account for the specific nickel and copper contents of the Columbia materials. The extent of reactor vessel embrittlement for upper-shelf energy (USE) and adjusted reference temperature for nil-ductility transition (ART) is projected for 60 years in accordance with Regulatory Guide 1.99, Revision

2. These projections Aging Management Programs Page B-175 January 2010* \ *

• B.2.46 Reactor Vessel Surveillance Program Program Description Columbia Generating Station License Renewal Application Technical Information The Reactor Vessel Surveillance Program manages the reduction of fracture toughness due to radiation embrittlement for the low alloy steel reactor vessel shell and welds in the beltline region. The! Reactor Vessel Program is a condit!on "monitoring program developed in response to 10 CFR 50 Appendix H. The Columbia program is part of the BWRVIP Integrated Surveillance Program (ISP) that includes multiple BWR vessels. The BWRVIP ISP is an NRC-approved program that appropriately implements the requirements of Appendix H to 10 CFR Part 50. Testing and reporting done by the BWRVIP ISP is performed in accordance with the requirements of ASTM E 185 (1982). The NRC has approved the use of the BWRVIP ISP in place of a unique plant program for Columbii;i.

The BWRVIP ISP has been revised for License Renewal; as documented in BWRVIP-116, to ensure representative" capsules are irradiated to fluence levels corresponding to the end of the period of extended operation. The BWRVIP ISP uses material surveillance capsules in BWR plants, as well as supplemental capsules irradiated in host plants, to provide data which bounds all operating BWR plants. No surveillance capsules from Columbia are included in the BWRVIP ISP; the Columbia surveillance' capsules will continue to be maintained in the reactor vessel in standby (deferred) status as required by the ISP. Capsules from host plants will be removed and tested in accordance with the ISP implementation plan defined in BWRVIP-86-A. Results from these tests that are applicable to Columbia will provide the necessary data to monitor embrittlement for the . Columbia reactor pressure vessel (RPV). EN will apply the results of the ISP capsule testing to Columbia. The neutron fluence values used for the projections of neutron embrittlement effects are determined using NRC*-approved methodology. The exposure conditions of the reactor" vessel are monitored 11:) ensure that they continue to be consistent with those used to project the effects of ernbrittlement to the end of the license term. If the reactor vessel exposure conditions (neutron flux, spectrum, irradiation temperature, etc.) are altered, then the basis for the projection to 60 years is reviewed; and, if deemed appropriate, a " revised fluence projection is prepared and the effects of the revised fluence analysis on neutron embrittlement calculations will be evaluated. The determination of neutron embrittlement effects for Columbia fully complies with NRC Regulatory Guide! 1.99, Revision 2. Projections for neutron embrittlement effects have been adjusted to account for the specific nickel and copper contents of the Columbia materials. The extent of reactor vessel embrittlement for upper-shelf energy (USE) and adjusted reference temperature for nil-ductility transition (ART) is prOjected for 60 years in accordance with Regulatory Guide 1.99, Revision 2. These projections I Aging Management Page 8-175 January 2010 Columbia Generating Station License Renewal Application Technical Information will be updated throughout the Iremaining life of Columbia if new information (e.g., material data from the ISP applicable to Columbia, or revised fluence values) becomes available. P-T limits will be managed for the period of extended operation. Participation in the BWRVIP ISP will ensure that changes to irradiation embrittlement information willbe factored into the determination of any required operating restrictions in a timely fashion.The Columbia program requires that untested capsules either be returned to the reactor vessel or maintained in storage for possible future re-insertion. As no Columbia capsules are scheduled for testing, the disposition of tested capsules is not applicable to Columbia.The Columbia Reactor Vessel Surveillance Program will also monitor the Effective Full Power Years (EFPY) accumulated by the unit and ensure that the P-T limit curves contained in plant technical specifications are updated periodically such that they are always valid beyond the EFPY that the plant has accumulated. Reactor vessel P-T limits will thus be managed as a TLAA for the period of extended operation. NUREG-1801 Consistency The Reactor Vessel Surveillance Program is an existing Columbia program that is consistent with the 10 elements of an effective integrated surveillance program as described in NUREG-1 801, Section XI.M31, "Reactor Vessel Surveillance." Exceptions to NUREG-1801 None.Required Enhancements None.Operating Experience The Reactor Vessel Surveillance Program has been effective in managing reduction of fracture toughness for the reactor vessel beltline components. Industry operating experience: Columbia participates in the BWRVIP ISP as described in reports BWRVIP-86-A and BWRVIP-116. Participation in the ISP ensures that future operating experience from all participating BWRs will be factored into the Reactor Vessel Surveillance Program. The NRC has concurred that the Reactor Vessel Surveillance Program is an acceptable program based on the NRC safety evaluation reports (SERs) for the Aging Management Programs Page B-176 January 2010 Columbia Generating Station License Renewal Application Technical Information will be updated throughout the remaining life of Columbia if new information (e.g., material data from the ISP applicable to Columbia, or revised fluence values) becomes aVailable. P-T limits will be managed for the period of extended operation. Participation in the BWRVIP ISP will ensure that changes to irradiation embrittlement information will be factored into the deter'mination of any required operating restrictions in a timely fashion. The Columbia program requires that untested capsules either be returned to the reactor vessel or maintained in storage for possible' future re-insertion. As no Columbia capsules are scheduled for testing, the disposition of tested capsules is not applicable to Columbia. The Columbia Reactor Vessel Surveillance Program will also monitor the Effective Full Power Years (EFPY) accumulated by the unit and ensure that the P-T limit curves contained in plant technical specifications are updated periodically such that they are always beyond the EFPY that the plant has accumulated. Reactor vessel P-T limits will thus be managed as a TLAA for the period of extended operation. NUREG-1801 Consistency

• The Reactor Vessel Surveillance Program is an existing Columbia' program that is consistent with the 1 0 elements of an effective integrated surveillance program as
• described in NUREG-1801, Section XI.M31, "Reactor Vessel Surveillance." Exceptions to NUREG-1801 None. Required Enhancements None. Operating Experience The Reactor Vessel Surveillance Program has been effective in managing reduction of fracture toughness for the reactor vessel beltline components.

Industry operating experience: Columbia participates in the BWRVIP ISP as qescribed in reports BWRVIP-86-A and BWRVIP-116. Participation in the ISP ensures that future operating experience from all participating BWRs will be factored into the Reactor Vessel Surveillance Program. The NRC has concurred that the Reactor Vessel Surveillance Program is an acceptable program based on the NRC safety evaluation reports, (SERs) for the Aging Management Programs Page '8-176 January 2010

• Columbia Generating Station License Renewal Application Technical Information BWRVIP ISP and the SER for the replacement of the Columbia site-specific program with the ISP.Columbia operating experience:

A review of Columbia operating experience identified no issues related to reactor vessel embrittlement. Surveillance specimen analysis and embrittlement projections are being performed by the BWRVIP ISP.The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the. new program is effective in managing the identified aging effects.Conclusion The Reactor Vessel Surveillance Program manages reduction of fracture toughness for components of the reactorvessel beltline region. The Reactor Vessel Surveillance Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-1 77 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information BWRVIP ISP and thE3 SER for the replacement of the Columbia site-specific program with the ISP. Columbia operating experience:

A review of Columbia operating experience identified no issues related to reactor vessel embrittlement. Surveillance specimen analysis and embrittlement projections are being performed by the BWRVIP ISP. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the* new program is effective in managing the* identified aging effects. . ' . Conclusion The Reactor Vessel Surveillance Program manages reduction of fracture toughness for components of the reactor* vessel beltline region. The Reactor Vessel Surveillance Program provides reasonable assurance that the aging effects will be managed such that components subject to aging management review will continue to perform their . intended functions consistent with the current licensing basis for the period of extended operation . / , Aging Management Programs Page 8-177 January 2010 / Columbia Generating Station License Renewal Application Technical Information B.2.47 Selective Leaching Inspection Program Description The Selective Leaching Inspection will detect and characterize the conditions on internal and external surfaces of subject components that are exposed to raw water, treated water (including closed cycle cooling water and steam), fuel oil, soil (buried), and moist air (including condensation) environments. This one-time inspection provides direct evidence through a combination of visual examination and material hardness testing, or NRC approved alternative, of whether, and to what extent, a loss of material due to selective leaching has occurred or is likely to occur that could result in a loss of intended function.Implementation of the Selective Leaching Inspection prior to the period of extended operation will ensure that the pressure boundary integrity of susceptible components is maintained consistent with the current licensing basis during the period of extended operation. Implementation of the inspection will also provide added assurance that the structural integrity of susceptible components is maintained such that spatial interaction will not impair or prevent a safety-related intended function during the period of extended operation. NUREG-1801 Consistency The Selective Leaching Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M33, "Selective Leaching of Materials." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The Selective Leaching Inspection is credited for evaluating the condition of selective leaching susceptible components and assessing their ability to perform their intended function during the period of extended operation. Susceptible components include piping and tubing, valve bodies, pump casings, filter bodies, heat exchanger components, hydrants, strainers, tanks, and trap bodies.Components within the scope of the program are formed of gray cast iron or copper alloy > 15% Zn. The components are exposed to raw water, treated water (including closed cycle cooling water and steam), fuel oil, soil (buried), or moist air (including condensation) environments during normal plant operations. The one-time Aging Management Programs Page B-178 January 2010 8.2.47 Selective Leaching Inspection Program Description Columbia Generating Station License Renewal Application Technical Information The Selective Leaching Inspection will detect and characterize the conditions on internal and external. surfaces of subject components that are exposed to raw water, treated water (including closed cycle cooling water and steam), fuel oil, soil (buried), and moist air (including condensation) environments. This one-time inspection provides direct evidence through a combination of visual examination and material hardness testing, or NRC approved alternative, of whether, and to what extent; a loss of material due to selective leaching has occurred or is likely to occur that could result in a loss of intended function. Implementation of the Selective Leaching Inspection prior to the period of extended operation will ensure that the pressure boundary integrity of susceptible components is maintained* consistent with the current licensing basis during the period of extended operation. Implementation of the inspection will also provide added assurance that the structural integrity of susceptible components is maintained such that spatial interaction will not impair or prevent a safety-related intended function during the period of extended operation. NUREG-1801 Consistency The Selective Leaching Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M33, "Selective Leaching of Materials." Exceptions to NUREG-1801 None. Aging Management Program Elements The results of an evaluation of each program element are provided below.

• Scope of Program The Selective Leaching Inspection is credited for evaluating the condition of selective leaching susceptible components and assessing their ability to perform their intended function during the period of extended operation.

Susceptible components include piping and tubing, valve bodies, pump casings, filter bodies, heat exchanger components, hydrants, strainers, tanks, and trap bodies. Components within the scope ofthe program are formed of gray cast iron or copper alloy> 15% Zn. The components are exposed to raw water, treated water (including closed cycle cooling water and steam), fuel oil, soil (buried), or moist air (including condensation) environments during normal plant operations. The one-time Aging Management Programs Page 8-178 January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Informationinspection includes a visual examination and hardness measurement, or NRC approved alternative, of a sample set of components to determine whether selective leaching is occurring or is likely to occur in the period of extended operation.The aging management activity is credited for the following systems:* Auxiliary Steam (AS) System eCirculating Water (CW) System* Containment Nitrogen (CN) System* Control Rod Drive (CRD) System* Diesel Building HVAC Systems (DMA)* Diesel Fuel Oil (DO) System* Fire Protection (FP) System* High Pressure Core Spray (HPCS) System* Low Pressure Core Spray (LPCS) System* Main Steam (MS) System* Plant Service Water (TSW) System* Potable Cold Water (PWC) System* Potable Hot Water (PWH) System* Process Sampling (PS) System* Radwaste Building Chilled Water (WCH) System* Radwaste Building HVAC Systems (WEA, WMA, WOA, WRA)' Reactor Building HVAC Systems (REA, ROA, RRA)* Residual Heat Removal (RHR) System* Standby Service Water (SW) System* Tower Makeup Water (TMU) System Preventive Actions No actions are taken as part of the Selective Leaching Inspection to prevent aging effects or to mitigate aging degradation.

Although the control of water chemistry may reduce selective leaching in treated water environments, no specific credit is taken for water chemistry control as part of this program.Aging Management Programs Page B-179 January 2010 Aging Management Programs Page B-179 January 2010* *

• Columbia Generating Station . License Renewal Application Technical Information inspection includes a visual examination and hardness measurement, or NRC approved alternative, of a sample set of components to determine whether selective leaching is occurring or is likely to occur in the period of extended operation.

The aging management activity is credited for the following systems:

• Auxiliary Steam (AS) Syste_m
• Circulating Water (CW), System
• Containment Nitrogen (eN) System
• Control Rod Drive (CRD) System
• Diesel Building HVAC Systems (DMA)
• Diesel Fuel Oil (DO) System
• Fire Protection (FP) System
• High Pressure Core Spray (HPCS) System'
• Low Pressure Core Spray (LPCS) System
• Main Steam (MS) System
• Plant Service Water (TSW) System
• Potable ColdWater (PWC) System
• Potable Hot Water (PWH) System
• Process' Sampling (PS) System
• Radwaste Building Chilled Water (WCH) System
• Radwaste Building HVAC Systems (WEA, WMA, WOA, WRA) * -Reactor Building HVAC Systems (REA, ROA, RRA)
• Residual Heat Removal (RHR) System
• Standby Service Water (SW) System
• Tower Makeup Water (TMU) System
• Preventive Actions . No actions are taken as part of the Selective Leaching Inspection to prevent aging effects or to mitigate aging degradation.

Although the control of water chemistry may reduce selective leaching in treated water environments, no specific credit is taken for water chemistry control as part of this program . Aging Management Programs Page 8-179 January 2010 , \ Columbia Generating Station License Renewal Application Technical, Information Parameters Monitored or Inspected The Selective Leaching Inspection will perform a combination of visual examination and hardness testing, or NRC approved alternative, of components within the scope of the program as a measure of loss of material due to selective leaching.The Selective Leaching Inspection activities will be conducted after the issuance of the renewed operating license and prior to the end of the current operating license, with sufficient time to implement programmatic oversight prior to the period of extended operation. The activities will be conducted no earlier than 5 years prior to the end of the current operating license, so that conditions are more representative of the conditions expected during the period of extended operation.,-Detection of Aging Effects The Selective Leaching Inspection will include provision for a combination of visual examination and hardness testing, or NRC approved alternative, of a sample of components with susceptible materials in environments conducive to the occurrence of selective leaching. The program will include the criteria for visual inspection and for hardness testing. The results of the inspections will be evaluated to determine the condition of the material. Engineering evaluation in conjunction with the corrective action program will determine whether components with degraded materials are capable of performing their intended functions. The aging management activities include: (a) determination of the sample size based on an assessment of materials of fabrication, environment and conditions, and operating experience; (b) identification of the inspection locations in thesusceptible system or component; (c) determination of the examination technique, including acceptance criteria; and (d) evaluation of the need for follow-up examinations to monitor the progression of aging if age-related degradation is found that could jeopardize an intended function before the end of the period of extended operation. The results of the inspections will be evaluated against the acceptance criteria.Additional testing will be performed, as necessary, based on review of the inspection results.* Monitoring and Trending No actions are taken as part of the Selective Leaching Inspection to monitor or trend inspection results. This is a one-time inspection activity used to determine if, and to what extent, further actions, including monitoring and trending, may be required.The inspection results will be evaluated through the site corrective action process.* Acceptance Criteria The Selective Leaching Inspection will include acceptance criteria for visual inspections and for hardness testing, or NRC approved alternative. Inspection Aging Management Programs Page B13180 January 2010* Parameters Monitored or Inspected Columbia Generating Station License Renewal Application Technical Information The Selective Leaching Inspection will perform a combination of visual examination and hardness testing, or NRC approved alternative, of components within the scope ofthe program as a measure of loss of material due to selective leaching. The Selective Leaching Inspection activities will be conducted after the issuance of the renewed operating license and prior to the end of the current operating license, with sufficient time to implement programmatic oversight prior to the period. of extended operation. The activities will be conducted no earlier than 5 years prior to the end of the current operating license, so that conditions are more representative of the conditions expected during the period of extended operation.'

• Detection of Aging Effects The Selective Leaching Inspection will include* provision for a combination of visual examination and hardness testing, or NRC approved alternative,*

of a sample of components with susceptible materials in environments conducive to the occurrence of selective leaching. The program will include the criteria for visual inspection and for hardness testing. The results of the inspections will be evaluated to determine the condition of the material. Engineering evaluation in conjunction with the corrective action program will determine whether components with degraded materials are capable of performing their intended functions. The aging management. activities include: (a) determination of the sample size based on an assessment of materials of fabrication, environment and conditions, and operating experience; (b) identification of the inspection locations in the susceptible system or component; (c) determination of the examination technique, including acceptance criteria; and (d) evaluation of the need for follow-up examinations to monitor the progression of aging if age-related degradation is found that could jeopardize an intended function before the end of the period of extended operation. The results of the inspections will be evaluated against the acceptance criteria. Additional testing will be performed, as necessary, based on review of the inspection results.

• Monitoring and Trending . No actions are taken as part of the Selective Leaching Inspection to monitor or trend inspection results. This is a one-time inspection activity used to determine if, and to what extent, further actions, including monitoring and trending, may be required.

The inspection results will be evaluated through the site corrective action process.

• Acceptance Criteria The Selective Leaching Inspection will include acceptance criteria for visual inspections for hardness testing, or NRC approved alternative.

Inspection Aging Management Programs Page January 2010 * *

• Columbia Generating StationLicense Renewal Application Technical Information results that do not meet the acceptance criteria will be entered into the corrective action program. The corrective action program includes provision for further evaluation of degraded materials and any necessary corrective actions.* Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3." Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Operating Experience The Selective Leaching Inspection is a new one-time inspection activity for which plant operating experience has not shown, the occurrence of the aforementioned aging effect. However, plant design considerations address the potential for degradation of installed components through the application of materials suitable for the expected operating environments, and inspection methods will be consistent with accepted industry practices.

NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Energy. Northwest will follow the industry initiatives with respect to inspection for selective leaching, such as those being pursued by the EPRI and the NEI License Renewal Implementation Working Group. If a suitable alternative to hardness testing is identified prior to implementation of the inspection, Energy Northwest will seek NRC approval prior to its use.Some evidence of dezincification of the brass tubes in the main condenser was identified through visual inspection prior to startup (1982), and attributed to stagnant circulating water and a drop in pH. The condenser tubes, which are not in the scope of license renewal, were cleaned and there has> been no recurrence of dezincification, although there are still residual effects of the original dezincification. Aging Management Programs Page B-181 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information results that do not meet the acceptance criteria will be entered into the corrective action program. The corrective action program includes provision for further evaluation of degraded materials and any necessary corrective actions.
• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. * . Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended*

operation and is discussed in Section 8.1.3.

• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section 8.1.3.
• Operating Experience The Selective Leaching Inspection is a new one-time.

inspection activity for which plant operating experience has not shown' the occurrence of the aforementioned aging -effect. However, plant design considerations address the potential for degradation of installed components through the application of materials suitable for the expected operating environments, and inspection methods will be consistent with accepted industry practices. NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Energy Northwest will follow the industry initiatives with respect to inspection for selective

leaching, as those being pursued by the EPRI and the NEI License Renewal Implementation Working Group. If a suitable alternative to hardness testing is identified prior to implementation of the inspection, Energy Northwest will seek NRC approval prior to its use; Some evidence of dezincification of the brass tubes in the main condenser was identified through visual inspection prior to startup (1982), and attributed to stagnant circulating water and a drop in pH. The condenser tubes, which are not in the scope of license renewal, were cleaned and there been no recurrence of dezincification, although there are still residual effects of the original dezincification.

Aging Management Programs Page 8-181 January 2010 Columbia Generating Station License Renewal Application Technical Information Required Enhancements Not applicable, this is a new activity.Conclusion Implementation of the Selective Leaching Inspection will verify that selective leaching does not require management for the susceptible components, or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current.licensing basis during the period of extended operation. Aging Management Programs Page B- 182 January 2010 Required Enhancements Not applicable, this is a new activity. Conclusion Columbia Generating Station License Renewal Application Technical Information Implementation of the Selective Leaching Inspection will verify that selective leaching does not require management for the susceptible components, or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current .licensing basis during the period of extended operation. Aging Management Programs Page 8-182 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information B.2.48 Service Air System Inspection Program Description The Service Air System Inspection is a new one-time inspection that will detect and characterize the material condition of piping and valve bodies that are within the scope of license renewal in the Service Air System and are exposed to an "Air (internal)" environmentl The Service Air System Inspection provides direct evidence as to whether, and to what extent, a loss of material due to general corrosion has occurred or is likely to occur in the subject components that could result in a loss of intended function.Implementation of the Service Air System Inspection will ensure that the pressure boundary integrity of the subject components will be maintained consistent with the current licensing basis during the period of extended operation.

Implementation of the inspection will also provide assurance (and confirmation) that the structural integrity of' susceptible NSR components will be maintained such that the integrity of the attached safety-related piping is not impacted and will not result in the loss of any safety-related component intended functions during the period of extended operation. NUREG-1801 Consistency The Service Air System Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M32, "One-Time Inspection." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The Service Air System Inspection detects and characterizes conditions relative to the following subject mechanical components to determine whether, and to what extent, degradation is occurring:

• Loss of material due to general corrosion on steel piping and valve bodies exposed to an air (internal) environment.

The Service Air System Inspection focuses on the portion of the Service Air System that forms the pressure boundary for containment penetration X93 and the connected piping subject to an air (internal) environment (i.e., compressed air) that Aging Management Programs Aging Management Prog~ans Page B-183 January 2010 Page B-183 January 2010* *

• B.2.48 Service Air System Inspection Program Description Columbia Generating Station License Application Technical Information The Service Air System Inspection is a new one-time inspection that will detect and characterize the material condition of piping and valve bodies that are within the scope of license renewal in the Service Air System and are exposed to an' "Air (internal)" . environment:

The Service Air System Inspection provides direct evidence as to whether, and to what extent, a loss of material due to general corrosion has occurred or is likely to occur in the subject components that could result in a loss of intended function. Implementation of the Service Air System Inspection will ensure that the pressure boundary integrity of the subject components will be maintained consistent with the current licensing basis during the period of extended operation. Implementation of the inspection will also provide assurance (and confirmation) that the structural integrity of' susceptible NSR components will be maintained such that the integrity of the attached . safety-related piping is not impacted and will not result in the loss of any safety-related component intended functions during the period of extended operation. NUREG-1801 ConsistEmcy The Service Air System Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1 801, Section XI,M32, "One-Time Inspection." Exceptions to NUREG-1801 None. Aging Management Program Elements The results of an evaluation of each program element are provided below.

• Scope of Program The Service Air System Inspection detects and characterizes conditions relative to the following subject mechanical components to determine whether, and to what extent, degradation is occurring:
• Loss of material due to general corrosion on steel piping and valve bodies exposed to an air (internal) environment.

The Service Air System Inspection focuses on the portion of the Service Air System that forms the boundary for containment penetration X93 and the connected piping subject to an air (internal) environment (i.e., compressed air) that Aging Management Progr.ams Page 8-183 January 2010 Columbia Generating Station License Renewal Application Technical Information performs a structural integrity function. The Service Air System Inspection provides symptomatic evidence of loss of material (due to general corrosion).

• Preventive Actions No actions are taken as part of the Service Air System Inspection to prevent agingeffects or to mitigate aging degradation.

Parameters Monitored or Inspected The parameters to be inspected by the Service Air System Inspection include wall thickness or visual evidence of internal surface degradation, as measures of loss of material. Inspections will be performed by qualified personnel using established NDE techniques. Detection of Aging Effects The Service Air System Inspection will use a combination of established volumetric (radiographic or ultrasonic testing) and visual (VT-3 or equivalent) examination techniques performed by qualified personnel on a portion of the subject Service Air System components as determined by engineering evaluation, to identify evidence of a loss of material, or to confirm a lack thereof.The sample population will be determined by engineering evaluation based on sound statistical sampling methodology, and, where practical, be focused on the components most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and design margins.The Service Air System Inspection will be conducted within the 10-year period prior to the period of extended operation. Monitoring and Trending This one-time inspection activity is used to characterize conditions and determine if, and to what extent, further actions may be required. The activity includes increasing the inspection sample size and location if degradation is detected.Sample size will be determined by engineering evaluation of the materials of construction, environment (i.e., service conditions), aging effects, and operating experience (e.g., time in-service, most susceptible locations, lowest design margins).Inspection findings that do not meet the acceptance criteria will be evaluated using the corrective action process to determine the need for subsequent aging management activities and for monitoring and trending of the results.Acceptance Criteria Indications or relevant conditions of degradation detected during the inspections will be compared to pre-determined acceptance criteria. If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective Aging Management Programs Page B-184 January 2010 Columbia Generating Station License Renewal Application

• Technical Information performs a structural integrity function.

The Service Air System Inspection provides symptomatic evidence of loss of material (due to general corrosion).

• Preventive Actions No actions are taken as part of the Service Air System Inspection to prevent aging effects or to mitigate aging degradation.
• Parameters Monitored or Inspected The parameters to be inspected by the Service Air System Inspection include wall thickness or visual evidence of internal surface degradation, as measures of loss of material.

Inspections will be performed by qualified personnel using established NDE techniques.

• Detection of Aging Effects The Service Air System Inspection will use a combination of established volumetric (radiographic or ultrasonic testing) and visual (VT-3 or equivalent) examination techniques performed by qualified personnel on a portion of the subject Service Air System components as determined by engineering evaluation, to identify evidence of a loss of material, or to confirm a lack thereof.

The sample population will be determined by engineering evaluation based on sound statistical sampling methodology, and, where practical, be focused on the

• cOI"DPonents most susceptible to aging, such as due to their time in service, the severity of conditions during normal plant operations, and design margins. The Service Air System Inspection will be conducted within the 10-year period prior to the period of extended operation.
• Monitoring and Trending This one-time inspection activity is used to characterize conditions and determine if, and to what extent, further actions may be required.

The activity includes increasing the inspection sample size and location if degradation is detected. Sample size will be determined by engineering evaluation of the materials of construction, environment (Le., service conditions), aging effects, and operating experience (e.g., time in-service, most susceptible locations, lowest design margins). Inspection findings that do not meet the acceptance criteria will be evaluated using the corrective action process to determine the need for subsequent aging management activities and for monitoring and trending of the results.

• Acceptance Criteria Indications or relevant conditions of degradation detected during the inspections will be compared to pre-determined acceptance criteria.

If the acceptance criteria are not met, then the indications and conditions will be evaluated under the corrective Aging Management Programs Page B-184 January 2010

• Columbia Generating Station License Renewal Application Technical Information action program to determine whether they could result in a loss of component intended function during the period of extended operation.
• Corrective Actions This element is common to aging management during Section B.1.3.* Confirmation Process This element is common to aging management during Section B.1.3." Administrative Controls This element is common to aging management during Section B.1.3.Columbia programs and activities that are the period of extended operation and is Columbia programs and activities that are the period of extended operation and is Columbia programs and activities that are the period of extended operation and is credited with discussed in credited with discussed in credited with discussed in Operating Experience The Service Air System Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effect. The activity provides confirmation of conditions where degradation is not expected, has not evidenced as a problem, or where the aging mechanism is slow acting. Due to the fact that portable compressors without dryers have been iused in the Service Air System, the system may not have always been reliably dry.'This inspection will verify the presence (or absence) of general corrosion within the license renewal boundary of the Service Air System.NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability; none was identified.

Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience to date has identified no instances of loss of material related to the subject components. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program is effective in managing the identified aging effects.Required Enhancements Not applicable, this is a new activity.Aging Management Programs Aging Management Programs Page B-185 January 2010 Page B-185 January 2010* *

• Columbia Generating Station License Renewal Application Technical Information action program to determine whether they could result in a loss of component intended function during the period of extended operation.
• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management

'during the period of extended operation and is discussed in Section B.1.3.

• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.
• Operating Experience The Service Air System Inspection is a new one-time inspection activity for which plant operating experience has not shown the occurrence of the aforementioned aging effect. The activity provides confirmation of conditions where degradation is not expected, has not evidenced as a problem, or where the aging mechanism is slow acting. Due to the fact that portable compressors without dryers have been iused in the Service Air System, the system may not have always been reliably dry. IThis inspection will verify the presence (or absence) of general corrosion within the license renewal boundary of the Service Air System. \

is based on industry operating experience through January 2005. Recent industry experience has been reviewed for applicability; none was identified. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. A review of Columbia operating experience to date has identified no instances of loss of material related to the subject components. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the program is effective in managing the identified aging effects. Required Enhancements Not applicable, this is a new activity . Aging Management Programs Page 8-185 January 2010 Columbia Generating Station License Renewal Application Technical Information Conclusion Implementation of the Service Air System Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation. Aging Management Programs Page 8-186 January 2010 Aging Management Programs Page B-186 January 2010 Columbia Generating Station License Renewal Application

• Technical Information Conclusion Implementation of the Service Air System Inspection will verify that there are no aging effects requiring management for the subject components or will identify corrective actions, possibly including programmatic oversight, to be taken to ensure that the component intended functions will be maintained consistent with the current licensing basis during the period of extended operation.

Aging Management Programs Page 8-186 January 2010 *

• Columbia Generating StationLicense Renewal Application Technical Information B.2.49 Small Bore Class 1 Piping Inspection Program Description The Small Bore Class 1 Piping Inspection will detect and characterize the conditions on the internal surfaces of small bore Class 1 piping components that are exposed to reactor coolant. The one-time inspection will provide physical evidence as to whether, and to,,what extent, cracking due to SCC or to thermal or mechanical loading has occurred in small bore Class 1 piping components.

It will also verify, by inspections for cracking, that reduction of fracture toughness due to thermal embrittlement requires no additional aging management for small Class 1 CASS valve bodies. The Small Bore Class 1 Piping Inspection will be an evaluation and inspection with no actions to prevent or mitigate aging effects.This one-time inspection is applicable to small bore ASME Code, Class I piping components less than-4 inches nominal pipe size (NPS 4), which includes piping, fittings, branch connections, and valve bodies. The Small Bore Class 1 Piping Inspection includes visual and volumetric inspection of a representative sample of small bore Class 1 piping components. The inspection provides additional assurance that either age-related degradation of small bore ASME Code Class 1 piping components isnot occurring or that the aging is insignificant, such that an additional aging management program is not warranted during the period of extended operation. Columbia has not experienced cracking of small bore Class 1 piping solely due to stress corrosion or thermal and mechanical loading, and therefore this one-time inspection is appropriate. The inspection will include a representative sample of the small bore Class 1 piping population, and, where practical, will focus on the bounding or lead components most susceptible to aging due to time in service, severity of operating conditions, and lowest design margin. The guidelines of EPRI Report 1000701, "Interim Thermal Fatigue Management Guideline (MRP-24)" will be considered in selecting the sample size and locations. Actual inspection locations will be based on physical accessibility, exposure levels, NDE techniques., and locations identified in NRC Information Notice (IN) 97-46. Volumetric examinations (including qualified destructive and/or nondestructive techniques) will be performed by qualified personnel following procedures that are consistent with Section Xl of the ASME Code and 10 CFR 50, Appendix B.Unacceptable inspection findings will be evaluated by the Columbia corrective action process using criteria in accordance with the ASME Code. The evaluation of indications will include determining the extent of condition by the expansion of the sample size when called for by the Code. Evaluation of inspection results may lead to the creation of a plant-specific AMP or may confirm that age-related degradation is either not occurring or is insignificant. Aging Management Programs Page B-1 87 January 2010* *

• B.2.49 Small Bore Class 1 Piping Inspection Program Description Columbia Generating Station License Renewal Application Technical Information The Small Bore Class 1 Piping Inspection will detect and characterize the conditions on the internal surfaces of small bore Class 1 piping components that are exposed to reactor coolant.'

The one-time inspection will provide physical evidence as to whether, and to\ what extent, cracking due to SCC or to thermal or mechanical loading has occurred in small bore Class 1 piping components. It will also verify, by inspections for crackirig, that reduction of fracture toughness due to thermal embrittlement requires no additional aging management for small Class 1 CASS valve bodies. The Small Bore Class 1 Piping Inspection will be an evaluation and inspection with no actions to prevent or mitigate aging effects. This one-time inspection is applicabJe to small bore ASME Code. Class piping components less than-4 inches nominal pipe size (NPS 4), which includes piping, fittings, branch connections, and valve bodies. The Small Bore Class 1 Piping Inspection includes visual and volumetric inspection of a representative sample of small bore Class 1 piping components. The inspection provides additional assurance'that either age-related degradation of small bore ASME Code Class 1 piping components is not occurring or that the aging is inSignificant, such that an additional aging management program is not warranted during the period of extended operation. Columbia has not experienced cracking of small bore Class 1 piping solely due to stress corrosion or thermal and mechanical and therefore this one-time inspection is appropriate. The inspection will include a representative sample of the small bore Class 1 piping population, and, where practical, will focus on the bounding or lead components most susceptible to aging due to time in service, severity of operating conditions, and lowest design margin. The guidelines of EPRI Report 1000701, "Interim Thermal Fatigue Management Guideline (MRP-24)" will be considered in selecting the sample size and locations. Actual inspection locations will be based on physical accessibility, exposure levels, NDE techniques, and locations identified in NRC Information Notice (IN) 97-46. Volumetric examinations (including qualified destructive and/or nondestructive techniques) will be performed by qualified personnel following procedures that are consistent with Section XI of the ASME Code and 10 CFR 50, Appendix B. Unacceptable inspection findings will be evaluated by the Columbia corrective action process using criteria in accordance with the ASME Code. The evaluation of indications will include determining the extent of condition by the expansion of the sample ,size when called for by the Code. Evaluation of inspection results may lead to the creation of a plant-specific AMP or may confirm that age-related degradation is either not occurring or is inSignificant. Aging Management Programs Page 8-187 January 2010 Columbia Generating Station License Renewal Application Technical Information The Small Bore Class 1 Piping Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted during the portion of the fourth 10-year ISI interval that is prior to the period of extended operation. The Small Bore Class 1 Piping Inspection will credit portions of the Inservice Inspection (ISI) Program. The Small Bore Class 1 Piping Inspection will verify the effectiveness of the BWR Water Chemistry Program in mitigating cracking of small bore piping and piping components. NUREG-1801 Consistency The Small Bore Class 1 Piping Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.M35, "One-time Inspection of ASME Code Class 1 Small-Bore Piping." Exceptions to NUREG-1801 None.Aging Management Program Elements The results of an evaluation of each program element are provided below.Scope of Program The Small Bore Class 1 Piping Inspection is a one-time inspection of a sample of ASME Code Class 1 piping and piping components less than NPS 4. The inspection will include measures to verify that unacceptable degradation is not occurring in Class 1 small bore piping and piping components (valve bodies), thereby confirming that an aging management program is not needed for the period of extended operation. See Monitoring and Trending below for a discussion of sample selection and inputs.* Preventive Actions The Small Bore Class 1 Piping Inspection will be an evaluation and inspection with no actions to prevent or mitigate aging effects.Parameters Monitored or Inspected The Small Bore Class 1 Piping Inspection is a one-time inspection that will include volumetric examinations (destructive or nondestructive) performed 'by qualified personnel, using qualified volumetric examination techniques, and followingprocedures consistent with Section Xl of the ASME Code and 10 CFR 50, Appendix B.Aging Management Programs Page B-188 January 2 010 Columbia Generating Station License Renewal Application Technical Information The Small Bore Class 1 Piping Inspection is a new one-time inspection that will be implemented prior to the period of extended operation. The inspection activities will be conducted during the portion of the fourth 10-year lSI interval that is prior to the period , of extended operation. The Small Bore Class 1 Piping Inspection will credit portions of the Inservice Inspection (lSI) Program. The Small Bore Class 1 Piping Inspection will verify the effectiveness of the BWR Water Chemistry Program in mitigating cracking of small bore piping and piping components. NUREG-1801 Consistency The Small Bore Class 1 Piping Inspection is a new one-time inspection for Columbia that will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI,M35, "One-time Inspection of ASME Code Class 1 Small-Bore Piping." Exceptions to NUREG-1801 'None. Aging Management Program Elements The results of an evaluation of each program element are provided below.

• Scope of Program The Small Bore Class 1 Piping Inspection is a one-time inspection of a sample of ASME Code Class 1 piping and piping components less than NPS 4. The inspection will include measures to verify that unacceptable degradation is not occurring in Class 1 small bore piping and piping components (valve bodies), thereby confirming that an aging management program is not needed for the period of extended operation.

See Monitoring and Trending for a discussion of sample selection and inputs.

• Preventive Actions The Small Bore Class 1 Piping Inspection will be an evaluation and inspection with no actions to prevent or mitigate aging effects.
• Parameters Monitored or Inspected The Small Bore Class 1 Piping Inspection is a one-time inspection that will include volumetric examinations (destructive or nondestructive) performed

'by qualified personnel, using qualified volumetric examination techniques, and following procedures consistentwith Section XI of the ASME Code and 10 CFR 50, Appendix B. Aging Management Programs Page 8-188 January 2010 * *

• Columbia Generating Station License Renewal Application Technical Information Detection of Aging Effects This inspection will perform volumetric examinations on selected weld locations.

Columbia has not experienced cracking of small bore Class 1 piping due to stress corrosion or thermal and mechanical loading, and therefore this one-time inspection is appropriate. Columbia has found cracking due to fatigue and growth of construction flaws of small bore piping. See Operating Experience below for discussion of site operating experience to date and lack of stress corrosion or thermal and mechanical loading induced cracks.Monitoring and Trending The inspection will include a representative sample of the small bore Class 1 piping population, and, where practical, will focus on the bounding or lead components most susceptible to aging due to time in service, severity of operating conditions, and lowest design margin. The guidelines of EPRI Report 1000701, "Interim Thermal Fatigue Management Guideline (MRP-24)" will be considered in selecting the sample size and locations. Actual inspection locations will be based on physical accessibility, exposure levels, NDE techniques, and locations identified in NRC Information Notice 97-46. Volumetric examinations (including qualified destructiveand nondestructive techniques) will be performed by qualified personnel following procedures that are consistent with Section Xl of the ASME Code and 10 CFR 50, Appendix B.Unacceptable inspection findings will be evaluated by the Columbia corrective action process. The Small Bore Class 1 Piping Inspection will require an increased sample size in response to unacceptable inspection findings. Evaluation of inspection results may lead to the creation of a plant-specific aging management program or may confirm that age-related degradation is either not occurring or is insignificant.

• Acceptance Criteria Unacceptable inspection findings will be evaluated by the Columbia corrective action process using criteria in accordance with the ASME Code. The evaluation of indications will include determining the extent of condition by the expansion of the sample size when called for by the Code.

Evaluation of inspection results may lead to the creation of a plant-specific aging management program or may confirm that age-related degradation is either not occurring or is insignificant.

• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.Aging Management Programs Page B-189 January 2010* * *
• Detection of Aging Effects Columbia Generating Station License Renewal Application Technical Information This inspection will perform volumetric examinations on selected weld locations.*

Columbia has not experienced cracking otrsmall bore Class 1 piping due to stress corrosion or thermal and mechanical loading, and therefore this one-time inspection is appropriate. Columbia has found cracking due to. fatigue and growth of construction flaws of small bore piping. See Operating Experience below for discussion of site operating experience to date and lack of stress corrosion or thermal and mechanical loading induced cracks. * . Monitoring and Trending The inspection will include a representative sample of the small bore Class 1 piping population, and, where practical, will focus on the bounding or lead components most susceptible to aging due to time in service, severity of operating conditions, and lowest design margin. The guidelines of EPRI Report 1000701, "Interim Thermal Fatigue Management Guideline (MRP-24)" will be considered in selecting the sample size and locations. Actual inspection locations will be based on physical accessibility, exposure levels, NDE techniques, and locations identified in NRC Information Notice H7-46. Volumetric examinations (including qualified destructive and nondestructive techniques) will be performed by qualified personnel following procedures that are consistent with Section XI of the ASME Code and 10 CFR 50, Appendix B. Unacceptable inspection findings will be evaluated by the Columbia corrective action process. The Small Bore Class 1 Piping Inspection will require an increased sample size in response to unacceptable inspection findings. Evaluation of inspection results may lead to the creation of a plant-specific aging management program or may confirm that age-related degradation is either not occurring or is insignificant.

• Acceptance Criteria . Unacceptable inspection findings will be evaluated by the Columbia corrective action process using criteria in accordance with the ASME Code. The evaluation of indications will include determining the extent of condition by the expansion of the sample size when called for by the Code. Evaluation of inspection results may lead to the creation of a plant-specific aging management program or may confirm that age-related degradation is either not occurring or is insignificant.
• Corrective Actions This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3. Aging Management Programs Page 8-189 January 2010 Columbia Generating Station License Renewal Application Technical Information
• Confirmation Process This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.* Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the periodý of extended operation and is discussed in Section B.1.3.* Operating Experience Based on review of plant-specific and industry operating experience, the identified.aging effects require management for the period of extended operation.

The Small Bore Class 1 Piping Inspection provides confirmation of material conditions near the period of extended operation as additional assurance that existing inspections, via the Inservice Inspection (ISI) Program, and control of water chemistry, via the BWR Water Chemistry Program, provide adequate management. Industry operating experience: NUREG-1801 is based on industry operating experience through January 2005.Recent industry operating experience has been reviewed for applicability. Future operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation. Industry operating experience will be considered when implementing this one-time inspection. Plant operating experience for this activity will be gained as it is implemented near the period of extended operation, and will be factored into the activity. As such, operating experience assures that implementation of the Small Bore Class 1 Piping Inspection 'will confirm material condition relative to the effects of aging such that applicable components will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Columbia operating experience: A review of Columbia operating experience identified other piping being examined by the same techniques and small bore piping that has experienced cracking due to fatigue.The Small Bore Class 1 Piping Inspection is a new one-time inspection activity for which plant operating experience has shown only one occurrence of stress corrosion cracking, and that as one of several contributors to fatigue cracking. The evaluations and examinations to be performed by this activity will use qualified volumetric examination techniques or destructive examination Aging Management Programs Page B-190 January 2010* Confirmation Process Columbia Generating Station License Renewal Application , Technical Information This element is common to Columbia programs and activities that are credited with aging management during the period of extended operation and is discussed in Section B.1.3.

• Administrative Controls This element is common to Columbia programs and activities that are credited with aging management during the period' of extended operation and is discussed in Section B.1.3.
• Operating Experience Based on review of plant-specific and industry operating experience, the identified aging effects require management for the period of extended operation.

The Small Bore Class 1 Piping Inspection provides confirmation of material conditions near the period of extended operation as additional assurance that existing inspections, via the Inservice Inspection (lSI) Program, and control of water chemistry, via the BWR Water Chemistry Program, provide adequate management. Industry operating experience:

• NUREG-1801 is based on industry operating experience through January 2005. Recent industry operating experience has been reviewed for applicability.

Future

• operating experience is captured through the normal operating experience review process, which will continue through the period of extended operation.

Industry operating experience will be considered when implementing this time inspection. Plant operating experience for this activity will be gained as it is implemented near the period of extended operation, and will be factored into the activity. As such, operating experience assures that implementation of the Small Bore C.lass 1 Piping Inspection will confirm material condition relative to the effects of aging such that applicable components will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Columbia operating experience: A review of Columbia operating experience identified other piping being examined by the same techniques and small bore piping that has experienced cracking due to fatigue. The Small Bore Class 1 Piping Inspection is a new one-time inspection activity for which plant operating experience has shown only one occurrence of stress corrosion cracking, and that as one of several contributors to fatigue cracking. The evaluations and examinations to be performed by this activity will use qualified volumetric examination techniques or destructive examination Aging Management Programs Page 8-190 January 2010

• Columbia Generating Station License Renewal Application Technical Information techniques with demonstrated capability and a proven industry record to detect cracking in piping weld and base metal.Several cracks due to vibration induced fatigue or construction flaws occurred in small bore piping during the early years of plant life. Design changes were instituted to reduce vibration and sources of cyclic loading. The occurrence of these small bore leaks has decreased in recent years showing the effectiveness of the actions being taken. No instances of stress corrosion cracking or low cyclefatigue cracking as the sole failure mechanism were identified.

A single instance of small bore Class 1 piping failure related to stress corrosion cracking was found in 1993, which also involved other contributing factors that led to fatigue cracking.The weld was removed and configuration was changed to address the vibration and cyclic loading considerations. No other instances of stress corrosion cracking of small bore Class 1 piping have been identified. The Small Bore Class 1 Piping Inspection will be developed based on relevant plant and industry operating experience. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the one-time inspection confirms material condition such that the existing program (ISI) is demonstrated to be effective in managing the identified aging effects, or a new aging management program will be developed. Required Enhancements Not applicable, this is a new activity.Conclusion The Small Bore Class 1 Piping Inspection will verify that cracking due to stress corrosion and mechanical loading, and cracking due to reduction of fracture toughness are not occurring or are insignificant, such that an aging management program is not required during the period of extended operation. The Small Bore Class 1 Piping Inspection will provide reasonable assurance that the aging effects are not occurring such that components subject to aging management review will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation. Aging Management Programs Page B-191.January 2010* *

• Columbia Generating Station License Renewal Application Technical Information techniques with demonstrated capability and a proven industry record to detect cracking in piping weld and base metal. Several cracks due to vibration induced fatigue or construction flaws occurred in small bore piping during the early years of plant life. Design changes were instituted to reduce vibration and sources of cyclic loading. The occurrence of these small bore leaks has decreased in recent years showing the effectiveness of the actions being taken. No instances of stress corrosion cracking or low cycle fatigue cracking as the sole failure mechanism were identified.

A single instance of small bore Class 1 piping failure related to stress corrosion cracking was found in 1993, which also involved other contributing factors that led to fatigue cracking. The weld was removed and configuration was changed to address the vibration and cyclic loading considerations. No other instances of stress corrosion cracking of small bore Class 1 piping have be,en identified. The Small Bore Class 1 Piping Inspection will be developed based on relevant plant and industry operating experience. The site corrective action program and an ongoing review of industry operating experience will be used to ensure that the time inspection confirms material condition such that the ,existing program (lSI) 'is demonstrated to be effective i'n managing the identified aging effec::ts, or a new aging management program will be developed . Required Enhancements Not applicable,this is a new activity. Conclusion , The Small Bore Class 1 Piping Inspection will verify that cracking due to stress corrosion and mechanical loading, and cracking due tp reduction of fracture toughness are not occurring or are insignificant, such that an aging management program is not required during the period of extended operation. The Small Bore Class 1 Piping Inspection will provide reasonable assurance that the aging effects are not occurring such that components subject to aging management review will continue to perform , their intended functions consistent with the current licensing basis for the period of extended operation . Aging Management Prograrns , PageB-191 January 2010 Columbia Generating Station License Renewal Application Technical Information B.2.50 Structures Monitoring Program Program Description The Structures Monitoring Program is part of the Maintenance Rule program. It is an existing program that is designed to ensure that age-related degradation of the plant structures and structural components within its scope is managed to ensure that each structure and structural component retains the ability to perform its intended function.The Maintenance Rule program is comprised of many existing monitoring and assessment activities, which collectively address potential and actual degradation conditions and their effects upon the reliability of the structures and components that are within the scope of the program.The Structures Monitoring Program implements provisions of the Maintenance Rule, 10 CFR 50.65, which relate to structures, masonry walls, and water-control structures. It conforms to the guidance contained in Regulatory Guide (RG) 1.160, "Monitoring the Effectiveness of Maintenance at Nuclear Power Plants", and NUMARC 93-01, "Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants." Concrete and masonry walls that perform a fire barrier intended function are also managed by the Fire Protection Program.The Structures Monitoring Program encompasses and implements the Water Control Structures Inspection and the Masonry Wall Inspection. Since protective coatings are not relied upon to manage the effects of aging for structural components included in the Structures Monitoring Program, the program does not address protective coating monitoring and maintenance. Aging effects identified within the scope of the Structures Monitoring Program are detected by visual inspection of external surfaces prior to the loss of the structure's or component's intended functions. The Structures Monitoring Program provides reasonable assurance that the effects of aging are adequately managed to assure that plant structures and structural components' intended function will be performed consistent with the current licensing basis for the period of extended operation. NUREG-1801 Consistency The Structures Monitoring Program is an existing Columbia program that, with enhancement, will be consistent with the 10. elements of an effective aging management program as described in NUREG-1801, Section XI.S6, "Structures Monitoring Program." Aging Management Programs Page B-192 January 2010 ,/ Columbia Generating Station License Renewal Application

• Technical Information 8.2.50 Structures Monitoring Program Program Description The Structures Monitoring Program is part of the Maintenance Rule program. It is an existing program that (s designed to ensure that age-related degradation of the plant structures and structural components within its scope is managed to ensure that each structure and structural component retains the ability to perform its intended function.

The Maintenance Rule program is comprised of many existing monitoring and assessment activities, which collectively address potential and actual degradation conditions and their effects upon the reliability of the structures and components that are within the scope of the program. The Structures Monitoring Program implements provisions of the Maintenance Rule, 10 CFR 50.65, which relate to structures, masonry walls, and water-control structures. It conforms to the guidance contained in Regulatory Guide (RG) 1.160, "Monitoring the Effectiveness of Maintenance at Nuclear Power Plants", and NUMARC 93-:01, "Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants." Concrete and masonry Vl(alls that perform a fire barrier intended function are also managed by the Fire Protection Program. The Structures Monitoring Program encompasses and implements the Water Control

• Structures Inspection and the Masonry Wall Inspection.

Since protective coatings are not relied upon to manage the effects of* aging for structural components included in the Structures Monitoring Program, the program does not address protective coating monitoring and maintenance. r Aging effects identified within the scope of the Structures Monitoring Program are detected by visual inspection of external surfaces prior to the loss of the structure's or component's intended functions. The Structures Monitoring Program provides reasonable assurance that the effects of aging are adequately managed to assure that plant structures and structural components' intended function will be performed consistent with the current licensing basis for the period of extended operation. . NUREG-1801 Consistency The Structures Monitoring Program is an existing Columbia program that, with enhancement, will be consistent with the 10 elements of an effective aging management program as described in NUREG-1801, Section XI.S6, "Structures Monitoring Program." Aging Management Programs Page 8-192 January 2010

• Columbia Generating StationLicense Renewal Application Technical Information Exceptions to NUREG-.1801 None.Required Enhancements Prior to the period of extended operation the enhancements listed, below will be implemented in the identified program element:* Scope -Include and list the following structures within the scope of license renewal that credit the Structures Monitoring Program for aging management:
• Circulating Water Basin* Circulating Water Pump House* Condensate Storage Tanks Foundations and Retaining Area* Cooling Tower Basins* Diesel Generator Building* Duct Banks and Manholes* Fire Water Bladder Tank (FP-TK-1 10) Embankment
• Fresh Air Intake Structure No. 1 and 2* Hydrogen Storage and Supply Facility* Makeup Water Pump House* Primary Containment (includes drywel!, biological shield wall, reactor pedestal, sacrificial shield wall, and internal structural components)
• Radwaste Control Building* Reactor Building (includes secondary containment, reactor cavity, refueling area, new fuel storage vault, release stack)* Service Building* Spray Pond 1A and 1B* Standby Service Water Pump House 1A and 1B* Station Blackout component foundations and structures in the yard (includesstartup transformers TR-S, backup transformer TR-B, Ashe A809 breaker, oil circuit breaker (OCB) E-CB-TRB, and Ashe relay house)Transmission Towers Aging Management Programs Page B7193 January 2010** * * \ Columbia Generating Station License Renewal Application Technical Information Exceptions to NUREG**1801 None. Required Enhancements Prior to the period of extended operation the enhancements listed, below will be implemented in the identified program element:
• Scope-Include and list the following structures within the scope of license renewal that credit the Structures Monitoring Program for aging management:

.* Circulating Water Basin

• Circulating Water Pump House
• Condensate Storage Tanks Foundations and Retaining Area
• Cooling Tower Basins
• Diesel Generator Building
• Duct Banks and Manholes
• Fire Water Bladder Tank (FP-TK-110)

Embankment

• Fresh Air Intake Structure No.1 and 2
• Hydrogen Storage and Supply Facility
• Makeup Water Pump House
• Primary' Containment (includes drywel.l, biological shield wall, reactor pedestal, shield wall, and internal structural components)
• Radwaste Control Building
• Reactor Building (includes secondary containment, reactor cavity, refueling area, new fuel storage vault, release stack) * . Service Building
• Spray Pond 1 A and 1 B
• Standby Service Water Pump House 1A and 1 B
• Station Blackout component foundations and structures in the yard (includes startup transformers TR-S, backup transformer TR-B, Ashe A809 breaker, oil circuit breaker (DC B) E-CB-TRB, and Ashe relay house)
• Transmission Towers Aging Management Programs Page January 2010 Columbia Generating Station License Renewal Application Technical Information
• Turbine Generator Building* Water Filtration Building Enhancements to this element for the Structures Monitoring Program also include enhancements that are being made to the Water Control Structures Inspection.

See the Water Control Structures Inspection for required enhancement details.Parameters Monitored or Inspected -Specify that if a below grade structural wall or structural component becomes accessible through excavation; a follow-up action is initiated for the responsible engineer to inspect the exposed surfaces for age-related degradation prior to backfilling. Identify that the term "structural component" for inspection includes componenttypes that credit the Structures Monitoring Program for aging management. Include the potential degradation mechanism checklist in the procedural documents. The checklist also requires enhancement to include aging effect terminology (e.g., loss of material, cracking, change in material properties, and loss of form).Specify that the responsible engineer shall review site groundwater and raw water testing results for pH, chlorides, and sulfates prior to inspection to validate that the below-grade or raw water environments remain non-aggressive during the period of extended operation. Chemistry data shall be obtained from Columbia's chemistry and environmental departments. Groundwater chemistry data shall be collected at least once every four years. The time of data collection shall be staggered from year to year (summer-winter-summer) to account for seasonal variations in the environment. Enhancements to this element for the Structures Monitoring Program also include enhancements that are being made to the Water Control Structures Inspection and the Masonry Wall Inspection. See the Water Control Structures Inspection and the Masonry Wall Inspection for required enhancement details.Operating Experience The Structures Monitoring Program has been effective in managing the identified aging effects. Although actual experience with Structures Monitoring Program inspections is limited, recent inspection results have shown that plant structures are maintained in good condition. No significant failures have occurred in any Columbia structure to date.Aging Management Programs Page B-1 94 January 2010* Turbine Generator Building

• Water Filtration Building Columbia Generating Station License Renewal Application Technical Information Enhancements to this element for the Structures Monitori'ng Program also include enhancements that are being made to the Water Control Structures Inspection.

See the Water Control Structures Inspection for required enhancement details.

• Parameters Monitored or Inspected

-Specify that if a below grade structural wall or structural component becomes accessible through excavation; a follow-up action is initiated for the responsible engineer to inspect the exposed surfaces for age-related degradation prior to backfilling. Identify that the term "structural component" for inspection includes component types that credit the Structures Monitoring Program for aging management. Include the potential degradation mechanism checklist in the procedural documents. The checklist also requires enhancement to include aging effect

• terminology (e.g., loss of material, cracking, change in material properties, and
• loss of form). Specify that the responsible engineer shall review site groundwater and raw water testing results for pH, chlorides, and sulfates prior to inspection to validate that the below-grade or raw water environments remain non-aggressive during the period of extended operation.

Chemistry data shall be obtained from Columbia's chemistry and environmental departments. Groundwater chemistry data shall be collected at least once every four years. The time of data collection shall be staggered from year to year (sum'mer-winter-summer) to account for seasonal variations in the environment. ' Enhancements to this element for the Structures Monitoring Program also include enhancements that are being made to the Water Control Structures Inspection and the Masonry Wall Inspection. See the Water Control Structures Inspection and the Masonry Wall Inspection for required enhancement details. Operating Experience The Structures Monitoring Program has effective in managing the identified effects. Although actual experience with Structures Monitoring Program inspectio'ns is limited, recent inspection results have shown that plant structures are maintained in good condition. No significant failures have occurred in any Columbia structure to date . Aging Management Programs Page 8-194 January 2010

• Columbia Generating Station License Renewal Application Technical Information Normal deterioration due to the effects of aging has been 'identified and effectivelymanaged under the site maintenance program.Visual examinations conducted by the Structures Monitoring Program have found general corrosion on steel components and concrete cracking, flaking, and scaling.Some of the currently identified concrete surface conditions have existed since original construction.

These conditions are the results of typical construction practices permitted by the original specifications and design criteria. They include small shrinkage cracks, minor construction joint voids, surface irregularities, and similar conditions determined to be minor degradation that did not require further evaluation. Inspected structures are in good condition and are capable of performing their design functions. Specific examples of age-related degradation identified by the Structures Monitoring Program include:* Circulating water pump house -Minor leaching observed on the concrete pad near the interface with the siding, cracks in the wall along joints due to stresses caused by a hanger attached to the wall above door, corrosion on the lower section of various door frames, and minor cracking of concrete damwork around the intake bays.* Turbine generator building -Air in-leakage noted at north exterior, turbine generator building wall panels, degraded roof membrane, and minor water in-leakage from roof above.* Radwaste control building -Some areas of concrete spalling in the switchgear rooms probably from racking breakers in and out, delaminated floor coatings, and punctured roof membrane from screws." Wetwell -Support steel has layer of corrosion products, condition was unchanged from previous inspections. The condition was reviewed by the material group which determined the condition of the wetwell and containment liner to be acceptable." Main steam tunnel -Some flaking of coating on the overhead horizontal panels, the condition was unchanged from previous inspections and determined to be acceptable. The overall Maintenance Rule program is comprised of many existing monitoring and assessment activities that collectively address potential and actual degradation conditions. The Maintenance Rule program screens all condition reports written at Columbia. When a condition report addresses a structure issue it is reviewed by a system engineer for evaluation of a functional failure. The screening resu}}