ML20204G485

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Forwards for Review & Approval,License Renewal Insp Plan for Calvert Cliffs Nuclear Power Plant.Insp Plan Developed Through Cooperative Effort Among Members of All Four Regions,Nrr,Ogc & OE
ML20204G485
Person / Time
Site: Calvert Cliffs  Constellation icon.png
Issue date: 01/07/1999
From: Charemagne Grimes
NRC (Affiliation Not Assigned)
To: Collins S
NRC (Affiliation Not Assigned)
References
NUDOCS 9903260158
Download: ML20204G485 (28)
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Text

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UNITED STATES NUCLEAR REGULATORY COMMISSION f"4-8/7 7/[

\*****/ January 7, 199 MEMORANDUM TO: Samuel J. Collins, Director qp (

Office of Nuclear Reactor Reg on >

THROUGH: David 8 Matthews, Director Division of Reactor Program Management FROM: Christopher Grimes, Project Director -

License Renewal Project Directorate Division of Reactor Program Management i Office of Nuclear Reactor Regulation

SUBJECT:

CALVERT CLIFFS NUCLEAR POWER PLANT LICENSE RENEWAL INSPECTION PLAN Attached for your review and approval is the license renewal inspection plan for Calvert Cliffs Nuclear Power Plant. This inspection plan was developed through a cooperative effort among members of all four regions, NRR, OGC and OE. Calvert Cliffs license renewalinspection activities will be supported by Region I, Region 11, and NRR. The use of consultants is an option if specialized skills are needed, but is currently not planned.

Reflect your approval by signing the attached inspection plan, and returning it to me. Note that Region I has approved the attached plan on December 22,1998.

Upon receiving your approval, Region I and PDLR will meet with Baltimore Gas and Electric Company to discuss the planned inspection activities. In addition, any requested changes to this inspection plan during implementation will be processed through License Renewal Project Directorate (PDLR), as directed in Inspection Procedure - 71002, " License Renewal In;pection."

All appropriate revisions will be approved after consultation with Region 1.

Attachment:

As stated cc: Hubert Miller, Rl Michael Modes, RI

.F05 i i l 9903260158 990107 ,

PDR ADOCK 05000317 G PDR l

i CALVERT CLIFFS NUCLEAR POWER PLANT LICENSE RENEWAL INSPECTION PLAN I PURPOSE This inspection plan provides Region 1 with guidance for implementing Inspection Manual Chapter 2515 and 2516 requirements for the verification of information, programs and activities relating to 10 CFR Part 54 (from herein referred to as "the rule") and the Calvert Cliffs Nuclear Power Plant (CCNPP) license renewal programs and activities. This plan defines the scope of the inspections planned to verify that the CCNPP's license renewal program is in compliance with the requirements of the rule, and is consistent with BGE's license renewal application (LRA) and the staff's safety evaluation of BGE's LRA. This plan also provides guidance for inspection scheduling, inspector training, inspection activities, resource requirements, and resource allocation.

Attachment 1 contains a list of systems, structures, and commodity groups within the scope of this inspection plan. Attachment 2 contains a list of definitions used by BGE in its LRA, and this inspection plan. Attachment 3 is a list of acronyms applicable to BGE inspection activities for license renewal Attachment 4 contains a list of reference material.

ll OBJECTIVES The overall objective of this instruction is to provide guidance for inspecting the implementation, and effectiveness of the programs and activities asso:iated with BGE's license renewal program to verify that there is reasonable assurance that the effects of aging will be adequately managed such that the intended function (s) of structures and components' requiring an aging management review will be maintained consistent with the current licensing basis (CLB) during the period of ex+ ended operation. To accomplish this objective, the inspection team will perform the followin; % ection activities on a sample of systems, structures and commodity groups within the u f a nf this inspection plan (refer to Attachment 1), to verify, with reasonable assurance, n ? 'he requirements of 10 CFR Part 54 have been fulfilled:

1. '/erify that the scoping (10 CFR 54.4) and screening (10 CFR 54.21[a][1]) activities implemented by BGE are consistent with the rule, BGE's methodology submitted for staff review, the staff's safety evaluation of that methodology, the guidance provided in DG-1047,

" Standard Format and Content for the Application to Renew Nuclear Power Plant Operating Licenses," dated August 1996, and documented staff positions, as applicable.

2. Verify that the aging management programs were implemented consistent with the rule, the LRA, the staff's safety evaluation of the LRA (SER), and NRC approved guidance including the Statement of Consideration, DG 1047, and documented staff positions.

' Reference footnote in SOC on page 60 FR 22462 for clarification between SSC and SC.

l 3. Verify that there is reasonable assurance that the demonstration provided by BGE is l consistent with the rule, LRA, staff's SER, and the results from implementing the aging j management programs at CCNPP.

4. Verify that the information and documentation required by, or otherwise necessary to l document compliance with the provisions of the rule are maintained in an auditable and l retrievable form.

111 INSPECTION REQUIREMENTS Each inspector will receive basic license renewal inspection program (LRIP) training. As an

alternate to the LRIP training, inspectors will read the list of reference material provided in j Attachment 4. In addition, the inspection team will be provided team training on the CCNPP LRA and the staff's safety evaluation of that appleation. Training will be given as part of the inspection preparation effort.

The acceptance criteria for the staff verification activities will be derived from the rule, the 2 description of the programs and activities as documented in the LRA, and the documented review performed by the staff in the safety evaluation report. To verify the completeness of the scope selected by BGE, the staff will review five systems and three structures not identified as being within the scope of the rule by the applicant against the scoping criteria under 10 CFR 54.4(a) to identify potential omissions from the scope selected by the applicant. In addition, the staff will perform system walk-downs and review maintenance history to confirm that applicable aging effects have been identified in the LRA.

Consistent with the Commission guidance in the SOC, probabilistic methods may be used as a supplemental tool to assess the relative importance of structures and components that are subject to an aging management review by drawing attention to specific vulnerabilities (e.g.,

results of an IPE or IPEEE). Probabilistic insights may assist in developing an approach for aging management adequacy. However, probabilistic insights alone will not be an acceptable basis for concluding that, for those structures and components subject to an aging management review, the effects of aging will be adequately managed in the period of extended operation. '

IV INSPECTION ACi VITIES The LRIP will be implemented at CCNPP, prior to the approval of its LRA to verify that BGE meets the requirements of the rule and has implemented license renewal programs and activities consistent with the rule, their application, and the staff's safety evaluation report (SER) of the LRA, Commission and staff approved guidance, and documented staff positions, as applicable.

2 The changes noted above were made subsequent to Region 1 initial approval on 12/22/98. These changes were discussed with and approved by James Wiggins j of Region 1 on 1/26/99.

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Inspection Procedure (IP) 71002, " License Renewal Inspections," will be the primary procedure used to inspect BGE's implementation of the requirements of the rule. Various other IPs will be

, used to verify the implementation of the individual aging management programs. This l inspection plan will be used to define the inspection activities and the implementation of these activities.

This inspection plan will be reviewed and approved by NRR and the Region l Regional Administrator prior to implementatit n. Substantive changes to the approved inspection plan will be approved by the Director, License Renewal Project Directorate, NRR or his designee. After inspection activities begin, changes to the inspection plan will be approved and documented as an attachment to the original plan.

The basic scope of the CCNPP inspection will be performed on the systems, structures, and commodity groups identified in Attachment 1 attached to this plan. The selection of these systems, structures, and commodity groups is based on risk / safety significance, uniqueness to CCNPP, and current issues.

1. The inspection team will verify that BGE implemented the scoping methodology consistent with the rule, BGE's methodology submitted for staff review on August 18,1995, and amended on January 11,1996, and the staff's safety evaluation of that methodology dated April 4,1996. The inspection team will also inspect the results of five systems and three structures not included within the scope of the rule by BGE's process to verify that there is reasonable assurance that all systems and structures that meet the criteria under 10 CFR 54.4 were identified. The inspection team will use IP-71002, 02.02.b and f 03.02.b for this inspection.
2. The implementation of screening activities required under 10 CFR 54.21(a)(1) will be inspected by reviewing the evaluation boundaries, intended functions, and active / passive or short-/long-lived characteristics of the structures and components (SC) included within the scope of BGE's aging management review for the systems, structures and commodity groups listed in Attachment 1. These inspection activities will be implemented to verify that BGE's process was implemented consistent with the rule, BGE's methodology submitted for staff review, and the staff's safety evaluation of that methodology. The inspection team will also walkdown the systems and structures, as available, to identify any observable inconsistencies w!th the scoping and screening activities. The inspection team will use IP-71002, f 02.02.c.10nd f 03.02.c.1 for this inspection.

For more information on the screening activities refer to the following reference:

. system-/ structural-level intended function (s) refer to 10 CFR 54.4(a),54.4(b),

54.21(a)(1)(i),60FR22467, and NEl 95-10,@3.2;

. evaluation boundaries refer to 60FR22467, and NEl 95-10, @4.1.1;

. component-/ structural component-level intended function (s) refer to 60FR22467, and NEl 95-10, @4.1.2; j . active / passive determination as defined under 10 CFR 54.21(a)(1)(i) refer to 60FR22477, and NEl 95-10, @4.1.2 and Attachment 8, and l

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l-short-/long-lived determirunon as defined under 10 CFR 54.21(a)(1)(ii) refer to 60FR22478, and NF! 95-10, S4.1.2.

3. The inspection team will verify that there is reasonable assurance that evident aging effects a (Refer to 60FR22468, and NEl 95-1,@ 4.2.1.1) for the systems, structures and components requiring an aging management review have been identified by BGE. Although the aging )

j effects identified by BGE will be reviewed during the technical review, the inspection team '

willidentify any aging effects observed during walkdowns and physicalinspections of the different systems, structures and commudity groups that are not included in the LRA as applicable. In addition, the inspection team will perform a samp!e inspection of related maintenance records of the systems, structures and comm0dity groups from Attachment 1 to identify ongoing aging not identified by BGE. The inspection team will use IP-71002, f ,

02.02.c.2 and f 03.02.c.2 for this inspection. l

4. The inspection team will inspect the aging management programs (Refer to 60FR22474 1 and NEl 95-10,6 4.2.1.2) for approximately half of the aging effects in each of the systems, structures, and commodity groups identified in Attachment 1. The inspections will be used  !

to verify that BGE implemented the aging management programs as identified in its LRA and the staff's safety evaluation. The inspection team will also perform a sample inspection of related maintenance records for the systems, structures and commodity groups in Attachment 1 to identify ongoing aging that is not being managed consistent with the aging

. management programs in p; ace. The inspection team will also walkdown systems and structures, and inspect structures and components, as plant conditions allow, to identify ongoing aging that is not being managed. Based on their observations from these inspection activities, the inspection team will document their findings relative to the effectiveness of an aging management program to maintain an intended function (s) consistent with the CLB for the period of extended operation. The inspection team will use

/P-71002, J 02.02.c.3, and J 03.02.c.3 to inspect the implementation activities. The inspection of the aging management programs and resulting effectiveness from implementing these programs will be performed by using variety of existing Inspection procedures from the IMC 2515 inspection program as applicable.

5. An inspection of BGE's supporting information and objective evidence relating to the demonstration (Refer to 10 CFR 54.21(a)(3), and NEl 95-1, G4.2.1.3,6 4.2.2.2, and @

4.2.3.2) of the aging management programs inspected in item 4 above, including a review of program documentation and a review of the applicable maintenance will be used to verify that there is reasonable assurance that the demonstrations provided by BGE are consistent and complete with the results from implementing the applicable aging management programs at CCNPP. The inspection team will use IP-71002, f 02.02.c.4, J 03.02.c.4, and IMC 2515 inspection procedures for this inspection activity.

6. An inspection of the documentation for the programs and activities relating to the scoping, screening, aging management, and demonstrations will be used to verify that the information and documentation (Refer to 10 CFR 54.21 and 54.37,60FR22482, and NEl 95-1, 3.3,S4.4, 5.3, and @ 6.0)) required by, or otherwise necessary to document compliance with, the provisions of the rule are maintained in an auditable and retrievable form. The inspection team will use IP-71002 for this inspection activity.

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1 V PLANMED INSPECTIONS i

The CCNPP license renewal inspection activities will be implemented through four site- 1 inspections. Each inspection will basically consist of one week of preparation, one week of on- l site inspection, and approximately one week of report writing.

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1. First irspection - The first inspection will primarily consist of an inspection of the scoping l and screening process described above (IV.1 and IV.2) to verify that these processes have  ;

been implemented consistent with the rule, BGE's methodology, and the staffs safety evaluation of BGE's methodology. This inspection must be performed after the staff's j safety evaluation of the scoping and screening methodology is complete. In addition, this  !

inspection will be used to verify that there is reasonable assurance that the implementation of BGE's scoping and screening processes has identified the systems, structures, and components, requiring an aging management review that is consistent with the requirements of the rule.

The first inspection includes the following:

a. Prior to the inspection preparation week, the Team Leader will review this inspection plan, BGE's methodology, the staffs safety evaluations of the methodology, and the LRA to assign various inspection activities to individual team members for detailed  ;

review during inspection prenaration. The goal for assigning these inspection activities is to allow each team mera' to become familiar with the scope of the inspection, and  :

for each team member te ; a 1re for their role in the inspection process.

b. During preparation week, the Team will review the necessary documentation. For the systems, structures, and commodity groups assigned to each inspection. the inspector will prepare to verify that BGE implemented its methodo,ay consistent with the rule, the methodology in its LRA, the staffs safety evaluation of that methodology, NRC approved guidance, and documented staff positions. The inspector will review the system-/ structural-level intended functions identified by BGE to verify that they fulfill the requirements and criteria of the rule and the applicable guidance documents. The inspectors will familiarize themselves with the systems and structures assigned cnd its evaluetion boundaries to identify any components or structural components not included within the eva!uation boundary that may fulfill the intended functions relating to the scoping criteria under 10 CFR 54.4. The inspectors will prepare to inspect the active / passive and the long Ishort-lived determination to verify that they were made consistent with the rule, staff approved guidance, and staff positions,
c. During the on site inspection, the team will implement the inspection activities defined in Sections IV.1, IV.2, and IV.6 of this inspection plan.
d. During the week following the on-site inspection, the team members will submit their documented findings within the time specified by the team leader. The team leader will develop the final inspection report consistent with regional practices.

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2. - Second Inspection The second inspection is expected to be performed in the following i sequence: one-week preparation; one-week of inspect;on; one week return to region for review, interim report writing, and adiustment to inspection plan; another week of inspection; '

and one week to write the inspection report. This inspection will be the heart of the aging management review and demonstration inspection. The second inspection should not begin until the "SER with open items" (currently scheduled for March 21,1999) is complete.

For the aging management review inspections, the inspector will verify, with reasonable j assurance, that BGE's aging management programs and activities have been implemented  !

completely, correctly, and consistent with the regt'irements of the rule, BGEs' LRAs, the  ;

staff's review of the application as documented in the SER, and site-approved program and l procedures.

a. Prior to the inspection preparation week, the team leader will review this inspection plan, the inspection report for the first inspection, and the LRA to assign various inspectiort activities to individual team members for detailed review during inspection preparation. The goal for assigning these inspection activities is to allow each inspection team member to become familiar with the scope of the inspection, and for each team member to prepare for their role in the inspection process.
b. During preparation week, the team will review the necessary documentation. For the systems, structures, and commodity groups assigned to each inspection, the inspector will verify that BGE's aging management review and demonstration was implemented consistent with the rule, BGE's LRA, the staff's safety evaluation of the LRA, the Commission and staff approved guidance, and documented staff positions, as applicable.
c. During the on-site inspection, the team will implement the inspection activities aefined in Section IV.3, IV.4, IV.5 and IV.6 of this inspection plan.
d. During the week following the second week of on-site inspection, the team members will submit their documented findings within the time specified by the team leader. The team leader will develop the final inspection report consistent with regional practices.
3. Third Inspection - The third inspection will primarily be used to followup on previous inspection activities and to inspect BGE actions relating to SER open items. This inspection should be performed about 30 days prior to final licensing action,
a. Prior to the inspection preparation week, the team leader will review this inspection plan, the inspection reports to the first two inspections, and input from the program office to assign various inspection activities to individual team members for detailed review during inspection preparation. The goal of this review will be to allow each inspection team member to become familiar with the scope of the inspection, and for each team member to prepare for their role in the inspection process.

l l b. Dunng preparation week, the team will review the necessary documentation to prepare

[ for the scope of this inspection as agreed upon by Region 1 and the program office.

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c. Team members will perform the inspection activities under Section IV, as assigned by the team leader. Other inspection activities, such as verifying the completion of an SER open items or inspection followup items will be performed using standard )

inspection practices and/or existing inspection procedures, as applicable. Special instructions will be documented, as necessary.

d. The staff's technical review of the LRA and resulting SER may result in specific inspection activities. PDLR will keep track of all required and recommended inspe ction  ;

activities resulting from the technical review. POLR will provide the team with a L of  !

these inspection activities and coordinate any clarification or discussions necessary to implement these activities. These inspection activities may be performed anytime throughout the inspection process. However, the third inspection will be used to verify that all required inspection activities are completed, and that any recommended activity, especially those within the scope of the inspection plan, were adequately considered.

e. Any followup items resulting from the first two inspections and any additional system, structural, component, or commodity grcup visual inspections, as arranged with BGE, will be performed during this inspection. In addition, any recommended visual inspection identified in one of the LRIP inspections can be performed by the resident or regional personnel at a later date if the component is not accessible during any of these inspections. The third inspection report should document the need for specific future inspections and identify the steps that have been taken to coordinate any future inspections with BGE.
f. Any inspection activities associated with enforcement items will be performed using standard inspection practbes and/or existing inspection procedures, as applicable.

Special instructions will be documented, as necessary.

As part of the above specified inspection activities for each of the three inspections, the inspection team will verify that the information and documentation required by, or otherwise necessary to document comptance with, the provisions of the rule are being maintained in an auditable and retrievable form wherever applicable throughout the inspection process.

INSPECTION RESOURCES:

The inspection resource will consist of the following positions and skills for the BGE inspections:

1. Inspectors - positions

. 1 Team leader

. 2 Regional based inspectors (1 senior inspector) l

. 1 Inspector with site-specific knowledge

. 1 Region 11 inspector (team leader for the Oconee Nuclear Station inspections) i

. 1 Support staffer from program office l

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2. Inspectors - skills - the inspection team needs a cross-section of skills including mechanical, material, civil and electrical engineering skills i

The scope of the third inspection (and correspondingly, the resources) will vary depending i on followup inspection activities, and the number of inspection requests. Therefore the third 1 inspection team will be made up of 3 to 6 inspectors with the skills determined necessary {

after the tnird inspection. 1 i

3. Resource Recon,mendations. ,

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. 4 weeks of inspection 5-7 inspectors per inspection 1 week preparation per inspection

. 1 week on-site inspecting

. 3 days reporting writing for each inspector 1 week for each team leader to finalize his/her inspection report 1 week processing inspection report At least one inspection performed during an outage to allow the inspectors to inspect the material condition of the SCs within the scope of the rule.

4. Resources Estimates:

6 inspectors X 4 inspection wks (1 wk prep +1 wk inspecting +3 days report writing) = 62.4 wks 62.4 wks + 2 wks (tearn leader) : 64.4 inspection wks i Training Resources - In addition to inspection activities, members of the inspection team need training. PDLR plans to provide two days of training on the rule and inspection ,

procedures prior to the beginning of inspection activities. In addition, BGE has volunteered i to provide background information on the LRA to the inspection team as part of inspection preparation

. 2 PDLR staff members X 3 days / sessions + 6 inspectors X 2 days / sessions = 15 person-days 15 person-days X 4 regions x 60 person-days + 5 person-days admin. support = 13 person wks.

Approved: /CfffR N l1 1 Date: 1 DM Samuel J! Collins, Office Director Office of Nuclear Reactor Regulation Approved: William L. Axelson for Date: 12/22/98 Hubert J. Miller, Regional Administrator Region I

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  • SYSTEMS, STRUCTURES, AND COMMODITY GROUPC Attachment la Systems. Aging Effects Aging Management Structures. Programs Commodity Groups Auxihary Feed *ater Crevice Corrosion Secondary Chemistry Specification and Surveillance Program l Demin. Water Chemistry Specification and Surveillance Program Age Related Degradation inspection Program
  • Visual inspections Buned Piping inspections
  • Preventive Maintenance l Erosion / Corrosion Age Related Degradation inspection Program
  • Secondary Chemistry Specification and Surveillance Program Galvanic Corrosion Buned Piping Inspections
  • General Corrosion Secondary Chemistry Specification and Surveillance Program Demin. Water Chemistry Specification and Surveillance Program Age Related Degradation Inspection Program
  • l Visual inspections l Buned Piping Inspections
  • Preventive Maintenance MIC Buned Piping inspections *

! Pitting Secondary Chemistry Specification and Surveillance Program Demin. Water Chemistry Specification and Surveillance Program Age Related Degradation Inspection Program

  • Visual Inspections Preventive Maintenance Elastomer Degradation Age Related Degradation inspection Program
  • Caulking / Sealant inspection
  • Wear Age Related Degradation Inspection Program

Boric Acid Corrosion Inspection Program Fatigue Fatigue Monitonng Program Galvanic Corrosion Boric Acid Corrosion inspection Program (MN-3-301)

Visual inspections i

ISI of ASME Section XI Components (MN 3-110)

S/G Pnmary Manway Cover Removal and Installation (SG-20)

S/G Eddy Current Testing (STP-M-5741/2)

General Corrosion Boric Acid Corrosion Inspection Program (MN 3-301) i l l ' 1 i e .

l Visual inspections ISI of ASME Section XI Components (MN-3-110)

S/G Pnmary Manway Cover Removal and Installation (SG 20)

S/G Eddy Current Testing (STP-M 574-1/2)

Intergranular Attack Specification and Surveillance Primary Systems (CP-204)

Spec. and Surv. for Component Cooling / Service Water Sys (CP-206)

Pitting S/G Eddy Current Testing (STP-M-5741/2) l I

Stress Corrosion Cracking Specification and Surveillance Pnmary Systems (CP 204)

Alloy 600 Program l l

Rx Vessel Flange Protection Ring Removal and Closure Head Install.(RV 78)

Bonc Acid Corrosion Inspection Program S/G Eddy Current Testing (STP-M-5741/2)

ISI of ASME Section XI Components (MN-3110)

Torquing and Fastener Applications (FASTENER 01) l Intergranular SCC Specification and Surveillance Primary Systems (CP-204)

Alloy 600 Program Plan Ax Vessel Flange Protection Ring Removal and Closure Head install (RV '8)

Bonc Acid Corrosion inspection Program S/G Eddy Current Testing (STP-M-5741/2)

ISI of ASME Section XI Components (MN 3110)

Torquing and Fastener Applications (FASTENER-01)

Primary Water SCC Specification and Surveillance Primary Systems (CP-204)

Alloy 600 Program Plan Rx Vessel Flange Protection Ring Removal and Closure Head Install.(RV 78)

Boric Acid Corrosion inspection Program S/G Eddy Current Testing (STP M-574-1/2)

IN of ASME Section XI Components (MN-3-110)

Torquing and Fastener Applications (FASTENER-01)

! Thermal Embnttle CASS Evaluation Program

Boric Acid Corrosion inspection Program Primary Manway Cover Removal and installation (RCS 10)

S/G Manway Cover Removal and Installation (SG-1/2) l S/G Secondary Hanc' hole Cover Removal and Installation (SG 1/2) l S/G Eddy Current Testing (STP-M-5741/2)

ACS Leakage Evaluation (STP-O-27-1/2)

S/G Pnmary Manway Cover Removal and Installation (SG-20) 120 VAC Vital Bus ' Cable Treeing Age Related Degradation inspection Program

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l Cable Thermal Aging Age Related Degradation inspection Program

  • Electncal Preventive Maintenance (EPM)

Cable Thermal and Age Related Degradation inspection Program

  • Radiation Aging Instrument Cakbration Program (MN 1211)

Cable IR Reduction Instrument Cakbration Program (MN 1-211)

EC' Dynamic Load Electncal Preventive Maintenance (EPM)

Age Related Degradation Inspection Program

  • EC Electncal Stressors Preventive Maintenance Program Admin Procedure MN 1 102 Electrical Preventive Maintenance (EPM)

Age Related Degradation Inspection Program

  • Fatigue Electrical Preventive Maintenance (EPM)

Age Related Degradation Inspection Program

  • General Corrosion Preventive Maintenance Program - Admin Procedure MN 1102 Age Related Degradation Inspection Program
  • Wear Preventive Maintenance Program - Admin Procedure MN-1-102 l Preventive Maintenance Program - Admin Procedure MN-1-102 l Age Related Degradation inspection Program
  • l Salt Water Crevice Corrosion Age Related Degradation inspection Program
  • l Preventive Maintenance Program Admin Procedure MN 1 102 l

Spec. and Surv. for Component Coohng/ Service Water Sys (CP-206)

Elastomer Degradation Preventive Maintenance Program - Admin Procedure HN 1 102 Spec. and Surv. for Component Coohng/ Service Water Sys (CP-206)

Erosion / Corrosion Spec. and Surv. for Component Cooling / Service Water Sys (CP-206)

Galvanic Corrosion Preventive Maintenance Program - Admin Procedure MN-1-102 General Corruton Age Related Degradation Inspection Program

  • Preventive Maintenance Program - Admin Procedure MN-1-102 Spec. and Surv. for Component Coohng/ Service Water Sys (CP-206)

MiC Age Related Degradation Inspection Program

  • Preventive Maintenance Program - Admin Procedure MN-1 102 Spec. and Surv. for Component CoahnryService Water Sys (CP-206)

Particulate Wear Erosion Preventive Maintenance Program - Admin Procedure MN 1-102 Age Related Degradation Inspection Program

  • Pitting Age Related Degradation Inspection Program
  • Preventive Maintenance Program - Admin Procedure MN-1 102 Spec. and Surv. for Component Cooling / Service Water Sys (CP-206)

Safety injection Crevice Corrosion Specification and Surveillance Pnmary Systems (CP-204)

Spec. and Surv. for Component Coohng' Service Water Sys (CP-206)

Demin. Water Chemistry Specification and Surveillance Program- CP-202 STP M-571L 1/2, STP M-571G-1/2 Age Related Degradation Inspection Program

  • Fatigue Fatigue Management Program General Corrosion Bone Acid Corrosion inspection Program Program Specification and Surveillance Pnmary Systems (CP-204)

Spec and Sury. for Component Cooling / Service Water Sys (CP-206)

Demin. Water Chemistry Specification and Surveillance Program (CP-202)

STP M 571L-1/2, STP M-571G 1/2 Age Related Degradation inspection Program

  • MIC Age Related Degradation inspection Program
  • Pitting Specification and Surve.Ilance Pnmary Systems (CP-204)

Spec. and Surv. for Component Cooling' Service Water Sys (CP-206)

Demin. Water Chemistry Specification and Surveillance Program (CP 202)

STP M-571L 1(2), STP M-571G-1/2 Age Related Degradation inspection Program

System and Structure Walkdown (MN 1-319)

Age Related Degradation inspection Program

  • Weathenng System and Structure Walkdown (MN 1319)

Component Cooling Crevice Corrosion Spec. and Sury. for Component Cooling / Service Water Sys (CP 206)

Age Related Degradation Inspection Program '

Erosion / Corrosion Age Related Degradation Inspection Program

Age Related Degradation Inspection Program

Age Related Degradation inspection Program

  • Rubber Degradation STP M-571E 1 STP M-571E-2 LLRT Selective Leaching Spec. and Surv. for Component Cooling / Service Water Sys (CP 206)

Age Related Degradation inspection Program' Wear STP M-571E 1 STP M-571E 2 Age Related Degradation Inspection Program

  • LLRT Control Room and Crevice Corrosion System and Structure Walkdown (MN-1-319)

D'G Building HVAC Preventive Maintenance Age Related Degradation inspection Program '

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Dynamic Loading System and Structure Walkdown (MN :-319)

Elastomer Degradation System and Structure Walkdown (MN 1319)

Preventive Maintenance Age Relawf Oegradation inspection Program

  • General Corrosion System and Structure Walkdown (MN-1319)

Preventive Maintenance Age Related Degradation Inspection Program

  • MIC System and Structure Walkdown (MN-1319)

Preventive Maintenance Age Related Degradation inspection Program

  • Pitting System and Structure Walkdown (MN-1-319)

Dreventive Maintenance ,

1 Age Related Degradation inspection Program *  !

Wear System and Structure Walkdown (MN-1-319)

Preventive Maintenance

Age Related Degradation inspection Program
  • 125 VDC' Cable Treeing Age Related Degradation Inspection Program
  • Cable Thermal Aging Age Pelated Degradation inspection Program
  • Electrical Preventive Maintenance Program Cable Thermal and Age Related Degradation inspection Program
  • Radiation Aging Electrical Preventive Maintenance Program Cable IR Reduction instrument valibration Program (Admin. Procedure MN-1-211)

EC' Dynamic Load Electrical Preventive Maintenance Program Age Related Degradation Inspection Program

  • EC Electncal Stressors Electrical Preventive Maintenance Program Age Related Degradation Inspection Program
  • Fatigue Preventive Maintenance Program - Admin Procedure MN 1 102 Age Related Degradation Inspection Program
  • General Corrosion Preventive Maintenance Program Admin Procedure MN-1 102 Age Related Degradation inspection Program
  • Wear Preventive Maintenance Program Admin Procedure MN-1 102 Age Related Degradation inspection Program
  • Fire Protection General Aging System and Structure Walkdown (MN 1-319) l General Aging Conduct of Operation (Admin. Procedure NO-1 100) 1 I

General Aging Age Related Degradation inspection Program

  • l General Aging FP Surveillance Program

. Crevice Corrosion Age Related Degradation inspection Program

  • General Corrosion Age Related Degradation inspection Program
  • l l

- . = . - - - - - _ - . -

9 Boric Acid Corrosion Inspection Program Pitting Age Related Degradation inspection Program

  • Pnmary Corrosion of Steel Protective Coating (Admin. Procedure MN 3-100)

Containment System and Structure Walkdown (MN-1319)

STP-M-661 1/2 Corrosion of Tendons STP-M 663-1/2 Loss of Prestress STP-M-665-1/2 Weathenng STP-M-663-1/2 Corrosion of Refueling System and Structure Walkdown (MN 1319)

Pool and PCSR Liner General Corrosion STP-M 6651/2 Auxiliary Buslding Corrosion of Steel System and Structure Walkdown (MN-1-319) and SR D/G Duilding Structures Corrosion of SFP Liners Operating Manual NO 1201 Operating Manual NO-1-203 Performance Evaluation Program (PE 0-67-2-O M)

Weathenng STP F 592-1/2 Degradation of Engineenng Test Procedure-ETP 86-03R (Admin. Procedure EN-4-101)

Carborundum Degradation of Boraflex Engineering Test Procedure-ETP 86 03R (Admin. Procedure EN 4101)

Matenal intake structure Aggressive Chemical Preventive Maintenance Program Admin Procedure MN 1 102 Attack of Concrete

~

1 Corrosion of Embedded Preventive Mamtenance Program Admin Procedure MN 1 102 Steel /Rebar System and Structure Walkdown (MN-1319)

Corrosion (Crevice System and Structure Walkdown (MN-1319)

Corrosion. General Corrosion. Pitting MIC)

Weathenng STP-F 5921/2 Component General Corrosion of Steel Protective Coating Supports -

Inservice Inspection Baseline Walkdowns

  • Age Related Degradation Inspection Program '

System Walkdowns PEG - 7 Operations inspections NO-1-200 1

Housekeeping No-1 107 l Control of Shift Activities Program Ownership of Plant Operating Spaces Hydraulic Vibration or Protective Coating Water Hammer Loading in'.ervice inspection Baseline Walkdowns

  • Age Related Degradation Inspection Program *

)

I System Walkdowns PEG 7 Operations inspections NO 1200 l l

Housekeeping No-1 107 Thermal Expansion of Protective Coating l Piping and Components j Loading inservice inspection Baseline Walkdowns

  • Age Related Degradation inspection Program
  • l System Walkdowns PEG 7 l
Operations inspections NO-1200 Housekeeping No-1 107 Elastomer Hardening Baseline Walkdowns
  • Control of Shift Activities Program Ownership of Plant Operating Spaces System Walkdowns PEG 7 Plant Modification
  • RotatirgReciprocating inservice inspect.on Machinery Loading System Walkdowns PEG 7

+

Operations inspections - NO 1-200 Housekeeping No 1 107 Stress Corrosion Cracking inservice inspection of High Strength Bolts Cabling Treeing Age Related Degradation inspection Program

  • Thermal Aging Age Related Degradation inspection Program
  • Electrical Preventive Maintenance Thermal / Radiation Aging Age Related Degradation Inspection Program
  • IR Reduction Instrument Calibration MN 1-211 Pipe Segments Dynamic Loading System Dependent 3 Providing etructural Support l

t AGING EFFECTS Attachment 1b Aging Effects Systems. Structures. Aging Management Commodity Groups Programs Crevice Corrosion Auxily.y Feedwater 1. Secondary Chemistry Specification and Survelitance Program CP 217

2. Demin. Water Chemistry Specification and Surveillance Program. CP 202 Salt Water 3. Age Related Degradation inspection Program *
4. Visual inspections - PEG 7 Safety Inlection 5. Buned Piping inspections
  • 6 Preventive Maintenance Component Cochng 7. Preventive Maintenance Program - Admin Proceduro MN 1 102
8. Spec. and Surv. for Component Coohng/ Service Water Sys (CP-206)

C.R. and DG Bldg 9. Chemistry Program HVAC 10. Specification and Surveillance Pnmary Systems (CP 204)

11. S stem and Structure Walkdown (MN-1319)

Fire Protection 12. S P M7W1(2) intake Structure Erosion / Corrosion Auxihary Feedwater 1. Age Related Degradation inspection Program *

2. Secondary Chemistry Specification and Surveillance Prograrr, Reactor Coolant 3. ISI of ASME Section XI Components (MN 3-110)
4.Section XI, Table IWB 3521 1 Salt Water 5. Spec. and Sury. for Component Cookng/ Service Water Sys (CP 206)

Component Cooling Galvanic Corrosion Auxiliary Feedwater 1. Burieo P! ping laspections *

2. Bonc Acid Corrosion inspection Program
3. Visualinspections Reactor Coolant 4.Section XI IWA 2212
5. S/G Pnmary Manway Cover Removal and Installation, SG-20
6. S/G Eddy Current Testing STP-M 574-1/2 Salt Water 7. Preventive Maintenance Program Admin Procedure MN 1-102 General Corrosion Auxikary Feedwater 1. Secoiidary Chemistry Specification and Surveillance Program
2. Demin. Water Chemistry Specification and Surveillance Program Reactor Coolant 3. Age Related Degradation Inspection Program *
4. VisualInspections 120 Volt Vital Bus 5. Buried Piping inspections *
6. Boric Acid Corrosion Inspection Program Salt Water 7.Section XI,IWA 2212
8. S/G Primary Manway Cover Removal and installation, SG 20 Safety injection 9. S/G Eddy Current Testing STP M-5741/2

., 10. Prevent:ve Maintenance Program Admin Procedure MN-1 102

11. Age Related Degradation Inspection Program
13. Chemistry Program "1 DG Bldg 14. Specification and Surveillance Primary Systems (GP 204)
15. Demin. Water Chemistry Specification and Surseillance Program (CP 202)
16. STP M 571L-1(2)

. O volt DC 17. System and Structure Walkdown (MN-1-319)

18. STP-M 665-1/2 Fire Protectinn Prmary Containment

'.ntake Structure Component Supports MIC Salt Water '. Buned Piping Inspections *

2. Age Related Degradation inspection Program
  • Safety injection 3. Preventive Maintenance Program (Admin Procedure MN-1 102) 4, Spec. and Surv. for Component Coohng/ Service Water Sys (CP-206)

Auxiliary Feedwater 5. Systen and Structure Walkdown (MN-1319) l C R. and DG Bldg l

HVAC

, intake Structure l

1 Pitting Auxiliary Feedwater 1. Secondary Chemistry Specification and Surveillance Program

2. Demin. Water Chemistry Specification and Surveillance Program Reactor Coolant 3. Age Related Degradation Inspection Program *
4. VisualInspections Salt Water 5. Preventive Maintenance
6. S/G Eddy Current Testing STP-M-574-1/2
7. Age Related Degradation Inspection Program
  • Safety injection
8. Preventive Maintenance Program Admin Procedure MN-1-102 Component Cooling 9. Spec and Surv. for Component Cooling /Sennce Water Sys (CP-206)
10. Chemistry Program
11. Specification and Surveillance Pnmary Systems (CP 204)

C A and DG Bld9 12.Demin. Water Chemistry Specification and Surveillance Program (CP-202)

HVAC

13. STP M 571L 1/2
14. System and Structure Walkdown (MN-1319)

Fire Pdechon Intake Structure Elastomer Degradation Auxiliary Feedwater 1. Age Related Degradation inspection Program *

2. Caulking / Sealant inspection *
3. Preventive Maintenance Program (Admin Procedure MN-1 102)

Salt Water 4. Spec. and Surv. for Component CoolintService Water Sys (CP-206)

5. System and Structure Walkdown (MN 1-319) l C R. and DG Bldg 6. Preventivo Maintenance HVAC '

- l Wear Auxiliary Feedwater 1. Age Related Degradation Inspection Program

  • l
2. Inservice inspection l Reactor Coolant 3. Bone Acid Corrosion in;pection Program
4. Pnmary Manway Cover Removal and installation (RCS 10)
5. S/G Manway Cover Re aoval and Installation (SG-1/2) 120 VAC V!tal Bus 6. S/G Secondary Handhc'.e Cover Renoval and installation (SG 1/2)
7. S/G Eddy Current Testing STP M S?41/2
8. RCS Leakage Evaluation (STP-O-271/2) 125 VDC 9 S/G Pnmary Manway Cover Removal and installation (SG-20)
10. Preventive Maintenance Program ( Admin Procedure MN-1 102)

Component Cooling 11. STP M 571E-1

12. STP M 571E 2
13. LLRT R nd DG Bldg 14. System and Structure Walkdown (MN-1-319)

Denting Reactor Coolant 1. Eddy Current Test;ng Erosion intake Structure 1. Bonc Acid Corrosion inspection Program l

Fatigue Reactor Coolant 1. Fatigue Monitoring Program

2. Preventive Maintenance Program (Admin Procedure MN 1 102) 120 VAC Vital Bus 3. Age Relateo Degradation Inspection Program
  • Safety injection 120 VDC Intergranuir ' tac.k Reactor Coolant 1. Specification and Surveillance Primary Systems (CP 204)
2. Spec. and Surv. for Component Cooling / Service Water Sys (CP-206)

Stress Corrosion Reactor Coolant 1. Specification and Surveillance Pnmary Systems (CP-204) j Cracking 2. Alloy 600 Program Plan j

3. Rx Vessel Flange Protection Ring Removal and Closure Head install.(RV- '

78)

4. Bonc Acid Corrosion Inspection Program  ;
5. S/G Eddy Current Testing STP-M-5741/2 Safety Wecbon 6. ISI of ASME Section XI Components (MN-3-110)
7. Torquing and Fastener Applications (FASTEWER 01)
8. System and Structure Walkdown (MN-1319)
9. Age Related Degradation Inspection Program
2. Alloy 600 Program Plan
3. Rx Vessel Flange Protection Ring Rernoval and Closure Herad Install.(RV-78) 4 Bonc Acid Corrosion Inspection Program
5. S/G Eddy Current Testing STP-M-5741/2 R ISI of ASME Section XI Components (MN-3-110)
7. Torquing and Fastener Applications (FASTENER-01) l l .

1 i .

l Pnmary Water SCC Reactor Coolant 1. Chemistry Procedure

2. Alloy 600 Program Plan
3. Rx Vessel Flange Protection Ring Removal and Closure Head install.(RV-78)
4. Boric Acid Corrosion inspection Program
5. S/G Eddy Current Testing STP-M-5741/2
6. ISI of ASME Section XIi.omponents (MN 3110) (
7. Torquing and Fas'a v ;$lications (FASTENER-01) i l

Thermal Embntile Reactor Coolant 1. CASS Evaluation Program

  • Cable Treeing 120 VAC Vital Bus 1. Age Related Degradation Inspection Program
  • j 125 VDC Cables I Cable Thermal Aging 120 VAC Vital Bus 1. Age Related Degradation inspection Program *
2. Electrical Preventive Maintenance (EPM) 125 VDC Cables Cable Thermal and 120 VAC Vital Bus 1. Age Rolated Degradation Inspection Program
  • Radiation Aging 2. Instrument Calibration Program (MN 1-211) 125 VDC Cables Cable IR Reduction 120 VAC Vital Bus 1. Instrument Calibration Program (MN-1211) 125 VDC Cables EC' Dynamic Load 120 VAC Vital Bus 1. Electncal Preventive Maintenance (EPM)
2. Age Related Degradation inspection Program
  • 125 VDC EC Electncal 120 VAC Vital Bus 1. Preventive Maintenance Program - Admin Procedure MN-1-102 Stressors 2. , p. Related Degradation Inspection Program
  • 125 VDC Particulate Wear Salt Water 1. Preventive Maintenance Program (Admin Proceduis MN-1 102; Erosion 2. Age Related Degradation inspection Program
  • Weathering Safety injection 1. System and Structure Waladown (MN-1319)
2. STP-M-663-1/2 Primary Containment 3. STP-F-592-1/2 Auxiliary Bldg and SR D/G Bldg Structures intake Structures Rubber Degradaten Component Cooling 1. STP M 571F 1
2. STP M-571E 2
3. LLRT Selective Leaching Component Cooling 1. Spec. and Surv. for Component Cooling / Service Water Sys (CP-206)
2. Age Related Degradation inspection Program
  • Dynamic Loading Control Room and 1. System and Structure Walkdown (MN 1319)

D/G Building HVAC 2. System Dependent

  • Pipe Segments Providing Structural Support General Aging Fire Protection 1. System and Structure Walkdown (MN 1319) l 2. Conduct of Operation (Admin. Procedure NO 1 100)
3. Age Related Degradation Inspection Program *
4. FP Surveillance Program j

i Corrosion of Steel Pnmary Containment 1. Protective Coating i

?. Protective Coating (Admin. Procedure MN-3-100) l

3. System and Structure Walkdown (MN 1-319)

Auxiliary Building and 4. STP-M-661-1/2 SR D/G Building 5. System and Structure Waikdown (MN-1319)

Structures Corrosion of Tendons Pnmary Containment 1. STP-M-6631/2 Loss of Prestress Pnmary Containment 1. STP-M 665-1/2 Ct rrosion of Refueling Primary Containment 1. System and Structure Walkdown (MN-1-319)

Pool and PCSR Liner l

Corrosion of SPF Liner Auxiliary Building and 1. Operating Manual NO-1201 l SR D/G Building 2. Operating Manual NO 1203 i Structures 3. Performance Evaluation Program (PE 0-67 2-O-M)

Degradation of Auxiliary Building and 1. Admin. Procedure EN 4-101 Carborundum SR D/G Building 2. Engineering Test Procedure-ETP 86-03R (Admin. Proredure EN 4101)

Structures Degradation of Auxiliary Build:ng and 1. Admin. Procedure EN-4-101 Boraflex Material SR D/G Building 2. Engineering Test Procedure-ETP 86-03R (Admin. Procedure EN-4-101)

Structures Aggressive Chemical intake structure 1. Preventive Maintenance Program - Admin Procedure MN-1 102 i Attack of Concrete j Corrosion of Intake structure 1. Preventive Maintenance Program Admin Procedure MN 1-102 Embedded 2. System and Structure Walkdown (MN-1319)  !

Steel /Rebar General Corrosion of Component Supports 1. Protective Coating Support Stees 2. Inservice Inspection

3. Baseline Walkdowns *
4. Age Related Degradation inspection Program
  • l S. System Walkdowns PEG - 7
6. Operations inspections - NO-1200
7. Housekeeping No-1 107
8. Control of Shift Activities Program
9. Ownership of Plant Operating Spaces Hydraulic Vibration or Component Supports Protective Coating Water Hammer Inservice inspection Loading Baseline Walkdowns
  • Age Related Degradation Inspection Program
  • System Walkdowns PEG - 7 Operations inspections - NO 1200 Housekeeping No-1 107 Thermal Exparuion of Component Supports Protective Coating Piping and inservice inspection Components Loading Baseline Walvdowns
  • Age Related Degradation inspection Program
  • System Walkdowns PEG - 7 Operations inspections NO-1-200 Housekeeping No 1 107 Elastomer Hardening Component Supports Basehne Walkdowns
  • Control of Shift Activities Program Ownership of Plant Operating Spaces System Walkdowns PEG - 7 Plant Modification
  • Rotating / Reciprocating Component Supports inservice inspection Mamnery Loading System Waikdowns PEG - 7 Operations inspections - NO-1200 Housekeeping No 1-107 Stress Corrosion Component Supports inservice inspection Cracking of High Strength Bolts

?

New Program .

. 1. Electrical systems are not assessed in the LRA as systems. BGE broke down the systems j . into commodity groups and presents the information under cables and electrical i commodities. This is an acceptable approach, but in the course of the inspection team's l activities, the inspectors need to be sensitive to this approach and the potential for groups of components being excluded from an aging management review that meet the requirements under 10 CFR 54.21(a)(1). j

2. EC - electrical commodities as described under 6.2.

3

3. The aging management programs 'm the Piping Segment Providing Structural Support

', . commodity group will be consisteel wir: the aging management of similar piping for the applicable system. ,

k i

i j

4

)

U

}

i I

l I

. .. - -- - ~. -. --

Definitions Attachment 2 4

1. Adequately Managed - The effects of aging are adequately managed for a group of SCs if their intended passive functions will be maintained consistent with the CLB during the period of extended operations.
2. Age-Related Degradation - A change in SSC performance or physical or chemical 4

properties resulting in whole or part from one or more aging mechanisms. Examples of this type of change include changes in dimension, ductility, fatigue resistance, fracture toughness, mechanical strength, polymerization, viscosity, and dielectric strength.

3, Aging Mechanisms - The physical or chemical processes that result in degradation.

These mechanisms include, but are not limited to, fatigue, erosion, corrosion, erosion / corrosion, wear, thermal embrittlement, radiation embrittlement, microbiologically-induced effects, creep, and shrinkage.

4. Critical Safety Function (CSF) - A condition or action that prevents core damage or minimizes radiation release to the public. A CSF may be fulfilled through automatic or manual actuation of a system or systems, from passive system performance, from inherent plant design, or from operator action while following recovery guidelines set down in procedures.

The seven CSFs include:

Reactivity Control Reactor Coolant System (RCS) Pressure and Inventory Control RCS Heat Removal Containment Isolation Containment Environment Control Radiation Control Vital Auxiliaries (VA)

5. Current Licensing Basis (CLB)- The set of NRC requirements applicable to a specific plant and a lice,asee's written commitments for assuring compliance with and operation within applicable NRC requirements, and the plant-specific design basis (including all modifications and additions to such commitments over the life of the license) that are docketed and in effect. The CLB includes the NRC regulations contained in 10 CFR Parts 2,19,20,50,51,70,73,100, and appendices thereto; orders; license conditions; exemptions; and technical specifications. It also includes the plant-specific design basis information defined in 10 CFR 50.2, as documented in the most recent Final Safety Analysis Report (FSAR) as required by 10 CFR 50.71, and the licensee's commitments remaining in effect that were made in docketed licensing correspondence, such as licensee responses to NRC bulletins, generic letters, and enforcement actions, as well as licensee

~ commitments documented in NRC safety evaluations or licensee event reports. [@54.3]

6. Commodity Group - Groups of like structures and components (SCs) with similar designs, materials of construction, and operating environments with identical aging effccts that can use the same aging management practices.
7. Device Type (DT)- A more specific categorization of components according to their function and design. Equipment types (ETs) are broken into a number of DTs. For example, the ET for valves include DTs hand valve, check valve, control valve, and others.

Device types are the starting point for the grouping process in the AMR task. Components A2-1

^

(

1 are grouped by DT as they enter this task. Device types may be divided to form more specific groups if needed, or the DT may define the component group for evaluation.

Whenever the LR Rule calls for justifications for SCs, the discussions provided by BGE IPA process are at the device-type level.

8. Equipment Type (ET)- A general categorization of components according to their function and design. Examples of specific ETs are valve, piping, instrument, etc. For those SCs subject to the list of age-related degradation mechanisms (ARDMS) which needs to be addressed is developed for each ET. Structural components are categorized into generic groupings of concrete / architectural and steel components.
9. Evaluation Boundaries - the structures and components determined by the applicant as necessary for fulfilling the system / structural-levelintended function relating to the scoping criteria under 10 CFR 54.4.
10. Extended Operations, Period of - The additional amount of time beyond the expiration of the current operating license that is requested in the renewal application.
11. Function Catalog - A Function Catalog for a particular intended function of a system consists of the list of all system components required to support that intended function that are within the boundary of the given system.
12. Functional Requirements - The general, high level functions which an SS may be called on to perform. The functional requirements are used during the system scoping process to establish conceptual boundaries so that wht n a detailed function is determined to be an intended function, the evaluator will know which SS to associate the function with. The term " functional requirements" is used to distinguish these high level functions from the detailed intended functions contained in the screening tools and used during the component level scoping process.
13. Integrated Plant Assessment (RLPA)- A licensee assessment inat demonstrates that a nuclear power plant facility's systems, structures, and components requiring AMR in accordance with 54.21(a) for LR have been identified and that the effects of aging on the functionality of such SCs will be managed to maintain the CLB, such that there is an acceptable level of safety during the period of extended operations. {Q54.31
14. Intended Function - Those functions that are the bases for including SSCs within the scope of LR. (@54.4b]
15. Licensed Life - The maximum period of operations, in calendar years, as defined by statute. For CCNPP, this period is 40 years.
10. Life Cycle Management Evaluation Database (LCMEVAL)- A computer-based application which is used to facilitate the component level scoping process for systems.

The LCMEVAL was created, tested and documented, in accordance with the BGE Quality Assurance Program for Software Development, to justify its use in the safety-related (SR) scoping tasks. Master Equipment List data,0-List daia, drawing references, and other information usefulin the scoping process are extracted one system at a timo from controlled plant databases, loaded into LCNMVAL, and made available to the evaluator.

The LCMEVAL helps to streamline the scoping process by automating key steps and facilitating storage and printing of the results.

A2-2 i

i. . .
17. Long-Lived - Components are considered to be long-lived if they are not subject to periodic replacement based on qualified life or specified time period.. [ 54.21 (a)(1)]
18. Maintenance Strategy - A philosophy regarding the level and type of maintenance that a component will receive throughout its life cycle. An adequate maintenance strategy is defined by the following program attributes: 4
a. Discovery-Identification of performance or condition degradation;
b. Assessment / analysis - Comparison with criteria or other guidance to determine the degree of the degradation:
c. Corrective action - Mitigation of the degradation; and
d. Confirmation / Documentation - Verification and documentation that the intended function was restored from its degraded condition as a result of the corrective action.
19. Master Equipment List (MEL)- A compilation of the NUCLEIS Equipment -Technical Database (NETD) technical data on equipment for a given system.
20. Nuclear Power Plant - A commercial nuclear power facility of a type described in 10 CFR  !

50.21(b) or 50.22. [@54.3)

21. NUCLEIS Database - A mainframe computer-based information system used to initiate, plan, schedule, track and provide a history of maintenance for all plant components. NETD )

is an acronym used to denote the NUCLEIS Equipment Technical Database, which is that )

part of the NUCLEIS information system, indexed by component, which contains information specific to each component. l

22. Passive - A function is said to be passive if it is performed without mcving parts or a l change in configuration or properties in order to perform the function during normal operating conditions or in response to an accident. [@54.21(a)(1)].
23. Plant Event Evaluations - Pre-existing evaluations which show compliance with regulations concerning fire protection, (FP), environmental qualification (EO), PTS, anticipated transients without scram (ATWS) and station blackout (SBO). These evaluations provide the bases for in-scope determinations under @54.4 Criterion 3.
24. Plausible Age-Related Degradation Mechanisms (ARDM)-(See Aging Mechanisms) An ARDM is considered plausible for a specific component if, when allowed to continue without any prevention or mitigation measures or enhanced monitoring techniques, it could not be shown that the component would maintain its capability to perform its intended, passive function throughout the period of extended operation.
25. Program / Activity (PA)- A group of procedures, formal or informal, that provide reasonable assurance that SSCs are capable of fulfilling their intended functions. This may range from a formalized, long-established group of prccedures to a one-time only procedure.
26. Renewal Term -The period of time that is the sum of the additional amount of time beyond the expiration of the operating license (not to exceed 20 years) that is requested in the l l

A2-3

l.

l ,

l renewal application plus the remaining number of years on the operating license currently in effect. [Q 54.31 (b)]

27. Screening Tool- A summary of source document (s) compiled through the research of an event / topic which contains lists of responding SSCs and their intended functions.
28. Structure - The term structure, when used as a stand-alone term in this methodology, refers to a building. When a component of a structure is referred to, the term " structural component" is used for clarity.
29. Structures and Components (SCs)- The phrase " structures and components" appl:es to matters involving the IPA required by 654.21(a) because the AMR required within the IPA should be a component level review rather than a more general system level review. [ SOC i.e.,80 FR 22462] In this Methodology, the term " structural components and components" (SCs) refers to the component level concept.
30. Structural component-/ Component-level intended function - the intended function (s) of the components within the evaluation boundaries directly derived from the system-

/ structural-level intended functions that requires each component to be included within the applicable evaluation boundary.

31. Systems, Structures and Components (SSCS)- Throughout these discussions, the term systems, structures and components" is used when referring to matters involving the discussions of the overall renewal review, the specific LR scope, TLAA and the LR finding.

[ SOC i.e.,80 FR 22462]

32. System-/ Structural-level intended function - the function (s) related to the scoping criteria under 10 CFR 54.4 that must be used to identify the systems and structures within the scope of the rule.
33. Structure or Component Subject to Aging Management Review (AMR)- Structures and components subject to an AMR shall encompass those SCs:

(1) That perform an intended function, as described in 54.4, without moving parts or a change in configuration or properties; and (2) That are not subject to replacement based on a qualified life or specified time period.

i

[s54.21(a)(1)]

l

34. Systems, Structures, and Components within the Scope of LR - are:  !

l (1) Safety-related SSCS, which are those relied on to remain functional during and following design basis events (DBES) [as described in 10 CFR 50.49(b)(1)] to ensure j the following functions:

)

(i) The integrity of the reactor coolant pressure boundary (PB);

(ii) The capability to shut down the reactor and maintain it in a safe shutdown

]

( condition; i - or-I A2 4 1 l

.. .- - .~. - . - - _ . . . . . . _ - . - . _ . - . . - . - . . = . - . . - - .

s; .

O (iii) The capability to prevent or mitigate the consequences of accidents that could result in potential offsite exposure comparable to the 10 CFR Part 100 guidelines.

(2) All non-safety-related (NSR) SSCs whose failure could prevent satisfactory accomplishment of any of the functions identified in paragraphs (1) (I), (ii), or (iii) of th;s definition.

(3) All SSCs relied on in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for FP(10CFR50.48)9 EO (10 CFR S0.49). PTS (IOCFR 50.61), ATWS (10 CFR 50.62), and SBO (10 CFR 50.63). [ 54.4a)

35. Time Limited Aging Analysis (TLAA)- those licensee calculations and analyses that:

(1) Involve SSCs within the scope of LR as delineated in 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 ability of the SSCs to perform its intended functions, as delineated in @54.4(b); and (6) Are contained or incorporated by reference in the CLB.

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[..

List of Acronyms Attachment 3 l

l AFW Auxiliary Feedwater l AMR. Aging Management Review l ARDM Age-Related Degradation Mechanism ATWS Anticipated Transient Without Scram BGE Baltimore Gas and Electric Company CCNPP Calvert Cliffs Nuclear Power Plant CCW Component Cooling Water CEA Control Element Assembly L CLB Current Licensing Basis

! CSF Critical Safety Function DBE Design Basis Event DT Device Type i

EP Electrical Panet EQ Environmental Qualification ET Equipment Type FP Fire Protection FSAR Final Safety Analysis Report

! IL Instrument Line IPA . Integrated Plant Assessment IPE Individual Plant Examination IPEEE Individual Plant Examination External Events IR issue Report LCM .

Life Cycle Management LCMEVAL Life Cycle Management Evaluation Database LR License Renewal LRA. License Renewal Application MEL Master Equipment List .

NETD NUCLEIS Equipment Technical Database NSR Non-Safety-Related PAM Post Accident Monitoring PB Pressure Bounday ,

PTS Pressurized Thermal Shock l PWSCC Primary Water Stress Coirosion Cracking RCS Reactor Coolant System SBO Station Blackout SCs Structures and Components SG Steam Generator SOC Statements of Consideration i SR Safety-Related

SSs. System and Structure i SSCs Systems, Structures and Components i TLAA Time-Limited Aging Analysis UFSAR Updated Final Safety Analysis Report VA Vital Auxiliary i

i A3-1 l

{

t, -. , , , _ _ _ , -. ,. . . _ . . . , . . , _ , . .,.c

-g ,

REFERENCE MATERIAL Attachment 4

. The License Renewal Rule promulgated in Title 10, Part 54, of the Code of Federal i Regulations revised May 8,1995.

The statement of consideration that accompanied the License Renewal Rule as published in the Federal Register, May 8,1995. l

. Draft Regulatory Guide DG-1047, entitled " Standard Format and Content for Applications to Renew Nuclear Power Plant Operating Licenses," issued August 1996.

1 The " Industry Guidelines for implementing the Requirements of 10 CFR Part 54 - The i License Renewal Rulo," issued March 1996.

The inspection Manual Chapter 2516

. Inspection Procedures 71002

+ CCNPP License Renewal Application i 1

The staff's Sa.: ?? Mvalus%1 relating to the CCNPP LRA.

l 9-l l

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