ML082880160
| ML082880160 | |
| Person / Time | |
|---|---|
| Site: | North Anna  |
| Issue date: | 10/07/2008 |
| From: | Price J Dominion, Virginia Electric & Power Co (VEPCO) |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| 08-0595 | |
| Download: ML082880160 (139) | |
Text
10 CFR 50.55a VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 October 7, 2008 U.S. Nuclear Regulatory Commission Serial No. 08-0595 Attention: Document Control Desk NL&OS/ETS RO Washington, D.C. 20555 Docket No. 50-338 License No. NPF-4 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 FOURTH INTERVAL INSERVICE INSPECTION PLAN AND ASSOCIATED PROPOSED ALTERNATIVES AND RELIEF REQUESTS Pursuant to 10 CFR 50.55a(g)(4), Dominion submits the North Anna Power Station, Unit 1, inservice inspection (ISI) program for the fourth Inservice Inspection (ISI) interval applicable to Class 1, 2, and 3, components and component supports. The ISI Plan, included as Attachment 1 to this letter, describes the programmatic aspects of ISI examinations of components and component supports. The attached ISI Plan does not address the piping examination requirements that will result from the implementation of risk-informed technology. Dominion is presently developing a risk-informed program for the examination of piping that will be applicable to Class 1 piping, as a minimum.
Upon the completion of the risk-informed program, and required supporting documents, a supplemental submittal to the fourth interval ISI Plan will be provided. This submittal will address the risk-informed scope and modifications to the examination requirements of affected piping components. The delayed submittal of the risk-informed portion of the ASME Section Xl program was discussed with the NRC staff on May 8, 2008 and agreed upon in a May 13, 2008 phone call with Mr. Siva Lingam.
The ISI program has been developed in accordance with the requirements of the 2004 Edition, with no addenda, of Section Xl of the ASME Boiler and Pressure Vessel Code.
North Anna Unit 1 will also comply with the limitations and modifications to these requirements stated in 10 CFR 50.55a(b) related to the implementation of the 2004 ASME Code. The fourth ISI interval will begin on May 1, 2009, and North Anna Unit 1 will begin implementation of the fourth interval ISI Plan on that date.
North Anna Unit 1 was not designed or licensed to standards that completely meet the detailed ISI examination and system pressure test requirements presently specified in the 2004 ASME Code. Therefore, pursuant to 10 CFR 50.55a (a)(3)(i) and/or (ii) and 10 CFR 50.55a(g)(5)(iv), Dominion is also requesting the use of alternative examination or testing requirements in place of and/or requesting relief from certain examination or testing requirements of the 2004 ASME Code. The proposed alternatives or relief requests from specific 2004 Code requirements are provided in Section 2 of the attached ISI Plan. Where applicable, previously approved alternative or relief requests are identified along with the appropriate reference. The North Anna Unit 1 fourth
Serial No.08-595 Docket No. 50-338 Fourth Interval ISI Plan Page 2 of 3 interval ISI Plan and associated requests for the use of alternatives or relief from specific 2004 ASME Code requirements have been reviewed and approved by the station's Facility Safety Review Committee.
Dominion requests review and approval of the attached relief requests by April 30, 2009 in order to implement the Plan at the start of the fourth ISI interval.
If you have any questions or require additional information, please contact Mr. Thomas Shaub at (804) 273-2763.
Respectfully, J. A n Price Vic4P esident - Nuclear Engineering Commitments made in this letter:
- 1. Submit a supplement to the fourth interval ISI Plan addressing the risk-informed scope and modifications to the examination requirements of affected piping components.
Attachment
- 1. Inservice Inspection Plan for the Fourth Inspection Interval
Serial No.08-595 Docket No. 50-338 Fourth Interval ISI Plan Page 3 of 3 cc: U.S. Nuclear Regulatory Commission Region II Sam Nunn Atlanta Federal Center 61 Forsyth Street, SW Suite 23T85 Atlanta, Georgia 30303 Mr. J. E. Reasor, Jr.
Old Dominion Electric Cooperative Innsbrook Corporate Center 4201 Dominion Blvd.
Suite 300 Glen Allen, Virginia 23060 NRC Senior Resident Inspector North Anna Power Station Ms. D. N. Wright NRC Project Manager U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 0-8 H4A 11555 Rockville Pike Rockville, Maryland 20852 Mr. J. F. Stang, Jr.
NRC Project Manager U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 0-8 G9A 11555 Rockville Pike Rockville, Maryland 20852
Serial No. 08-0595 Docket No. 50-338 Fourth Interval ISI Plan Attachment INSERVICE INSPECTION PLAN FOR THE FOURTH INSPECTION INTERVAL North Anna Power Station Unit 1 Virginia Electric and Power Company (Dominion)
VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN FOR THE FOURTH INSPECTION INTERVAL INSERVICE INSPECTION PROGRAM FOR COMPONENTS AND COMPONENT SUPPORTS Interval 4 May 1, 2009 - April 30, 2019 Approval Signatures on File in Records Management Revision 0 June, 2008
CONTENTS Abstract ISI Classification Boundary Drawings Interval 4 ISI Correspondence Section 1 - Inservice Inspection Plan - General Section 2 - Inservice Inspection Plan for Components 2.3 Relief Requests for Components 2.4 Relief Requests for System Pressure Tests Section 3 - Inservice Inspection Plan for Component Supports Section 4 - Miscellaneous Documentation Section 5 - Partial Coverage Relief Requests Section 6 - Code Cases Utilized in the Fourth Inservice Inspection Interval Section 7 - (Reserved For Later Use)
Section 8 - Plan Changes Section 9 - Classification and Identification of Components NAPS U1 14-ISI Plan i Revision 0
ABSTRACT VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN FOURTH INSPECTION INTERVAL MAY 1, 2009 THROUGH APRIL 30, 2019 As required by the Code of Federal Regulations, Title 10, Part 50, Section 50.55a (10 CFR 50.55a), the NAPS 1 Inservice Inspection (ISI) Program should have been updated to the 2001 Edition of ASME Section XI with addenda through the 2003 Addenda.. This was the latest edition and addenda of Section XI incorporated into 10 CFR 50.55a as of April 30, 2008. However, as allowed by 10 CFR 50.55a(g)(4)(iv), the fourth inservice inspection plan was prepared to the requirements of the 2004 Edition of ASME Section XI. This updated program is for the NAPS 1 fourth ten year inspection interval scheduled to commence May 1, 2009 and be completed April 30, 2019. These dates reflect extension of the first interval by 201 days documented in our letter to the NRC dated 8/25/88, Serial No.88-486, and extension of the second interval by 127 days approved per NRC Letter No.98-167, dated 3/6/98. In cases where the requirements of Section XI have been determined to be impractical, requests for relief have been developed per 10 CFR 50.55a(g)(5). Alternatives, as allowed by 10 CFR 50.55a(a)(3), to specific requirements of ASME Section XI or 10 CFR 50.55a, that provide an acceptable level of quality and safety and provide a methodology more conducive to the performance of an examinations have been proposed. Similarly, alternatives have been proposed when compliance with specified requirements would result in hardship or unusual difficulty without a compensation increase in the level of quality and safety.
This document provides an overview and summary of the NAPS-1 ISI Program for Subsections IWA, IWB, IWC, IWD, and, JWF. The boundaries of the ISI Program, component classifications, and the employment of exemptions in 1WB-1220, 1WC-1220, LWD-1220, and TWF-1230 are shown on the ISI Classification Boundary Drawings (CBMs). The graphic codes, symbols and text used on the CBMs are detailed on 11715-CBM-L&S-4, Legends and Symbols Drawing.
The Inservice Inspection Schedule for Components and Component Supports and the Inservice Inspection Plan for System Pressure Tests are provided in separate volumes to the ISI Program. System Pressure Tests are performed in accordance with the System Pressure Test Implementing Schedule.
The IWE (Inservice Inspection of Class MC and CC Components) and IWL (Inservice Testing of Class CC Concrete Components) Program, and the IWP (Inservice Testing of Pumps) and IWV (Inservice Testing of Valves), Program are separate programs and are not included as part of the ISI Program. Steam generator inspections will continue to be performed under Plant Technical Specifications NAPS U I14-ISI Plan ii Revision 0
North Anna Power Station Unit 1, Interval 4 ISI Classification Boundary Drawings Unit 1 CBM Drawing 11715-CBM-L&S-4 Legend and Symbols Unit 1 CBB Drawings 11715-CBB-006A-4 Air Cooling and Purging System 11715-CBB-040C-4 Air Conditioned Chilled Water System 11715-CBB-040D-4 Air Conditioning Condenser Water System 11715-CBB-102B-4 Interior Fire Protection & Hose Rack System Unit 1 CBM Drawings 11715-CBM-070A-4 Main Steam System 11715-CBM-070B-4 Main Steam System 11715-CBM-072A-4 Auxiliary Steam and Air Removal System 11715-CBM-074A-4 Feedwater System 11715-CBM-078A-4 Service Water System 11715-CBM-078B-4 Service Water System 11715-CBM-078C-4 Service Water System 11715-CBM-078G-4 Service Water System 11715-CBM-078H-4 Service Water System 11715-CBM-078J-4 Service Water System 11715-CBM-078K-4 Service Water System 11715-CBM-078L-4 Service Water Chemical Addition System 11715-CBM-079A-4 Component Cooling Water System 11715-CBM-079B-4 Component Cooling Water System 11715-CBM-079C-4 Component Cooling Water System 11715-CBM-079D-4 Component Cooling Water System 11715-CBM-079E-4 Component Cooling Water System 11715-CBM-082A-4 Compressed Air System 11715-CBM-082F-4 Compressed Air System 11715-CBM-082N-4 Compressed Air System NAPS Ul 14-ISI Plan iii Revision 0
North Anna Power Station Unit 1, Interval 4 ISI Classification Boundary Drawings (Continued)
Unit 1 CBM Drawings (cont'd) 11715-CBM-088A-4 Fuel Pit CLNG & Refueling Pur. System 11715-CBM-089B-4 Sampling System 11715-CBM-089D-4 Sampling System 11715-CBM-090A-4 Vent and Drains System 11715-CBM-090C-4 Vent and Drains System 11715-CBM-091A-4 Cont Quench & Recirc Spray Sub System 11715-CBM-091B-4 Cont Quench & Recirc Spray Sub System 11715-CBM-092A-4 Leakage Monitoring System 11715-CBM-092A-4 Containment Vacuum System 11715-CBM-093A-4 Reactor Coolant System 11715-CBM-093B-4 Reactor Coolant System 11715-CBM-094A-4 Residual Heat Removal System 11715-CBM-095A-4 Chemical and Volume Control System 11715-CBM-095B-4 Chemical and Volume Control System 11715-CBM-095C-4 Chemical and Volume Control System 11715-CBM-096A-4 Safety Injection System 11715-CBM-096B-4 Safety Injection System 11715-CBM-098A-4 Steam Generator Blowdown System 11715-CBM-102A-4 Chemical Feed System 11715-CBM-105B-4 Secondary Plant Gas Supply System 11715-CBM-106A-4 Containment Atmosphere Cleanup System 13075-CBM-093C-4 Reactor Coolant System 13075-CBM- 102C-4 Chemical Feed System NAPS Ul 14-ISI Plan iv Revision 0
North Anna Power Station Unit 1, Interval 4 ISI Classification Boundary Drawings (Continued)
Additionally, several Unit 1 drawings contain Unit 2 Components. These follow:
Unit 1/2 CBM Drawings 11715-CBB-040C-4 Air Conditioned Chilled Water System 11715-CBB-040D-4 Air Conditioning Condenser Water System 11715-CBM-072A-4 Auxiliary Steam and Air Removal System 11715-CBM-078A-4 Service Water System 1 11715-CBM-078C-4 Service Water System 11715-CBM-078G-4 Service Water System 11715-CBM-078H-4 Service Water System 11715-CBM-078J-4 Service Water System 11715-CBM-078K-4 Service Water System 11715-CBM-079A-4 Component Cooling Water System 11715-CBM-088A-4 Fuel Pit CLNG & Refueling Pur. System 11715-CBM-093B-4 Reactor Coolant System 11715-CBM-105B-4 Secondary Plant Gas Supply System 11715-CBM-106A-4 Containment Atmosphere Cleanup System NAPS UI 14-ISI Plan V Revkisin 0
North Anna Power Station Unit 1, Interval 4 ISI Correspondence Outgoing NRC Ltr.
Document Identification Status Ltr. No. No. Comments Component Relief Requests NDE-001 - The original construction code, ANSI Pending B31.7, 1969 Edition, 1970 Addenda, did not establish a weld reference system.
NDE-002 - The automated tooling used to inspect the Pending Reactor Vessel and Reactor Vessel Nozzles uses its own reference system.
NDE-003- Due to the physical configuration of the Pending pressurizer, attached electrical equipment and local dose rates, it is not practical to perform the code required UT examinations of the surge nozzle to vessel weld and the associated nozzle-inside radius area.
NDE-004 - Temporary repairs and augmented Pending inspections will be performed to pressure retaining piping, fittings, and associated welds (excluding socket welds) of the service water system until full repair/replacement can be performed during a scheduled outage.
NDE-005 - Examination of pressurizer nozzle Pending preemptive weld overlays.
NDE-006 - Request to use CC N-706-1 for Pending examination of the residual heat removal heat exchangers.
NAPS U I14-ISI Plan vi Revision 0
North Anna Power Station Unit 1, Interval 4 ISI Correspondence(Continued)
TOutgoing NRC Document Identification Status Ltr. No. Ltr. No. Comments System Pressure Test Relief Requests SPT-001 - It is not practical to perform the VT-2 Pending examinations on reactor vessel partial penetration welds during a hydrostatic test, and the bottom of the reactor vessel during a system leakage test.
SPT-002 - It is not practical to perform the code Pending required VT-2 examination on the identified Class 1 vent and drain, sample, and instrumentation piping and connections.
SPT-003- Proposed alternative requirements for testing Pending piping within the RHR System.
SPT-004- Proposed alternative requirements for testing Pending piping within the SI System.
SPT-005 - Proposed alternative requirements for testing Pending piping within the RCS System.
SPT-006 - Proposed alternative requirements for testing Pending piping within the RHR and SI Systems.
NAPS U I 14-ISI Plan vii Revision 0
North Anna Power Station Unit 1, Interval 4 ISI Correspondence (Continued)
Component Support Relief Requests CS-001 - Surveillance of snubbers will be in accordance Pending with Technical Requirements Manual and preservice testing in accordance with ISTD.
Miscellaneous Documents (Reserved for Later Use.)
Partial Coverage Relief Requests (Reserved for Later Use.)
Risk Informed Application (Reserved for Later Use.)
NAPS U1 14-ISI Plan viii Revision 0
Section 1 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN GENERAL FOURTH INSPECTION INTERVAL NAPS UI 14-ISI Plan 1-1 Revision 0
1.0 INSERVICE INSPECTION PLAN - GENERAL 1.1 General Information North Anna Power Station Unit 1 (NAPS 1) is located on Lake Anna in Louisa County, Virginia. The plant employs a Pressurized Water Reactor (PWR) and associated Nuclear Steam Supply System components provided by Westinghouse Electric Corporation.
1.1.1 Preservice Examinations Preservice examinations at NAPS 1 were performed utilizing the requirements of ASME Section XI, 1974 Edition with Addenda through Summer 1975.
1.1.2 Initial Inservice Inspection Interval NAPS 1 commercial operation commenced on June 6, 1978. Accordingly, the initial ten-year inspection interval started on 6/6/78. This interval, however, was extended 201 days to 12/24/88 as documented by letter to the NRC dated 8/25/88, Serial No.88-486. Examinations during the first inspection interval were also performed per ASME Section XI, 1974 Edition with Addenda through Summer 1975. Certain system pressure testing requirements were completed per ASME Section XI, 1977 Edition with Addenda through Summer 1979.
1.1.3 Second Inservice Inspection Interval The second inservice inspection interval commenced on December 24, 1988 and was completed on April 30, 2000. The end of interval date reflects an extension of 1 year and 127 days as approved by NRC Letter 98-167, dated 3/6/98.
Examinations were performed per ASME Section XI, 1983 Edition through the summer 1983 Addenda.
1.1.4 Third Inservice Inspection Interval The third inservice inspection interval commenced on May 1, 1999 and was completed on April 30, 2009. Examinations and tests were performed to the 1989 Edition of ASME Section XI. The one year overlap with the end of the second inspection interval reestablished the normal 10-year schedule.
1.1.5 Fourth Inservice Inspection Interval As required by the Code of Federal Regulations, Title 10, Part 50, Section 50.55a (10 CFR 50.55a), the NAPS 1 Inservice Inspection (ISI) Program should have been updated to the 2001 Edition of ASME Section XI with addenda through the 2003 Addenda.. This was the latest edition and addenda of Section XI incorporated into 10 CFR 50.55a as of April 30, 2008. However, as allowed by 10 CFR 50.55a(g)(4)(iv), the fourth inservice inspection plan was prepared to the requirements of the 2004 Edition of ASME Section XI. The fourth inservice inspection interval is scheduled to commence on May 1, 2009 and be completed on April 30, 2019.
NAPS U1 I4-ISI Plan 1-2 Revision 0
1.1.6 Inservice Inspection Program Description The ISI Program contained herein addresses the inservice inspection and testing of ISI Class 1, 2, and 3 components and their associated component supports. The applicable requirements in Subsections IWA, JWB, IWC, IWD, IWF and the Mandatory Appendices of the 2004 Edition of ASME Section XI have been incorporated into our corporate and site ISI programs and procedures.
Additionally, the applicable supplemental requirements of 10 CRFR 50.55a(b) have been incorporated into the program.
This document is not intended to provide specific information on the implementation of the ISI Program. The intent of this document is to provide specific information on the scope of the NAPS I ISI program (i.e., its boundary and compliance with Section XI) and identify those Section XI requirements which are deemed impractical or for which alternatives are proposed. Requests for relief from these impractical requirements or for use of alternatives have been developed per 10 CFR 50.55a(g)(5) and 10 CFR 50.55a(a)(3).
1.1.6.1 Risk-Informed ISI (RI-ISI)_Program North Anna Power Station, Unit 1, will develop a RI-ISI program for various piping components within the scope of the ISI program. The exact scope of the RI-ISI program will be determined as part of this activity. Implementation of the program will most likely require additional submittals of requests for relief to the NRC as well as revisions to the ISI Schedule.
1.1.6.2 Exclusion of Subsections IWE and IWL Subsections IWE and IWL, Inservice Inspection of Class MC and CC components and Inservice Testing of Class CC concrete components in Nuclear Power Plants are not included in the ISI Plan. They are committed to a different 10-year interval schedule.
1.1.6.3 Inservice Inspection Schedule The inservice inspection schedule required by IWA-2420, detailing the components and component supports selected for examination during the interval is provided in the IST Schedule.
1.1.6.4 System Pressure Test The system pressure test schedule required by IWA-2420, detailing system pressure tests required during the interval is provided as a separate document (System Pressure Test Implementing Schedule).
1.1.6.5 Inspection Program Employed The ISI Program for North Anna Unit 1 will utilize the interval format of Inspection Program B, as shown in IWA-2432.
1.1.6.6 Classification of Components NAPS U I 14-ISI Plan 1-3 Revision 0
A. Classification of Components-Design North Anna Unit 1 was issued construction permit No. CPPR-77 in February 1971. The station design incorporates the codes and standards that were in effect when the equipment was purchased. The codes and standards used for the design, fabrication, erection, and testing of safety related components are commensurate with the importance of the safety functions to be performed.
The group classifications tabulated in the "Standard Format and Content of Safety Analysis Reports for Nuclear Power Reactors," issued in February 1971, and in Safety Guide No. 26, published in March 1972, incorporated, in most cases, later editions of codes than those in effect when the majority of safety-related equipment was designed. Some of the equipment that would fall under a "group" as defined in Safety Guide No. 26 was designed to. different codes or different editions of the same code. For example, for different components that would be in the same group, one may be designed to ASME HI-1968, one to ASME 111-1971, and one to ASME VIII-1968. Therefore, pressure-containing components of safety-related systems do not necessarily fall under the group classification stated in the safety guide..
B. Classification of Components-Inservice Inspection The classification of components for Inservice Inspection was performed by employing the requirements of 10 CFR 50.55a, and the guidance of USNRC Regulatory Guide 1.26 Revision 3, ANSI N18.2-1973, ANSI N18.2a-1975, and NUREG-0800, Standard Review Plan 3.2.2-Revision 1.
The ISI Classification of each component included in NAPS 1 program is shown on the ISI Classification Boundary Drawings (CBBs and CBMs).
These drawings detail by the use of line graphic codes and component markings the ISI Classification of all items included within the ISI Program boundaries. In general, the ISI classification of piping is accomplished by line "codings" or symbols shown on 11715-CBM-L&S-
- 4. ISI classification of components which graphically cannot be coded, such as pressure vessels, pumps, strainers, and tanks, etc. include text (e.g., ISI Class 1A, 3E, etc.) shown either inside of the component graphics or adjacent to the component mark number.
Classification changes are typically shown at the seat of a valve, with the ISI Class shown on either side of the classification "break line."
1.1.6.7 Components Exempt from Examination The application of the exemptions allowed per IWB-1220, 1WC-1220, IWD-1220, and IWF- 1230 are also detailed by the graphic codes and component markings of 11715-CBM-L&S-4.
NAPS U1 14-ISI Plan 1-4 Revision 0
1.1.6.8 Requests For Relief Where the requirements of ASME Section XI have been determined to be impractical, requests for relief have been developed in accordance with 10 CFR 50.55a(g)(5)(iii). Impractical requirements are detailed as NDE for issues involving nondestructive examinations, CMP issues involving components, SPT for issues involving system pressure testing, CS for issues involving component supports, and a Partial or PRT series for documenting partial coverage exams. Any requests for relief developed to support the RBISI program will be indicated with a R. Additionally, where alternatives to the requirements of Section XI are proposed, they will be developed in accordance with the requirements of 10 CFR 50.55a (a)(3)(i) and/or (ii).
These requests for approval to use alternative requirements will also be presented in the sets of relief requests described above.
1.1.6.9 ASME Section XI Code Cases Incorporated Into Program As allowed by 10 CFR 50.55a(g) and USNRC Regulatory Guide 1.147, Revision 15, Code Cases were incorporated into the NAPS 1 ISI Program.
Any Code Case that is approved by the NRC in a later version of Regulatory Guide 1.147 as referenced by 10 CFR 50.55a(b) may also be used provided the Code Case is implemented with any limitations or modifications as stated in the Regulatory Guide. Applicable Code Cases are listed in Section 6 of this ISI Plan.
1.6.10 Augmented Inservice Inspection Program for ISI Class 1, 2, and 3 Components Augmented Inservice Inspection activities which pertain to components within the scope of the ASME Section XI program and specific components scheduled to be examined per the augmented program will be included as part of the Inservice Inspection Schedule discussed in Section 1.1.6.3.
Examinations performed to satisfy the requirements of the Augmented Inservice Inspection Program are outside of the scope of ASME Section XI.
The Authorized Nuclear Inservice Inspector (ANII) is not involved in the Augmented Inservice Inspection Program. Examinations performed to satisfy requirements of ASME Section XI, the ISI program, are subject to the review of the ANII.
1.6.11 Continuing Commitment from Interval 3 As part of the activities associated with Interval 3, Relief Request CMP-022R1 was approved by the NRC. The approval of CMP-022R1 allowed the overlay of the pressurizer nozzle to safe-end welds as a means of mitigating the potential for stress corrosion cracking of these dissimilar metal welds which contained Alloy 82/182 weld metal. Dissimilar metal welds containing Alloy 82/182 weld material have shown a propensity for primary water stress corrosion cracking (PWSCC) degradation, especially in NAPS U I 14-ISI Plan 1-5 Revision 0
components subject to the higher operating temperatures associated with the pressurizer. Due to the close proximity of the associated safe-end to pipe welds, it was necessary to also include these welds in the overlays.
Commitments contained in CMP-022R1 require that 25% of this group of welds be examined in the fourth interval.
A unique examination methodology, not part of Section XI, must be used to examine these welds. This examination methodology was part of CMP-022R 1 and was approved as part of that relief request. However, since the approval of the alternative examination methodology did not exceed beyond the end of the third interval, Relief Request NDE-005 is included in this program requesting the approval of the same alternative examination methodology for the fourth inspection interval.
NAPS UI 14-ISI Plan 1-6 Revision 0
Section 2 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN COMPONENTS FOURTH INSPECTION INTERVAL NAPS UI 14-ISI Plan 2-1 Revision 0
2.0 INSERVICE INSPECTION PLAN FOR COMPONENTS 2.1 Program Description 2.1.1 The Inservice Inspection Program for Class 1, 2 and 3 components meets the requirements of Section XI of the ASME Boiler and Pressure Vessel Code, 2004 Edition. Where these requirements are determined to be impractical, or where alternatives are identified in accordance with 10 CFR 50.55a(a)(3),
specific requests for relief have been written and included in this section.
2.1.2 Repairs and replacements shall be in accordance with Station Administrative Procedures, which assure compliance with ASME Section XI, Division 1, 2004 Edition.
2.2 Program Summary 2.2.1 The Inservice Inspection Program for North Anna Unit 1 utilizes the tables IWB-2500-1, IWC-2500-1, IWD-2500-1, and IWF-2500-1 of the 2004 Edition of the ASME Section XI Code. Components selected for examination are identified in the Inservice Inspection Schedule.
2.2.2 Categories B-P, C-H, and D-B constitute the scheduled 10-year interval pressure testing requirements. The following guidance will be utilized programmatically concerning pressure testing.
Pressure tests which meet the pressure, temperature, hold time, and VT-2 examination requirements of IWA-5000, IWB-5000, IWC-5000, IWD-5000 will be treated as complete for inspection scheduling purposes.
Pressure tests required for ASME Section XI repairs or replacements will be conducted in accordance with the station's repair replacement program as documented at the station.
NAPS U1 14-ISI Plan 2-2 Revision 0
Section 2.3 RELIEF REQUESTS FOR COMPONENTS NAPS UI 14-ISI Plan 2-3 Revision 0
RELIEF REQUEST NDE-001 I. IDENTIFICATION OF COMPONENTS 1SI Class 1 and 2 piping, vessel, and component welds normally examined from their outside surface. Excluded from this request for relief are all welds normally examined from their inside surface by use of the automated reactor vessel examination tool.
II. CODE REQUIREMENTS Section XI of the ASME Boiler and Pressure Vessel Code, 2004 Edition, IWA-2600, "Weld Reference System."
III. BASIS OF REQUEST FOR RELIEF The original construction and fabrication codes used in the construction of North Anna Power Station predated the requirement that a weld reference system be established.
Establishment of a weld reference system cannot be practically attained within the scope and schedule of existing outages. During the third inservice inspection interval, the implementation of thisSection XI Code requirement was also considered to be impractical and a request for relief was submitted (NDE-004 of the third inservice inspection interval program). The alternative provisions proposed in this request for relief are consistent with those proposed and accepted by the NRC for the third inservice inspection interval.
Consistent with the commitments made in the third inservice inspection interval, this alternative reference system was established within the plant on those welds examined as part of the third inservice inspection interval. Continued use of the alternative reference system is reasonable because it provides an acceptable level of quality and safety. To reject the alternative reference system already in use would require the plant to establish either the system required by the Section XI Code in IWA-2600 or some other alternative system yet to be developed. In either case, significant effort would be expended to achieve compliance with the requirements of IWA-2600 (or as modified) without any justifiable gain in quality or safety. Therefore, continued use of the alternative reference system presented below is requested under the provisions of 10 CFR 50.55a(a)(3)(ii).
IV. ALTERNATE PROVISIONS North Anna Unit 1 will use weld isometrics drawings (the WMKS series) to provide a detailed identification of location of each weld requiring examination as part of the fourth inservice inspection interval. For any weld volumetrically examined as part of the fourth inservice inspection interval that did not require volumetric examination as part of the third inservice inspection interval, the proposed alternative reference system will establish a permanent reference point indicating a zero point and direction of examination. The volumetric examination of welds examined in the third interval will use the points of reference established in the third inservice inspection interval, which are consistent with the stated proposal for the fourth inservice inspection interval.
NAPS U1 14-ISI Plan 2-4 Revision 0
Relief Request NDE-00 1 (continued)
Where surface examination is specified,Section XI requires that 100 percent of the selected weld or area be examined. Unlike the performance of a volumetric examination, there is no need to indicate the direction of examination (or scan) to assure uniformity in reporting results. In these cases, no marks are placed on the weld or area. In some cases, only a portion of a weld may be examined as part of a period examination. This usually involves a large weld that is divided into thirds, with 1/3 being done each period. Therefore, a reference point is marked on the weld to assist with the volumetric examination.
A weld accepted for continued service that contains volumetric indications accepted under the criteria of IWX-3500 or IWX-3600 shall be marked to ensure the relocation of the indication, using appropriate reference marks. All reference marks will be permanently fixed on the weld.
The location of indications is documented on an examination report of the weld or surface that permits accurate identification of areas on the examination surface. The report contains sufficient indicators (e.g., reference points, orientation, and/or proximity to other welds) to positively identify the weld or area in question and the examination starting point. The starting point of the map is determined from the instructions provided for determining the location of the zero reference point associated with a volumetric examination. The examination record will provide information as to the location of the surface indication on the weld examination report.
(Note: A similar relief request was approved for North Anna Unit 1 for the third interval inspection Program by letter dated April 25, 2000, under TAG No. MA5750; for North Anna Unit 2, the third inservice inspection interval, under TAG No. MB2223; and Surry Unit 2,'third inservice inspection interval, under TAG No. M89085.)
NAPS UI 14-ISI Plan 2-5 Revision 0
RELIEF REQUEST NDE-002 I. IDENTIFICATION OF COMPONENTS Pressure retaining welds in the reactor vessel (Examination Category B-A), the reactor vessel nozzle area (Examination Category B-D), and the dissimilar metal welds joining the reactor vessel nozzles to the reactor coolant loop piping (Examination Category B-F) examined by the automated reactor vessel examination tool.
II. CODE REQUIREMENTS Section XI of the ASME Boiler and Pressure Vessel Code, 2004 Edition, IWA-2600, "Weld Reference System III. BASIS OF REQUEST FOR RELIEF The original construction requirements of the North Anna Power Station did not require establishing a reference system for the reactor vessel and associated reactor vessel nozzle-to-piping dissimilar metal welds as now required by IWA-2600. An automated examination tool now accomplishes these examinations. The automated examination tool establishes its reference point using a known reference point on the reactor vessel. This point allows the device to repeat examination locations without the necessity of any other reference systems.
The tool determines its location by the use of an electronic encoder system, which provides for sufficient repeatability. Electronic encoding systems have been in use for the reactor vessel examinations performed for Dominion and the industry for over two decades.
Dominion has not identified any concern regarding the use of the system from its staff, the vendor, the ANII, or the regulator. Additionally, Dominion is unaware of an industry concern with this type of location/reference system. It is Dominion's position that the electronic referencing system used by the automated reactor vessel examination tool provides an acceptable level of quality and safety. This alternative system can locate welds with sufficient repeatability for future examinations. Therefore, it will satisfy the objectives of rWA-2600.
The examinations performed by the automatic tool are conducted from the inside of the reactor vessel. Establishing the reference system required by IWA-2600 on the inside of an operational reactor vessel is a significant hardship that will provide no increase in quality or safety. Therefore, approval of this proposed alternative reference system is requested under the provisions of 10 CFR 50.55a(a)(3)(ii).
IV. ALTERNATE PROVISIONS The automated reactor vessel examination tool will continue to establish its reference system based upon the existing reference points and the electronic encoding system designed into the tool. No other system is planned or deemed necessary.
(Note: A similar relief request was approved for North Anna Unit 1, third inservice inspection interval, under TAG No. MA5750; for North Anna Unit 2, the third inservice inspection interval, under TAC No. MB2280.
NAPS U I14-ISI Plan 2-6 Revision 0
RELIEF REQUEST NDE-003
- 1. IDENTIFICATION OF COMPONENTS Nozzle Inner Radius Section (Pressurizer Surge Nozzle)
Examination Items Component # Drawing # Class Weld 1and
-RC-E-2 11715-WMKS-RC-E-2 1 9NIR II. CODE REQUIREMENTS North Anna Unit 1 is beginning the Fourth inservice Inspection Interval under the 2004 Edition of the ASME Section XI Code. Category B-D of this Code requires a volumetric examination of nozzle-to-vessel weld 9. The 2004 Edition of Section XI does not require that an examination of the nozzle-inside-radius of weld 9 (9NIR).
However, 10 CFR 50.55a(b)(2)(xxi) mandates use of the 1998 Edition of Section XI for the examination requirements of 9NIR. Category B-D, Item B3.120 of the 1998 Edition requires a volumetric examination of the nozzle inside radius section of the pressurizer surge nozzle. 10 CFR 50.55a(b)(2)(xxi) allows an enhanced visual VT-i on the inside surface in lieu of the volumetric requirement, which is performed from the outside surface.
III BASIS OF REQUEST FOR RELIEF The North Anna Unit 1 pressurizer surge line nozzle is welded into the bottom head of the pressurizer. The nozzle is located under the pressurizer skirt and is surrounded by the 78 heater penetrations (Figure 1). Multi-layered, stainless steel mirror insulation and cables for the pressurizer heaters (Figure 2) obstruct access to the nozzle. Access to the area on 9NIR for a visual examination is also obstructed by the heater support plates and the basket diffuser which extends over the nozzle-inside-radius area.
Removal of the insulation and cables would be difficult as well as labor and time intensive. The radiation exposure to the personnel involved in performing the associated work is a real and relevant concern. It is almost certain that some, and possibly all, heater cables would have to be disconnected so that the cables can be pulled back to allow access for removing insulation and performing the exam. It is also likely that some cable or heater damage would occur during this removal. If it is assumed that all seventy-eight (78) heater cables have to be disconnected and pulled back, the dose estimate for this work is 8.5 man-rem.
Other personnel safety concerns potentially involved with this examination include the increased risk for an unplanned exposure event and prevention of contamination with NAPS UJ1 4-1ST Plan 2-7 Revision 0
Relief Request NDE-003 (continued) personnel working in tight spaces between the surge line and the exposed portion of the pressurizer heaters. While actions would be taken to prevent any such events, the large dose rate gradients in the under-pressurizer area challenge even the protection afforded by the best available technology. Temporary shielding is considered impractical in this regard because placement of the shielding material would obstruct and potentially preclude accessibility to the examination surface. Other issues include actual accessibility after removal of the various forms of interference and the likelihood of difficulties in replacing the insulation to its original configuration. Furthermore, the amount of examination coverage would be dependent on the overall accessibility obtained.
In conjunction with license renewal, Westinghouse performed an evaluation to address the impact of operational transients for North Anna Units to account for insurge/outsurge transients in addition to design transients in the pressurizer lower head. The results of the evaluation show that the Cumulative Usage Factor (CUF) for the nozzle inner radius is 0.17 (inside surface) and 0.09 (outside surface). The results determined the CUF for the lower head to nozzle weld to be 0.32 for the inside surface and 0.07 for the outside surface.
Fatigue is one of the prominent degradation mechanisms and the cumulative usage factor (CUF) is an indicator of fatigue for which the ASME design limit is 1.0. The ASME limit of 1.0 on the usage factor is a design threshold and is not intended to be a limit on serviceability.
The calculation of CUF is performed using the worst combinations of design transients, which are much more severe than actual operational transients. This introduces additional conservatism to the analysis. Thus, it can be said that the calculated CUF of 0.32 for all loading conditions including insurge/outsurge transients indicates that degradation due to fatigue is very small in the operating conditions. The environmental effects on fatigue were evaluated for the pressurizer surge line and the surge nozzle during license renewal application. It was determined that the surge line weld at the hot leg pipe connection will be inspected and used as the leading indicator for Environmentally Assisted Fatigue (EAF) concerns. The surge line weld at the hot leg pipe connection is included in augmented inspections as a part of our commitment for Aging Management. The results of these inspections and the results of planned research by the EPRI-sponsored Materials Reliability Program will be used to address and assess EAF for the surge nozzle. Dominion is unaware of any industry failure involving the either the surge line nozzle to vessel weld or the associated inside radius section of the surge line nozzles in a Westinghouse design pressurizer.
There are several uncertainties regarding an alternative examination of the inside surface of the pressurizer surge line area by use of a remote visual tool. Such an examination requires that a boroscope be fed through the manway and down through openings in the heater support baffles. Adding to the difficulty in performing such an exam, there is a perforated basket diffuser covering the surge nozzle opening on the inside of the pressurizer (Figure 3). The boroscope would need to be positioned through the support plates, and thenthreaded through a perforation in the basket diffuser, if possible, to the pressurizer surge line area. This examination will be partially obscured by the thermal sleeve, which extends beyond the inside radius area into the volume of the pressurizer. These obstructions would need to be NAPS UI 14-ISI Plan 2-8 Revision 0
Relief Request NDE-003 (continued) overcome several times in order to achieve the required examination coverage. Furthermore, the resulting examination would be of the cladding that covers the inside radius of the nozzle, which is considered to be only marginally beneficial in determining the structural integrity of the nozzle. Additionally, performing the visual inspection requires opening the RCS and establishing access and foreign material exclusion controls. The boroscope itself has the potential to become lodged inside the perforated basket diffuser or behind a pressurizer heater support plate.
Any ultrasonic examination on this nozzle could only be described as "best effort." The limited benefit gained would not be commensurate with the difficulty and anticipated exposure estimate of 8.5 man-rem to,perform this examination. An alternative examination employing a remote visual technology also has limited benefit as well as a limited probability of success. Therefore, Dominion concludes that this examination effort and the associated significant potential risk are not commensurate with the limited benefit that may be obtained from the inspection. As such, we are applying for relief per 10 CFR 50.55a(a)(3)(ii) since compliance with the specified requirements would result in hardship or unusual difficulties without a compensating increase in the level of quality and safety.
IV ALTERNATIVE PROVISIONS The pressurizer surge line nozzle-to-vessel weld and associated inner radius section wi 1l be VT-2 examined as part of the normally scheduled Class 1 system leakage test each refueling.
In addition, the surveillance requirements of Technical Specifications that determine the reactor coolant system leak rate and the containment atmosphere radioactivity will be satisfied. The pressurizer surge line weld to the reactor coolant hot leg will be examined as part of augmented inspections to detect environmentally affected fatigue and will be used as the leading indicator of EAF. Furthermore, Dominion has an active Boric Acid Corrosion Control Program that identifies and monitors borated water leakage to prevent boric acid related degradation of the Reactor Coolant System. These programs ensure that the overall level of plant quality and safety will not be compromised.
NRC letter dated February 18, 2005 granted similar relief for the fourth ten-year inservice inspection interval for Kewaunee Power Station. Relief was also granted for North Anna Power Station Unit 1 during the second and third inservice inspection intervals (TAC Nos.
M71066 and MA5750, respectively) and for North Anna Power Station Unit 2 for the second and third inservice inspection intervals (TAG Nos. M79147 and MB2280, respectively).
Similar relief was also granted for Surry Power Station Units 1 and 2 for the third inservice inspection intervals (TAC Nos. M87312 and M89085, respectively), and for the fourth inspection interval (TAC Nos. MD3673 and MD3674). Byron Station Units 1 and 2 were also granted relief for the second inservice inspection intervals (TAC Nos. M94830 and M94831 J respectively), and the Haddam Neck Plant was granted relief for the third inservice inspection interval (TAC No. M80457). Beaver Valley Power Station was also granted relief for their third inservice inspection interval in an NRC letter dated October 8,1997.
NAPS U1 14-ISI Plan 2-9 Revision 0
Relief Request NDE-003 (continued) ktslPen ~atiorn Slpowet Ra4et and Nozzlefor Spray Lwre salty Valve Nozzles N4- Marway Instnmunent Nozzles Liftin Trumnno Top View Opehlrlgi Le iel 7e Healer Elements Bottom view Nozzles 78 Heater Ekernrts SVirtI PRESSURIZER FIGURE 1 NAPS Ul 14-ISI Plan 2-10 Revision 0
RELIEF REQUEST NDE-004
- 1. IDENTIFICATION OF COMPONENTS Service Water System Components shown on the following drawings:
- 1) Drawing 11715-CBB-040D-3, Sheet 1 - 4"-WS-G01-163-Q3 and 4"-WS-F99-163-Q3
- 2) Drawing 11715-CBM-078A-3, Sheet 1 - 4"-WS-F62-163-Q3, 4"-WS-F64-163-Q3, 4"-WS-G35-163-Q3, 4"-WS-F63-163-Q3, 4"-WS-F65-163-Q3, and 8"-WS-94-163-Q3
- 3) Drawing 11715-CBM-078A-3, Sheet 4 - 8"-WS-113-163-Q3, 8"-WS-115-163-Q3, 8"-WS-114-163-Q3, and 8"-WS-1 16-163-Q3
- 4) Drawing 11715-CBM-078C-3, Sheet 2 - 2"-WS-84-163-Q3, 2"-WS-377-163-Q3, and 2"-
WS-376-163-Q3 Pressure retaining piping, fittings, and associated welds on moderate energy stainless steel piping of the Service Water System (SW). This piping system provides cooling water from the Service Water Reservoir to safety related equipment and returns the Service Water back to the return headers. Normal operating pressure is 100 psig. The design pressure is 150 psig and the design temperature is 150'F. This is an ASME,Section XI, Class 3 system.
Attachment 1 provides an identification of each piping segment within the scope of this Request for Relief. The piping segments are identified by their line number designation, which is a unique identifier. Attachment 2 provides the flaw assessment and evaluation procedure that proposed to assess the structural integrity of a flaw in the service water system. The procedure is based on the requirements contained in CC N-513-2 of Section XI.
II. IMPRACTICAL CODE REQUIREMENTS The Service Water System has experienced through-wall leakage caused by Microbiological Influenced Corrosion (MIC). While, chemical treatment of the Service Water System has been effective in reducing MIC; the Service Water System continues to be monitored for MIC.
Through-wall leakage is required to be located and evaluated in accordance with the requirements of IWA-5250 of the 2004 Edition for Unit 1. The specific Code requirement for which an alternative is proposed to the requirements of IWA-5250(a)(3).
"IWA-5250 Corrective Measures (a) The source of leakage detected during the conduct of a system pressure test shall be located and evaluated by the Owner for corrective measures as follows:
NAPS U1 T4-1ST Plan 2-11 Revision 0
Relief Request NDE-004 (continued)
(3) Components requiring corrective action shall have repair/replacement activities performed in accordance with IWA-4000 or corrective measures performed where the relevant condition can be corrected without a repair/replacement activity."
Articles IWA-4000 of ASME Section XI Code repair/replacements requirements would require removal of the flaw by either subsequent weld repair or replacement.
The use of ASME Code Case, N-513-2, "Evaluation Criteria for Temporary Acceptance of Flaws in Moderate Energy Class 2 or 3 Piping," is authorized for use by 10 CFR 50.55a rulemaking. However, the Code Case requires a Code repair or replacement not exceeding the time to the next scheduled outage. Additionally, the Code case provides no timeframe for completion of the evaluation of the flaw. As explained in the following paragraphs, these issues make the Code Case impractical for application at North Anna Power Station for repairs of the service water piping.
III. BASIS FOR RELIEF Code repairs for through-wall leaks require the line to be isolated and drained. Taking a train of service water out of service in some instances is a major evolution and requires entering a Technical Specification action statement. The Service Water System is common to both Units.
As long as one Unit is in Mode 1, 2, 3, or 4 both trains of service water must be operable. If both Units are in Mode 5 or 6, then one train of service water must be operable.
Historically, the timeframe from detection of the flaw to completion of the flaw evaluation process for the components in the affected system has been within 14 days of detection otherwise the component has been repaired or replaced. The timeframe for this process will be continued and is appropriate for the damage mechanism as approved previously by the NRC for NDE-32 (2nd interval corresponding relief request) in letter dated December 22, 1998 (TAC NOS. MA1222 and MA1223) NDE-15 (3rd interval corresponding relief request) in a letter dated April 27, 2000 (TAC No. MA8567).
IV. ALTERNATE PROVISIONS Code repairs in accordance with JWA-5250(a)(3) will be performed to the above identified welds and piping in the Service Water System within 14 days. Alternatively, an evaluation will be performed per the requirements of Attachment 1 to this request for relief. If supported by the evaluation, flaws will be replaced within 18 months from the time of discovery coinciding with an appropriate service water header outage. Because North Anna Power Station, Unit 1, is also on an 18-month refueling cycle, this allowed duration of operation is considered to comparable to industry expectations for repair of such leaks.
Attachment 1 provides the methodology that will be employed by North Anna in determining the acceptance of an identified flaw for continued service. The methodology is based on the requirements of ASME Code Case N-513-2, "Evaluation Criteria for Temporary Acceptance of Flaws in Class 3 Piping."
NAPS U1 14-ISI Plan 2-12 Revision 0
Relief Request NDE-004 (continued)
NRC Letter dated April 27, 2000, (TAC No. MA8567), states "This relief request is only applicable to SWS piping that is accessible to flaw characterization...." This limitation on the use of the relief granted by the April 27, 2000 letter will also govern the use of this request for relief.
V. REFERENCE
- 1. ASME Code Case N-513-2, "Evaluation Criteria for Temporary Acceptance of Flaws in Class 3 Piping."
Attachment:
- 1) Service Water Piping Flaw Assessment and Evaluation Procedure NAPS U I 14-ISI Plan 2-13 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 Service Water Piping Flaw Assessment and Evaluation Procedure 1 SCOPE a) Use of the flaw evaluation criteria within this attachment is permitted for pipe and tube associated with the Service Water System only. The flaw evaluation criteria are permitted for adjoining fittings and flanges to a distance of (R0 t) 11 2 from the weld centerline.
b) The provisions of this attachment do not apply to the following: 1) pumps, valves, expansion joints, and heat exchangers, 2) socket welds, 3) leakage through a flange joint; and
- 4) threaded connections employing nonstructural seal welds for leakage protection.
2 PROCEDURE (a) The flaw geometry shall be characterized by volumetric inspection methods or by physical measurement. The full pipe circumference at the flaw location shall be inspected to characterize the length and depth of all flaws in the pipe section.
(b) Flaw shall be classified as planar or nonplanar.
(c) When multiple flaws, including irregular (compound) shape flaws, are detected, the interaction and combined area loss of flaws in a given pipe section shall be accounted for in the flaw evaluation.
(d) A flaw evaluation shall be performed to determine the conditions for flaw acceptance. Section 3.0 provides accepted methods for conducting the required analysis.
(e) Frequent periodic inspections of no more than 30 day intervals shall be used to determine if flaws are growing and to establish the time at which the detected flaw will reach the allowable size. Alternatively, a flaw growth evaluation may be performed to predict the time at which the detected flaw will grow to the allowable size. The flaw growth analysis shall consider the relevant growth mechanisms such as general corrosion or wastage, fatigue, or stress corrosion cracking. When a flaw growth analysis is used to establish the allowable time for temporary operation, periodic examinations of no more than 90 day intervals shall be conducted to verify the flaw growth analysis predictions.
(f) For through-wall leaking flaws, leakage shall be observed by daily walkdowns to confirm the analysis conditions used in the evaluation remain valid.
(g) If examinations reveal flaw growth rate to be unacceptable, a repair or replacement shall be performed.
NAPS U] 14-ISI Plan 2-14 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 (h) Repair or replacement shall be performed no later than when the predicted flaw size from either periodic inspection or by flaw growth analysis exceeds the acceptance criteria of 4.0, or the next scheduled outage allows for removal of the components from service, whichever occurs first. Repair or replacement shall be in accordance with IWA-4000.
(i) Evaluations and examination shall be documented in accordance with IWA-6300.
Use of this request for relief shall be documented on the applicable data report form.
3 FLAW EVALUATION (Note: Reference in the following paragraphs to "Appendix C" is a reference to Nonmandatory Appendix C of the 2004 Edition of ASME Section XI)
(a) For planar flaws, the flaw shall be bounded by a rectangular or circumferential planar area in accordance with the methods described in Appendix C. IWA-3300 shall be used to determine when multiple proximate flaws are to be evaluated as a single flaw. The geometry of a through-wall planar flaw is shown in Fig. 1.
(b) For planar flaws in austenitic piping, the evaluation procedure in Appendix C shall be used. Flaw depths up to 100% of wall thickness may be evaluated. When through-wall circumferential flaws are evaluated, the formulas for evaluation given in C-5320 of Appendix C may be used, with the flaw penetration (alt) equal to unity.
When through-wall axial flaws are evaluated, the allowable flaw length is:
fa LSB8R-f(16 .)O 2 (]L)
= pD2t (2)
= (S, + S,)/2 (3) where p = pressure for the loading condition D, = pipe outside diameter rf = flow stress S, = Code specified yield strength S. = Code specified ultimate tensile strength and SF, = structural factor on primary membrane stress as specified in C-2622 Material properties at the temperature of interest shall be used.
NAPS U1 T4-1S1 Plan 2-15 Revision 0
Relief Request NDE-004. (continued)
Attachment 1 (c) For planar flaws in ferritic piping, the evaluation procedure of Appendix C shall be used.
Flaw depths up to 100% of wall thickness may be evaluated. When through-wall circumferential flaws are evaluated in accordance with C-5300 or C-6300, the flaw penetration (alt) shall be set to unity. When through-wall axial flaws are evaluated in accordance with C-5400, the allowable length is defined by Eqs. (1) through (3), with the appropriate structural factors from Appendix C, C-2622. When through-wall flaws are evaluated in accordance with C-7300 or C-7400, the formulas for evaluation given in C-4300 may be used, but with values for F,,, Fb, and F applicable to through-wall flaws.
Relations for F,,, Fb, and F that take into account flaw shape and pipe geometry (R/t ratio) shall be used. The appendix to this Attachment provides equations for Fm Fb, and F for a selected range of R/t. Geometry of a through-wall crack is shown in Fig. 1.
d) For nonplanar flaws, the pipe is acceptable when the remaining pipe thickness (tp) is greater than or equal to the minimum wall thickness t..i,,:
pDO (4) 2(S + 04p)(
where p = maximum operating pressure at flaw location S = allowable stress at operating temperature and the longitudinal stress limits for the Construction Code are satisfied for a uniform wall thickness equal to t,.
Alternatively, an evaluation may be performed as given below. The evaluation procedure is a function of the depth and the extent of the affected area as illustrated in, Fig. 2.
(1) When the width of wall thinning W,,,, that exceeds t,,m,,, is less than or equal to 0.5 (Rot) 11 2 where R, is the outside radius and Wm, is defined in Fig. 2, the flaw can be classified as a planar flaw and evaluated in accordance with 3(a) through 3(c), above. When the above requirement is not satisfied, (2) shall be met.
(2) When the transverse extent of wall thinning that exceeds tmini, L111(t), is not greater than (Rotm..n) 1/2 1, taloc is determined from Curve 1 of Fig. 3, where L,,,(t) is defined in Fig. 2. When the above requirement is not satisfied, (3) shall be met.
NAPS UI 14-ISI Plan 2-16 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 FIG, 2 ILLUSTRATION OF NONPLANAR FLAW DUE TO WALL THINNING A,
A1 SectiOn A-A A
Transverse (c rctpM ferenaIl)
Axial direction ditettion r
NAPS Ul 14-IST Plan 2-17 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 (3) When the maximum extent of wall thinning that exceeds t,,,,, L" , is less than or equal to 2.65 (Ro tmiln ) 1/2 and t~o, is greater than 1.13 tmn, taoc is determined by satisfying both of the following equations:
Il 1 5 /R,1M,,.f1 LI',,> 1.0
+10(5) t -I 1i, I +
Imin >
tt,, >_0.3534,, (6)
When the above requirements are not satisfied, (4) shall be met.
(4) When the requirements of (1), (2), and (3) above are not satisfied, t, 10, is determined from Curve 2 of Fig. 3. In addition, t,10, shall satisfy the following equation:
t,,, 0 ý Ind"
+ ( - - J ]
L.8 where ab is the nominal pipe longitudinal bending stress resulting from all primary pipe loadings.
(e) When there is through-wall penetration along a portion of the thinned wall, as illustrated in Fig. 4, the flaw may be evaluated by the branch reinforcement method. The thinned area including the through-wall penetration shall be represented by a circular opening at the flaw location. Only the portion of the flaw lying within tadj need be considered as illustrated in Fig. 5. When evaluating multiple flaws in accordance with IWA-3330, only the portions of the flaws contained within tadj need be considered.
The minimum wall thickness, tm,, 1 , shall be determined by eq. (4). For evaluation purposes, the adjusted wall thickness, tdj., is the postulated thickness as shown in Fig. 5. The pipe wall thickness is defined as the thickness of the pipe in the non-degraded region as shown in Fig. 5(a). The diameter of the opening is equal to d~dj as defined by tadj as shown in Fig. 5(a).
The postulated value for tadj shall be greater than t,,,i,, and shall not exceed the pipe wall thickness. The t,,dj value may be varied between t .. i, and the pipe wall thickness to determine whether there is a combination of tadj and dadj that satisfies the branch reinforcement requirements.
NAPS UI 14-ISI Plan 2-18 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 FIG. 3 ALLOWABLE WALL THICKNESS AND LENGTH OF LOCALLY THINNED AREA 1.0 0.8 0.6 0.4 ... .........
0.2 0 A .U .L .A. A 0 1 2 3 4 5 6 7 8
/
The required area reinforcement for the postulated circular opening, dadj and tjad, as illustrated in Fig. 5(b), shall be calculated in accordance with NC-3643.3 or ND-3643.3, as appropriate. If a flaw growth analysis is performed, the growth in flaw dimensions shall consider the degradation mechanism(s) as relevant to the application. The flaw is acceptable when there is sufficient thickness in the degraded area to provide the required area reinforcement. Compliance with the primary stress limits of the Construction Code shall be verified. The flow area of the flaw, or the total of the flow areas of multiple flaws that are combined into a single flaw for the purpose of evaluation, shall not exceed the lesser of the flow area of the pipe or 20 in2 (130 cm2).
(f) Alternatively, when there is through-wall penetration along a portion of the thinned wall as illustrated in Fig. 4 the flaw may be evaluated as two independent planar through-wall flaw-one oriented in the axial direction and the other oriented in the circumferential direction. The minimum wall thickness trai,, shall be determined by eq. (4). The through-wall lengths for each flaw are the lengths Laxial and Lcirc, where the local wall thickness is equal to tr1 in as projected along the axial and circumferential planes as shown in Fig. 4. The two planar flaws so constructed shall be evaluated to 3(a) and 3(b) or 3(c), as appropriate. If a flaw growth analysis is performed, the growth in flaw dimensions shall consider both corrosion and crack-growth mechanisms as relevant to the application. The flow area of the flaw, or the total of the flow areas of multiple flaws that are combined into a single flaw for the purpose of evaluation, shall not exceed the lesser of the flow area of the pipe or 20 in.2 NAPS 111 14-1ST Plan 2-19 Revision 0
(130 cmr).
Relief Request NDE-004 (continued)
Attachment 1 (g) In performing a flaw growth analysis, the procedures in C-3000 may be used as guidance. Relevant growth rate mechanisms shall be considered. When stress corrosion cracking (SCC) is active, the following growth rate equation shall be used:
da=dr STCKn,: (8) where da/dt is flaw growth rate in inches/hour, K,. is the maximum stress intensity factor under long-term steady state conditions in ksi in.05, ST is a temperature correction factor, and C and n are material constants.
For intergranular SCC in austenitic steels, where T < 200'F (93°C).
C = 1.79 X 10-8 ST =1 n = 2.161 For transgranular SCC in austenitic steels, where T < 200'F (93°C).
C - 1.79 X 10-7 ST 3.71 X 108 [ 1 0 (0.01842 T-12.25)]
n = 2.161 The temperature T is the metal temperature in degrees Fahrenheit. The flaw growth rate curves for the above SCC growth mechanisms are shown in Figs. 6 and 7. Other growth rate parameters in eq. (8) may be used, provided they are supported by appropriate data.
NAPS UI 14-ISI Plan 2-20 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 FIG. 4 ILLUSTRATION OF THROUGH-WALL NONPLANAR FLAW DUE TO WALL THINNIN Through-wall penetration trin t'7 N\
en, n, Section A-A 4
A Transverse (circumferential)
Axial / direction
-4/ direction A
NAPS U1 14-IST Plan 2-21 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 FIG. 5 ILLUSTRATION OF ADJUSTED WALL THICKNESS AND EQUIVALENT HOLE DIAMETEF Through-wallI
/ penetration lal Adjusted Wall Thickness t;mn (b1 Equivalent Hole Representation (h) For nonferrous materials, nonplanar and planar flaws may be evaluated following the general approach of 3(a) through 3(g) above. For planar flaws in ductile materials, the approach given in 3(b) and 3(g) may be used; otherwise, the approach given in 3(c) and 3(g) should be applied. Structural factors provided in 3 shall be used. It is the responsibility of the evaluator to establish conservative estimates of strength and fracture toughness for the piping material.
4 ACCEPTANCE CRITERIA Piping containing a circumferential planar flaw is acceptable for temporary service when flaw evaluation provides a margin using the structural factors in Appendix C. C-2621. For axial planar flaws, the structural factors for temporary acceptance are as specified in Appendix C. C-2622.
Piping containing a nonplanar part through-wall flaw is acceptable for temporary service if tp > tao, where talo, is determined from 3(d). Piping containing a nonplanar through-wall flaw is acceptable for temporary service when the flaw conditions of 3(e) or 3(f) are satisfied.
NAPS UI 14-ISI Plan 2-22 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 5 AUGMENTED EXAMINATION An augmented volumetric examination or physical measurement to assess degradation of the affected system shall be performed as follows:
(a) From the engineering evaluation, the most susceptible locations shall be identified. A sample size of at least five of the most susceptible and accessible locations, or, if fewer than five, all susceptible and accessible locations shall be examined within 30 days of detecting the flaw.
(b) When a flaw is detected, an additional sample of the same size as defined in 5(a) shall be examined.
(c) This process shall be repeated within 15 days for each successive sample, until no significant flaw is detected or until 100% of susceptible and accessible locations have been examined.
6 NOMENCLATURE C = coefficient in the crack growth relationship D,, = outside pipe diameter F = nondimensional stress intensity factor for through-wall axial flaw under hoop stress Fi, nondimensional stress intensity factor for through-wall circumferential ilaw under pipe
.bending" stress F11= nondimensional stress intensitv factor for through-wall circumferential flaw under mem-brane stress L = maximnum extent of a local thinned area with I < t)JUm L,,jaj = length of through-wall crack for the hole pene-tration in the axial direction of the pipe lchy' = length of through-wall crack for the hole diamn-eter pen tration in the circumferential direction of the pipe L1r = maximum extent of a local thinned area with I < tHmn L,(,j= axial extent of wall thinning below rm,,
NAPS U1 14-ISI Plan LM(0 circumnferential extent of wall thinning below Revision 0
Relief Request NDE-004 (continued)
Attachment 1 R = pipe radius RO = outside pipe radius S = allowable stress at operating temperature SF,i = structural factor on primary membrane stress ST = coefficient for temperature dependence in the crack growth relationship S, =: Code-specified ultimate tensile strength SY - Code-specified yield strength
,,4 =maximum extent of a local thinned area per-pendicular to L,,, with t < t,,;,
c = half crack length d(/dt = flaw growth rate for stress corrosion cracking dt = diameter equivalent circular hole at t,,,.*
d,13i,= diameter of equivalent circular hole at t C = total crack length = 2c
("an = allowable axial through-wall flaw length n = exponent in the crack growth relationship p = maximum operating pressure al flaw location I = wall thickness r,,ý = adjusted wall thickness which is varied for evaluation purposes in the evaluation of a through-wall nonplanar flaw
= allowable local thickness tor a nonplanar flaw tmn = muinum wall thickness required for pressure loading
,,r,,rt nominal wall thickness i, = minimum remaining wall thickness A = nondimensional half crack length for through-wall axial flaw t- = material flow stress q,, = pipe hox)p stress due to pressure ai, = nominal longitudinal bending stress for pri-mary loading withouLi stress intensification factor 0 = half crack angle for througrh-wall circumferen-tial flaw NAPS U I 14-ISI Plan 2-24 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 FIG. 6 FLAW GROWTH RATE FOR IGSCC IN AUSTENITIC PIPING I.OE-02 1.OE-05 S1.OE-06 1 10 100 Stress Intensity Factor, K~ksi in-0-5)
GENERAL NOTE: (SI convemi on: 1.0 in/hr = 7-06 x 10 mm/sec; 1.0 Ki 'tn." , =I ogg MPa m11; T = PF-32111l8i NAPS UI 14-ISI Plan 2-25 Revision 0
Attachment 1 Relief Request NDE-004 (continued)
FIG. 7 FLAW GROWTH RATE FOR TGSCC IN AUSTENITIC PIPING I£OE-02 1t0E-03 1.OE-04
- 1.0Eo05 I.OE-07 iFOE-1.OE-O9 ii Stress Intensity Factor, K (ksi i,-P5 )
GENERAL NOTE: (SI coDnvers**n: 1,0 ithr = 7.06x.01/4 trm/sec- 1.0 K).i it ._ = 5;C = V°oF - 321/V1.).
3,099 MPa M'-;
NAPS UI 14-1TS Plan 2-26 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 MANDATORY APPENDIX I RELATIONS FOR F, Fb, AND F FOR THROUGH-WALL FLAWS I-1 DEFINITIONS For through-wall flaws, the crack depth (a) will be replaced with half crack length (c) in the stress intensity factor equations in C-7300 and C-7400 of Section XI, Appendix C. Also, Q will be set equal to unity in C-7400.
1-2 CIRCUMFERENTIAL FLAWS For a range of R/t between 5 and 20, the following equations for F, and Fb may be used:
25 ,*' (*W)3i5 F, I + A,, ((*r)15 + B,, (0U'%) +
14 = I + A, (00r)'- + B, (67/)2 -' + Cb (0*T) 3 "
where 0 = Half crack angle = c/R R = Mean pipe radius t = Pipe wall thickness and A,,. = -2.02917 + 1.67763 (Rkt) -0.07987 (Rkt)' + 0.00176 (Rkt)'
B,.. = 7.09987 -4.42394 (Rkt) + 0.21036 (Rkt)2 - 0.00463 (Rkt)3 Cm = 7.79661 + 5.16676 (Rkt) - 0.24577 (Rkt) + 0.00541 (Rkt)'
Ab = -3.26543 + 1.52784 (Rkt) -0.072698 (Rkt)2 + 0.00160 II (Rkt)'
Bb = 11.36322 -3.91412 (Rkt) + 0.18619 (Rkt)2 -0.004099 (Rkt) 3 Cb = -3.18609 + 3.84763 (Rkt) -0.18304 (Rkt)2 + 0.00403 (Rkt)3 Equations for F.. and Fb are accurate for Rkt between 5 and 20 and become increasingly conservative for Rkt greater than 20. Alternative solutions for F,,, and Fb may be used when Rkt is greater than 20.
NAPS U I 14-ISI Plan 2-27 Revision 0
Relief Request NDE-004 (continued)
Attachment 1 1.3 AXIAL FLAWS For internal pressure loading, the following equation for F may be used:
2 3 4 5 F - I + 0.072449k* + 0.64856k - 0.2327k + 0.038 154k - 0.0023487k where c = half crack length A =c(Rt)112 The equation for F is accurate for k between 0 and 5. Alternative solutions for F may be used when k is greater than 5.
NAPS UI 14-ISI Plan 2-28 Revision 0
RELIEF REQUEST NDE-005 IDENTIFICATION OF COMPONENTS Code Class: Class 1 System Welds: Reactor Coolant System (RCS)
Component Descriptions and Category Identification:
This alternative is applicable to preemptive weld overlays (PWOL) on the six potentially PWSCC susceptible dissimilar safe end-to-pressurizer nozzle welds that also were extended across the adjacent stainless steel pipe/fitting/elbow-to-safe end welds. The RCS welds affected by the PWOL welds are:
- 1. Weld No. SW-51, 14-inch RCS Safe End Reducer-To-Surge Nozzle Weld, Category B-F; and adjacent Pipe-to-Safe End Reducer Weld No. 39, Category B-J (Pipe Identifier 14-RC-10-2501R-Q1).
- 2. Weld No. SW-30, 6-inch Safe End-to-Safety Nozzle-Weld, Category B-F; and adjacent Elbow-to-Safe End Weld No. 21 Category B-J (Pipe Identifier 6-RC-38-1502-Q1).
- 3. Weld No. SW-31, 6-inch Safe End-to-Safety Nozzle-Weld Category B-F; and adjacent Elbow-to-Safe End Weld No. 17 Category B-J (Pipe Identifier 6-RC-39-1502-Q1).
4.Weld No. SW-38, 6-inch Safe End-to-Safety Nozzle-Weld Category B-F; and adjacent Elbow-to-Safe End Weld No.25 Category B-J (Pipe Identifier 6-RC-37-1502-Q1).
- 5. Weld No. SW-64, 6-inch Safe End-to-Relief Nozzle-Weld Category B-F; and adjacent 6X4 Concentric Reducer-to-Safe End Weld No. 30 Category B-J (Pipe Identifier 4-RC-34-1502-Q 1).
6.Weld No. SW-71, 4-inch Safe End-to-Spray Nozzle-Weld Category B-F; and adjacent Pipe-to-Safe End Weld No. 11 Category B-J (Pipe Identifier 4-RC-15-1502-Q 1).
II. CODE REQUIREMENT
- 1. ASME Section XI 2004 Edition (Section XI) in paragraph IWA-2232 requires that the ultrasonic volumetric examination of welds be performed in accordance with Appendix I which in turn requires that the examinations be performed in accordance with Appendix VIII - specifically Supplement 11 of Appendix VIII.
- 2. In addition, IWB-2500 specifies the extent, frequency, and acceptance criteria for examinations of the welds, but does not provide requirements for structural overlay welds.
NAPS TU1 14-1ST Plan 2-29 Revkisin 0
Relief Request NDE-005 (continued)
- 3. IWB-2430 specifies requirements for the examinations of supplemental welds, if unacceptable indications are identified as the result of the required examinations.
III. BASIS FOR ALTERNATIVE Dissimilar metal welds, primarily consisting of Alloy 82/182 weld metal are frequently used in pressurized water reactor (PWR) construction to connect stainless steel pipe and safe ends to vessel nozzles, generally constructed of carbon or low alloy ferritic steel. Dissimilar metal welds have shown a propensity for primary water stress corrosion cracking (PWSCC) degradation, especially in components subjected to higher operating temperatures, such as the pressurizer. The subject welds were overlaid as mitigation against the potential cracking of these welds in their as designed and installed state.
During the North Anna Unit 1 fall 2007 refueling outage, six Class 1 dissimilar metal welds located on the pressurizer were modified to have full structural preemptive weld overlays (PWOLs). Due to their proximity, these welds also were extended across the adjacent stainless steel pipe/fitting/elbow-to-safe end weld. (See Figure 1.) Repair/replacement activities associated with PWOL repairs are required to address examination techniques and procedure requirements as part of the repairs. Comprehensive and generic NRC approved criteria are, however, are not currently available for application of PWOL repairs to dissimilar metal welds. In addition the ASME Section XI Code or associated Code Cases do not provide approved industry requirements/criteria for examination of the PWOL welds but do provide criteria for the examination of the welds overlaid.
As part of this repair/replacement activity performed in the fall of 2007, North Anna Unit 1 committed, in part, to performing an ultrasonic volumetric inservice examination of 25% of the PWOL welds once every 10 years. Specific alternative examination requirements were included in the third interval request for relief, CMP-022R1, approved by the NRC for the application of the overlays.
However, the third interval approval expires on April 30, 2009, the end of the third inspection interval. These alternatives are also applicable to the performance of the associated interval four examination commitments. Therefore, North Anna Unit 1 needs to request approval to use the applicable alternatives in the fourth interval; and, requests the proposed alternative shall be met in lieu of all other examination requirements.
Nondestructive examination methods shall be in accordance with 1WA-2200, except as specified herein. Nondestructive examination personnel shall be qualified in accordance with 1WA-2300. Ultrasonic examination procedures and personnel shall be qualified in accordance with Appendix VIII, Supplemented 11, revised as proposed in Table 1.
NAPS U1 14-ISI Plan 2-30 Revision 0
Relief Request NDE-005 (continued)
SS Elbow.'-
/--ElbowISE Weld (SS)
ASS Safe End (SA-182 F316L)
~rSEi'ozzle Wel2dBalance PWOL (A52h-_I_ 'L A821 RootA'
-We ~ Btterieng (A132)
-Low Alloy Steel_
Nozzle (SA-508 Class. 2)
Figure 1 - Typical PWOL Configuration NAPS UI 14-ISI Plan 2-31 Revision 0
Relief Request NDE-005 (continued)
A. Proposed Alternatives to Supplement 11, Appendix VIII, 2001 Edition of Section XI The ultrasonic examination of the completed PWOLs associated with the initial fabrication of the PWOL as well as the first inservice examination were performed in accordance with the ASME Code Section XI, 1989 Edition with compliance to the 1995 Edition including Addenda through 1996, Appendix VIII, Supplement 11 with the alternatives used for complying with the current requirements of the Performance Demonstration Initiative (PDI)
Program. The ultrasonic volumetric examinations in the fourth interval will be performed in accordance with the requirements of ASME Section XI, 200lEdition, Appendix VIII, Supplement 11. The requirements to be used in the fourth interval are essentially the same as those used in the third interval; therefore, the same alternatives to comply with the current requirements of the PDI are proposed. The alternatives are presented and discussed in Table 1 (See Attachment 1).
The proposed alternative paragraphs were part of the PDI protocol that qualified the examination procedures and the personnel that performed the preservice and inservice examinations performed in the third inspection interval. To change the basis of the PDI qualification may cause the qualification performed to support the initial examinations to no longer be acceptable. Requalification may be necessary. Based on the current positions of the PDI in implementing the requirements, it may be difficult to meet the original protocol as presented in the 2001 Edition. North Anna Power Station believes that implementation of 2001 Edition of Section XI , Appendix VIII, Supplement 11 modified as requested is consistent with current industry practice and provides an acceptable level of quality and safety.
B Proposed Additional Alternatives to Examination Requirements of Section XI a) Examination Requirements (1) As a minimum, twenty-five percent of the subject welds shall be examined ultrasonically during the fourth inservice inspection interval (2) The weld overlay examination volume in Fig. 2 shall be ultrasonically examined to determine if any new or existing cracks have propagated into the upper 25% of the base material or into the overlay. The angle beam shall be directed perpendicular and parallel to the piping axis, with scanning performed in four directions.
(3) The inservice examination acceptance standards of Table IWB-3514-2 shall be met for the weld overlay. If the acceptance criteria of Table IWB-3514-2 cannot be met, the acceptance criteria of IWB-3600 shall be met for the weld overlay. Cracks in the outer 25% of the base metal shall meet the design analysis requirements of Attachment 2, Crack Growth and Design.
(4) If inservice examinations reveal crack growth, or new cracking, which meet the acceptance criteria of IWB-3514, IWB-3600, the weld overlay examination volume shall be reexamined during the first or second refueling outage following discovery of the growth or new cracking.
NAPS U1 14-ISI Plan 2-32 Revision 0
Relief Request NDE-005 (continued)
(5) For weld overlay examination volumes with unacceptable indications according to B a)(3), the weld overlay shall be removed, including the original defective weld, and the item shall be corrected by a repair/replacement activity in accordance with IWA-4000.
b) Additional Examinations If inservice examinations reveal an unacceptable indication according to B a)(3) crack growth into the weld overlay design thickness, or axial crack growth beyond the specified examination volume, additional weld overlay examination volumes, equal to the number scheduled for the current inspection period, shall be examined prior to return to service. If additional unacceptable indications are found in the second sample, a total of 50% of the total population of weld overlay examination volumes shall be examined prior to operation. If additional unacceptable indications are found, the entire remaining population of weld overlay examination volumes shall be examined prior to return to service.
IV PROPOSED ALTERNATIVE REQUIREMENTS The proposed alternative requirements of the request will allow the initial program established for the PWOLs to continue into the fourth interval. This set of alternatives establish an examination program for the subject welds in the fourth inspection interval that is consistent with the requirements established at the time the PWOLs were approved for the fall of 2007. As was established by their initial approval, these alternatives used in conjunction with the remaining requirements of Section XI provide acceptable level of quality and safety.
NAPS U1 14-ISI Plan 2-33 Revision 0
Relief Request NDE-005 (continued)
FIG. 2 PRESERVICE AND INSERVICE EXAMINATION VOLUME 1/2 In. (min.) *
- 1/2 in. (rain.)
A-7 B(Note 1)
D B Examination Volume A-B-C-D3 NOTES:
(1) For axial or circumferential flaws, the axial extent of the examination volume shall extend at least 1/2 in. (13mm) beyond the as-found flaw and at least 1/2 in. (13mm) beyond the toes of the original weld.
(2) The weld includes weld end butter, where applied.
NAPS U1 14-ISI Plan 2-34 Revision 0
Relief Request NDE-5 (continued)
Attachment 1 TABLE 1 PDI Program Modifications to Appendix VIII Supplement 11 Appendix VIII, Supplement 11 - PDI Program:
Qualification Stualfcatua Requirements for Full Oequrl W s oroFugt The Proposed Alternative to Supplement 11 Structural Overlaid Wrought Rqieet Austenitic Piping Welds Requirements 1.0 SPECIMEN REQUIREMENTS 1.1 General The specimen set shall conform to the following requirements.
(b) The specimen set shall consist of at Alternative: (b) The specimen set shall consist of at least least three specimens having different three specimens having different nominal pipe diameters nominal pipe diameters and overlay and overlay thicknesses. They shall include the minimum thicknesses. They shall include the and maximum nominal pipe diameters for which the examination procedure is applicable. Pipe diameters minimum and maximum nominal pipe within a range of 0.9 to 1.5 times a nominal diameter shall diameters for which the examination be considered equivalent. If the procedure is applicable procedure is applicable. Pipe diameters to pipe diameters of 24 inches or larger, the specimen set within a range of 0.9 to 1.5 times a must include at least one specimen 24 inches or larger, nominal diameter shall be considered but need not include the maximum diameter.
equivalent. If the procedure is The specimen set shall include specimens with overlays not thicker than 0.1 inches more than the minimum ainchsorlabler, tohpe dpciamet to 2 t thickness, nor thinner than 0.25 inches of the maximum inches or larger, the specimen set must nominal overlay thickness for which the examination include at least one specimen 24 inches procedure is applicable.
or larger, but need not include the Basis: To avoid confusion, the overlay thickness maximum diameter. The specimen set tolerance contained in the last sentence was reworded and must include at least one specimen with the phrase "and the remainder shall be alternative flaws" overlay thickness within -0.1 inches to was added to the next to last sentence in paragraph 1.1 (d)
+0.25 inches of the maximum nominal (1). 7 overlay thickness for which the procedure is applicable.
(d) Flaw Conditions (1) Base metal flaws. All flaws must Alternative: (1) Base metal flaws. All flaws must be in be cracks in or near the butt weld heat- or near the butt weld heat-affected zone, open to the NAPS UI 14-ISI Plan 2-35 Revision 0
Relief Request NDE-5 (continued)
Attachment 1 Appendix VIII, Supplement 11 - PDI Program:
Qualification Stualfcatua Requirements for Full Oequrl W s oroFugt The Proposed Alternative to Supplement 11 Structural Overlaid Wrought Austenitic Piping Welds Rqieet Requirements affected zone, open to the inside inside surface, and extending at least 75% through the surface, and extending at least 75% base metal wall. Intentional overlay fabrication flaws through the base metal wall. Flaws shall not interfere with ultrasonic detection or may extend 100% through the base characterization of the base metal flaws. Specimens metal and into the overlay material; in containing IGSCC shall be used when available. At least this case, intentional overlay fabrication 70% of the flaws in the detection and sizing tests shall be flaws shall not interfere with ultrasonic cracks and the remainder shall be alternative flaws.
detection or characterization of the Alternative flaw mechanisms, if used, shall provide crack-cracking. Specimens containing like reflective characteristics and shall be limited by the IGSCC shall be used when available. following:
(a) The use of alternative flaws shall be limited to when the implantation of cracks produces spurious reflectors that are uncharacteristic of actual flaws.
(b) Flaws shall be semi-elliptical with a tip width of less than or equal to 0.002 inches.
Basis: This paragraph requires that all base metal flaws be cracks. Implanting a crack requires excavation of the base material on at least one side of the flaw. While this may be satisfactory for ferritic materials, it does not produce a useable axial flaw in austenitic materials because the sound beam, which normally passes only through base material, must now travel through weld material on at least one side, producing an unrealistic flaw response. To resolve this issue, the PDI program revised this paragraph to allow use of alternative flaw mechanisms under controlled conditions. For example, alternative flaws shall be limited to when implantation of cracks precludes obtaining an effective ultrasonic response, flaws shall be semi-elliptical with a tip width of less than or equal to 0.002 inches, and at least 70% of the flaws in the detection and sizing test shall be cracks and the remainder shall be alternative flaws. To avoid NAPS UI 14-ISI Plan 2-36 Revision 0
Relief Request NDE-5 (continued)
Attachment 1 Appendix VIII, Supplement 11 - PDI Program:
Qualification Requirements for Full The Proposed Alternative to Supplement 11 Structural Overlaid Wrought Requirements Austenitic Piping Welds confusion, the overlay thickness tolerance contained in paragraph 1.1(b) last sentence, was reworded and the phrase "and the remainder shall be alternative flaws" was added to the next to last sentence. Paragraph 1.1(d)(1) includes the statement that intentional overlay fabrication flaws shall not interfere with ultrasonic detection or characterization of the base metal flaws.
(e) Detection Specimens i
(1) At least 20%, but less than 40%, of Alternative: (1) At least 20%, but less than 40%, of the the flaws shall be oriented within +20 base metal flaws shall be oriented within +/-20 degrees of degrees of the pipe axial direction. The the pipe axial direction. The remainder shall be oriented circumferentially. Flaws shall not be open to any surface remainder shall be oriented to which the candidate has physical or visual access.
circumferentially. Flaws shall not be Basis: The requirement for axially oriented overlay open to any surface to which the fabrication flaws was excluded from the PDI Program as candidate has physical or visual access.
an improbable scenario. Weld overlays are typically The rules of IWA-3300 shall be used to applied using automated GTAW techniques with the filler determine whether closely spaced flaws metal applied in a circumferential direction. Because should be treated as single or multiple resultant fabrication induced discontinuities would also be flaws.
expected to have major dimensions oriented in the circumferential direction axial overlay fabrication flaws are unrealistic. The requirement for using IWA-3300 for proximity flaw evaluation was excluded; instead indications will be sized based on their individual merits.
(2) Specimens shall be divided into Alternative: (2) Specimens shall be divided into base base and overlay grading units. Each metal and overlay fabrication grading units. Each specimen shall contain one or both specimen shall contain one or both types of grading units.
Flaws shall not interfere with ultrasonic detection or types of grading units.
characterization of other flaws.
(a)(1) A base grading unit shall include Alternative: (a)(1) A base metal grading unit includes the at least 3 inches of the length of the overlay material and the outer 25% of the original overlaid weld. The base grading unit overlaid weld. The base metal grading unit shall extend NAPS UI 14-ISI Plan 2-37 Revision 0
Relief Request NDE-5 (continued)
Attachment 1 Appendix VIII, Supplement 11 - PDI Program:
Qualification Requirements for Full Suctural Ovequrlai W s oroFugt The Proposed Alternative to Supplement 11 Structural Overlaid Wrought Austenitic Piping Welds Requirements includes the outer 25% of the overlaid circumferentially for at least 1 inch and shall start at the weld and base metal on both sides. The weld centerline and be wide enough in the axial direction base grading unit shall not include the to encompass one half of the original weld crown and a inner 75% of the overlaid weld and minimum of 0.50 inch of the adjacent base material.
Basis: The phrase "and base metal on both sides," was basemetaloverlay material. or inadvertently included in the description of a base metal grading unit, The PDI program intentionally excludes this requirement because some of the qualification samples include flaws on both sides of the weld. To avoid confusion, several instances of the term "cracks" or "cracking" were changed to the term "flaws" because of the use of alternative flaw mechanisms. Modified to require that a base metal grading unit include at least 1 inch of the length of the overlaid weld, rather than 3 inches.
(a)(2) When base metal cracking Alternative: (a)(2) When base metal flaws penetrate into penetrates into the overlay material, the the overlay material, the base metal grading unit shall not base grading unit shall include the be used as part of any overlay fabrication grading unit.
overlay metal within 1 inch of the crack location. This portion of the overlay material shall not be used as part of any overlay grading unit.
(a)(3) When a base grading unit is Alternative: (a)(3) Sufficient unflawed overlaid weld and designed to be unflawed, at least 1 inch base metal shall exist on all sides of the grading unit to of unflawed overlaid weld and base preclude interfering reflections from adjacent flaws.
metal shall exist on either side of the base grading unit. The segment of weld Basis: Modified to require sufficient unflawed overlaid length used in one base grading unit weld and base metal to exist on all sides of the grading shall not be used in another base unit to preclude interfering reflections from adjacent grading unit. Base grading units need flaws, rather than the 1 inch requirement.
not be uniformly spaced around the specimen.
(b)(l) An overlay grading unit shall Alternative: (b)(l) An overlay fabrication grading unit NAPS U] 14-ISI Plan 2-38 Revision 0
Relief Request NDE-5 (continued)
Attachment 1 Appendix VIII, Supplement 11 - PDI Program:
Qualification Sualiicatul Requirements for Full Oequrl W s oroFugt The Proposed Alternative to Supplement 11 Structural Overlaid Wrought Rqieet Austenitic Piping Welds Requirements include the overlay material and the shall include the overlay material and the base metal-to-base metal-to-overlay interface of at overlay interface for a length of at least 1 inch.
least grading6 unit square inches. The overlay shuall bnchera he lar, w Basis: Modified to require sufficient unflawed overlaid mradinimum nsion ofall 2eietnc , w weld and base metal to exist on all sides of the grading minimum dimensions of 2 inches.
unit to preclude interfering reflections from adjacent flaws, rather than the 1 inch requirement.
(b)(2) An overlay grading unit designed Alternative: (b)(2) Overlay fabrication grading units to be unflawed shall be surrounded by designed to be unflawed shall be separated by unflawed unflawed overlay material and overlay material and unflawed base metal-to-overlay unflawed base metal-to-overlay interface for at least 1 inch at both ends. Sufficient interface for at least 1 inch around its unflawed overlaid weld and base metal shall exist on both entire perimeter. The specific area used sides of the overlay fabrication grading unit to preclude in one overlay grading unit shall not be interfering reflections from adjacent flaws. The specific used in another overlay grading unit. area used in one overlay fabrication grading unit shall not Overlay grading units need not be be used in another overlay fabrication grading unit.
spaced uniformly about the specimen. Overlay fabrication grading units need not be spaced uniformly about the specimen.
Basis: (b)(2) states that overlay fabrication grading units designed to be unflawed shall be separated by unflawed overlay material and unflawed base metal-to-overlay interface for at least 1 inch at both ends, rather than around its entire perimeter.
(b)(3) Detection sets shall be selected Alternative: (b)(3) Detection sets shall be selected from from Table VIII-S2-1. The minimum Table VIII-S2- 1. The minimum detection sample set is detection sample set is five flawed base five-flawed base metal grading units, ten unflawed base grading units, ten unflawed base metal grading units, five flawed overlay fabrication grading units, five flawed overlay grading units, and ten unflawed overlay fabrication grading units, and ten unflawed overlay grading units. For each type of grading unit, the set shall grading units. For each type of grading contain at least twice as many unflawed as flawed grading unit, the set shall contain at least twice units. For initial procedure qualification, detection sets as many unflawed as flawed grading shall include the equivalent of three personnel qualification sets. To qualify new values of essential NAPS UI 14-ISI Plan 2-39 Revision 0
Relief Request NDE-5 (continued)
Attachment 1 Appendix VIII, Supplement 11 - PDI Program:
Qualification Requirements for Full Stualfcatua Oequrl W s oroFugt The Proposed Alternative to Supplement 11 Structural Overlaid Wrought Austenitic Piping Welds Requirements units. variables, at least one personnel qualification set is required.
(f) Sizing Specimen (1) The minimum number of flaws shall Alternative: (1) The minimum number of flaws shall be be ten. At least 30% of the flaws shall ten. At least 30% of the flaws shall be overlay fabrication be overlay fabrication flaws. At least flaws. At least 40% of the flaws shall be open to the 40% of the flaws shall be cracks open inside surface. Sizing sets shall contain a distribution of to the inside surface. flaw dimensions to assess sizing capabilities. For initial procedure qualification, sizing sets shall include the equivalent of three personnel qualification sets. To qualify new values of essential variables, at least one personnel qualification set is required.
(3) Base metal cracking used for length Alternative: (3) Base metal flaws used for length sizing sizing demonstrations shall be oriented demonstrations shall be oriented circumferentially.
circumferentially.
(4) Depth sizing specimen sets shall Alternative: (4)' Depth sizing specimen sets shall include include at least two distinct locations at least two distinct locations where a base metal flaw where cracking in the base metal extends into the overlay material by at least 0.1 inch in extends into the overlay material by at the through-wall direction.
least 0.1 inch in the through-wall direction.
2.0 CONDUCT OF PERFORMANCE DEMONSTRATION The specimen inside surface and Alternative: The specimen inside surface and identification shall be concealed from identification shall be concealed from the candidate. All the candidate. All examinations shall examinations shall be completed prior to grading the be completed prior to grading the results and presenting the results to the candidate.
results and presenting the results to the Divulgence of particular specimen results or candidate candidate. Divulgence of particular viewing of unmasked specimens after the performance specimen results or candidate viewing *demonstration is prohibited. The overlay fabrication flaw NAPS U I 14-ISI Plan 2-40 Revision 0
Relief Request NDE-5 (continued)
Attachment 1 Appendix VIII, Supplement 11 - PDI Program:
Qualification Requirements for Full The Proposed Alternative to Supplement 11 Structural Overlaid Wrought Requirements Austenitic Piping Welds of unmasked specimens after the test and the base metal flaw test may be performed performance demonstration is separately.
prohibited.
2.1 Detection Test Flawed and unflawed grading units Alternative: Flawed and unflawed grading units shall be shall be randomly mixed. Although the randomly mixed. Although the boundaries of specific boundaries of specific grading units grading units shall not be revealed to the candidate, the shall not be revealed to the candidate, candidate shall be made aware of the type or types 'of the candidate shall be made aware of grading units (base metal or overlay fabrication) that are the type or types of grading units (base present for each specimen.
or overlay) that are present for each specimen.
2.2 Length Sizing Test (d) For flaws in base grading units, the Alternative: (d) For flaws in base metal grading units, candidate shall estimate the length of the candidate shall estimate the length of that part of the that part of the flaw that is in the outer flaw that is in the outer 25% of the base metal wall 25% of the base wall thickness. thickness.
2.3 Depth Sizing Test For the depth sizing test, 80% of the Alternative: (a) The depth sizing test may be conducted flaws shall be sized at a specific separately or in conjunction with the detection test.
location on the surface of the specimen (b) When the depth sizing test is conducted in conjunction identified to the candidate. For the with the detection test and the detected flaws do not remaining flaws, the regions of each satisfy the requirements of 1.1(f), additional specimens shall be provided to the candidate. The regions specimen containing a flaw to be sized containing a flaw to be sized shall be identified to the shall be identified to the candidate. The candidate. The candidate shall determine the maximum candidate shall determine the maximum depth of the flaw in each region.
depth of the flaw in each region. (c) For a separate depth sizing test, the regions of each specimen containing a flaw to be sized shall be identified to the candidate. The candidate shall determine the maximum depth of the flaw in each region.
NAPS UI 14-ISI Plan 2-41 Revision 0
Relief Request NDE-5 (continued)
Attachment 1 Appendix VIII, Supplement 11 - PDI Program:
Qualification Requirements for Full Stualicatua Oequrl W s oroFugt The Proposed Alternative to Supplement 11 Structural Overlaid Wrought Rqieet Austenitic Piping Welds Requirements 3.0 ACCEPTANCE CRITERIA 3.1 Detection Acceptance Criteria Examination procedures, equipment, Alternative: Examination procedures are qualified for and personnel are qualified for detection when:
detection when the results of the (a) All flaws within the scope of the procedure are edemonstration satisfy the detected and the results of the performance demonstration performance crtsatisfy the acceptance criteria of Table VIII-S2-1 for false acceptance criteria of Table VIII-S2-l calls.
for both detection and false calls. The (b) At least one successful personnel demonstration has criteria shall be satisfied separately by been performed meeting the acceptance criteria defined in the demonstration results for base (c).
grading units and for overlay grading (c) Examination equipment and personnel are qualified units. for detection when the results of the performance demonstration satisfy the acceptance criteria of Table VIII-S2-1 for both detection and false calls.
(d) The criteria in (b) and (c) shall be satisfied separately by the demonstration results for base metal grading units and for overlay fabrication grading units.
3.2 Sizing Acceptance Criteria (a) The RMS error of the flaw length Alternative: (a) The RMS error of the flaw length measurements, as compared to the true measurements, as compared to the true flaw lengths, is flaw lengths, is less than or equal to less than or equal to 0.75 inch. The length of base metal 0.75 inch. The length of base metal flaws is measured at the 75% through-base-metal cracking is measured at the 75% position.
through-base-metal position.
(b) All extensions of base metal Alternative: This requirement is omitted.
cracking into the overlay material by at leastk0.1 inchare rveporlaymtedias bei Basis: The requirement for reporting all extensions of intrusions into the overlay material, cracking into the overlay is omitted from the PDI Program because it is redundant to the RMS calculations performed in paragraph 3.2(c) and its presence adds confusion and ambiguity to depth sizing as required by paragraph 3.2(c). This also makes the weld overlay NAPS U I14-ISI Plan 2-42 Revision 0
Relief Request NDE-5 (continued)
Attachment 1 Appendix VIII, Supplement 11 - PDI Program:
Qualification Requirements for Full Structural Overlaid Wrought The Proposed Alternative to Supplement 11 Austenitic Piping Welds Requirements program consistent with the supplement 2 depth sizing criteria.
NAPS U I 14-ISI Plan 2-43 Revision 0
Relief Request NDE-005 (continued)
Attachment 2 CRACK GROWTH AND DESIGN (A) Crack Growth The size of all flaws detected or postulated in the original weldment shall be projected to the end of the expected life of the overlay. Crack growth due to both stress corrosion and fatigue shall be evaluated. Flaw characterization and evaluation shall be based on the ultrasonic examination results.
(1) For repair overlays, the initial flaw size for crack growth shall be based on the as-found flaw.
(2) For mitigative overlays, the initial postulated flaw size for crack growth shall be assumed consistent with the examinations performed, either pre or post overlay. The axial flaw length shall be set at 1.5 inches (38 mm) or the combined width of the weld plus buttering, whichever is greater. The circumferential flaw length shall be assumed to be 360 degrees.
(a) If no examination is performed prior to application of the overlay, initial flaws equal to 100% through the original wall thickness shall be assumed, in both the axial and circumferential directions, consistent with the overlay inservice inspection volume in Fig. 2.
(b) There may be circumstances in which an overlay examination is performed using an ultrasonic examination procedure, which is qualified in accordance with Appendix VIII, Supplement 11 for depths greater than the outer 25% of the original wall thickness (Fig.
2). For such cases, initial flaw sizes may be assumed consistent with the depth to which the examination procedure is qualified.
(c) Any inside surface connected planar flaw found by the overlay preservice inspection of paragraph 3(b), which exceed the depth of (a), or (b) above, shall be used as the initial flaw depth in determining the expected life of the overlay. Overlays meeting this condition shall be considered a repair.
(B) Structural Design and Sizing of the Overlay The design of the weld overlay shall satisfy the following using the assumptions and flaw characterization restrictions in paragraph (A). The following design analysis shall be completed in accordance with IWA-4311.
(1) The axial length and end slope of the weld overlay shall cover the weld and the heat affected zones on each side of the weld, and shall provide for load redistribution from the item into the weld overlay and back into the item without violating applicable stress limits of NB-3200, or the Construction Code. Any laminar flaws in the weld overlay shall be evaluated in the analysis to ensure that load redistribution complies with the above. These requirements will usually be satisfied if the weld overlay full thickness length extends axially beyond the projected flaw by at least 0.75'lRt, where R is the outer radius of the item and t is the nominal wall thickness of the item.
NAPS U1 14-ISI Plan 2-44 Revision 0
Relief Request NDE-005 (continued)
Attachment 2 (2) Unless specifically analyzed in accordance with paragraph (B)(1), the end transition slope of the overlay shall not exceed 30 degrees. A slope of not more than 1:3 is recommended.
(3) For determining the combined length of circumferentially-oriented flaws in the underlying base material or weld, multiple flaws shall be treated as one flaw of length equal to the sum of the lengths of the individual flaws characterized in accordance with IWA-3300.
(4) For circumferentially-oriented flaws in the underlying base material or weld, the flaws shall be assumed to be 100% through the original wall thickness of the item for the entire circumference of the item.
(5) For axial flaws in the underlying base ,material or weld, the flaws shall be assumed to be 100% through the original wall thickness of the item for the entire axial length of the flaw or combined flaws, as applicable for the entire circumference.
(6) For mitigative full structural overlays, the assumed flaw in the underlying base material or weld is to be based on the limiting case of the two below:
(a) 100% through wall for the entire circumference, or (b) 100% through wall for 1.5 in. (38 mm) or the combined width of the weld plus buttering, whichever is greater, in the axial direction for the entire circumference.
(7) The overlay design thickness shall be based on the measured circumference, using only the weld overlay thickness conforming to the deposit analysis requirements of 1(e). The combined wall thickness at the weld overlay, and the effects of any discontinuities (e.g.,
another weld overlay or reinforcement for a branch connection) within a distance of 2.5*/Rt from the toes of the weld overlay, including the flaw size assumptions defined in 2(b)(4),
(5), or (6) above, shall be evaluated and shall meet the requirements of 1WB-3640, 1WC-3640 or 1WD-3640 as applicable.
(8) The effects of any changes in applied loads, as a result of, weld shrinkage from the entire overlay, on other items in the piping system (e.g., support loads and clearances, nozzle loads, changes in system flexibility and weight due to the weld overlay) shall be evaluated.
Existing flaws (not in the weld overlay), previously accepted by analytical evaluation, shall be evaluated in accordance with IWB-3640, IWC-3640, or IWD-3640 as applicable.
NAPS IT] 14-ISI Plan 2-45 Revision 0
Relief Request NDE-006 IDENTIFICATION OF COMPONENTS Specific welds on the residual heat removal (1-RH-E-1A and 1B) and regenerative heat exchangers (1-CH-E-2) as identified below:
1-RH-E-1A and 1B (Drawing 11715-WMKS-RH-E-1A and 1B - See Figure 1 Typical):
Welds Description Category/Item Class 1 Head Circumferential Weld C-A/Cl.20 2 2 Shell Circumferential Weld C-A/C 1. 10 2 3A, 3B, 4A, 4B Reinforcing Plate Welds to C-B/C2.31 2 Nozzle and Vessel 1-CH-E-3 (Drawing 11715-WMKS-CH-E See Figure 2)
Welds Description Category/Item Class 3,7,11 Tubesheet-to-head B-B/B2.60 1*
2,6,10 Tubesheet-to-shell B-B/B2.80 1 1,4,5, 8,9, 12 Circumferential head B-B/B2.51 1 13, 14, 15, 16, 17, 18 Nozzle-to-vessel B-D/B3.150 1 23, 24, 25, 26, 27, 28 Nozzle-to-vessel B-D/B3.150 1 13NIR, 14NIR, 15NIR, Nozzle inside radius B-DIB/3.160 1 16NIR, 17NIR, 18NIR Nozzle inside radius B-D/B3.160 1 23NIR, 24NIR, 25NIR Nozzle inside radius B-D/B3.160 1 26NIR, 27NIR, 28NIR Nozzle inside radius B-D/B 3.160 1 II CODE REQUIREMENTS North Anna Power Station Unit 1 is committed to the 2004 Edition of the ASME Code,Section XI for the fourth inspection interval. This code requires volumetric examinations for items identified in Categories B-B and B-D. It also requires a volumetric examination for items identified in Category C-A. For Category C-B, Item C2.3 1, the 2004 Edition requires a surface examination of the identified weld surface and associated material.
III BASIS FOR RELIEF The regenerative heat exchanger (1-CH-E-3) provides preheat for the normal charging water flowing into the reactor coolant system (RCS). The residual heat NAPS UI 14-ISI Plan 2-46 Revision 0
Relief Request NDE -006 (continued) removal heat exchanger is designed to cool the RCS during plant shut down operations. As part of the approval process for Code Cases N-706 a feasibility study had been performed within the ASME and prepared by Westinghouse Owner's group (WOG) project MUHP 5093, Working Group Inservice Inspection Optimization Action 97-01 (Boiler Code Item BC03-338). "Technical Basis for Revision of Inspection Requirements for Regenerative and Residual Heat Exchangers," August, 2004. This report was used to support the revision of Code Case N-706. Code Case N-706-1 expanded and clarified the requirements of N-706 to include the surface examinations of the saddle welds (Item B2.3 1) and the nozzle inside radius volumetric examinations (Item C3.160). Technical justification for eliminating the surface and volumetric inspection of the residual heat removal and regenerative heat exchangers is provided in this report. The components at North Anna are typical of the heat exchangers described in the Westinghouse report in fabrication, geometric design, inspection requirements and geometric restrictions.
As stated in the Westinghouse report, these components were designed and installed before the imposition of the inservice inspection requirements by Section XI and are not designed for performance of ultrasonic examination. The small diameter of the vessel and nozzles of the regenerative heat exchanger makes obtaining a meaningful ultrasonic examination very time consuming. The physical limitations would substantially diminish the ability to discriminate flaw indications from geometric indications. Referring to the residual heat removal heat exchangers, interference with the lower support and interference with inlet and outlet piping leads to only partial coverage for examination of the head and shell circumferential welds.
Two other factors, flaw* tolerance and risk assessment, presented in the Westinghouse report for these components were considered by the ASME committee. Fracture evaluations were performed for the components using finite element models and fracture calculations. It was concluded that the heat exchangers have a large flaw tolerance and that significant leakage would be expected long before any failure occurred. Fatigue crack growth was determined to be extremely slow even in the most highly stressed region. These heat exchangers do not have a severe duty cycle. Thus detailed inspections are not required to ensure their integrity.
A risk evaluation was performed using the accepted methodology applied for Risk Informed ISI piping inspection programs. The following conclusions were made:
- Safety equipment required to respond to a potential event is unaffected.
- Potential for loss of pressure boundary integrity is negligible.
- No safety analysis margins are changed.
NAPS UI 14-ISI Plan 2-47 Revision 0
Relief Request NDE -006 (continued) 0 Leakage before full break is expected (i.e., there are no core damage consequences associated with leakage).
Thus, elimination of the subject inspections would not be expected to result in a significant increase in risk.
There have been no through-wall leaks on these components or components of similar design as reported in the industry and as discussed in the Westinghouse report. The only related leak in the United States occurred in January 2004 at San Onofre Unit 3 on the letdown line exiting the regenerative heat exchanger. The failure was caused by excessive vibration on the piping line and is not an indication of failure on the actual heat exchanger.
These heat exchangers were designed, constructed, and inspected to ASME Code rules.
Since the Code required preservice exams, visual VT-2 examinations in accordance with the system pressure test program have been performed in accordance with NRC approved relief requests.
Furthermore, these components are located in high radiation fields. The estimated personnel dose to perform the Code required ultrasonic and surface examinations on the regenerative heat exchanger is 13 man-rem, and it is estimated that 4.5 man-rem would be required to meet the examination requirements per interval for the residual heat removal heat exchangers. In view of the significant dose expenditure and limited examination results, performing the code required examinations is not commensurate with the cost.
IV PROPOSED ALTERNATIVE REQUIREMENTS In accordance with the provisions of 10 CFR 50.55a(a)(3)(ii), approval is requested to use the requirements of Code Case N706-1, "Alternative Examination Requirements of Table IWB-2500-1 and IWC-2500-1 for PWR Stainless Steel Residual and Regenerative Heat Exchanges,Section XI, Division 1," as an alternative to the requirements of:
- Table IWB-2500-1 for Categories B-B and B-D pertaining to the regenerative heat exchanger, and
- Table IWC-2500-1 for Categories C-A and C-B pertaining the residual heat removal heat exchangers.
Code Case N-706-1 requires VT-2 examinations to be performed as acceptable alternatives to the above Code required examinations. The VT-2 examination would be performed as part of the system leakage test that is required by Categories B-P and C-H.
NAPS U1 14-ISI Plan 2-48 Revision 0
Relief Request NDE -006 (continued)
Additionally, the Improved Technical Specifications (ITS) establish limits on RCS leakage to one gallon per minute of unidentified leakage and no identified leakage in the pressure boundary. To monitor for leakage, the ITS also require that (a) one containment sump (level or discharge flow) monitor, and (b) one containment atmosphere radioactivity monitor (gaseous or particulate) be operable during modes 1, 2, 3, and 4. In addition, the plant must verify RCS operational leakage is within limits by performance of a RCS inventory balance at a frequency not exceeding 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. The ITS also require that channel check be performed of the required containment atmosphere radiography monitor at a frequency not exceeding 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
Based'on the above, North Anna Power Station believes that compliance with the Code required examinations would result in a hardship due to excessive personnel radiation exposure and the geometric examination difficulties without a compensation increase in quality and safety.
(Similar requests for relief from the above mentioned requirements were submitted and approved by the Nuclear Regulatory Commission for North Anna Power Station Unit 2, second interval, under TAC No. MB07050: Joseph M. Farley plant under TAC No.
MA3449; Surry Power Station unit 1, under TAC No, MB 1998; and Surry Power Station Unit 2, under TAC No. MD2673.)
r NAPS U I14-ISI Plan 2-49 Revision 0
Relief Request NDE -006 (continued)
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Figure 1: 11715/12050-WMKS-RH-E-1A/B NAPS UI 14-1SI Plan 2-50 Revision 0
Relief Request NDE -006 (continued)
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TUTESTEET ENO VIEW SIDE VIEW DETAIL 1 Figure 2: 11715-WMKS-CH-E-3 NAPS U1 14-1SI Plan 2-51 Revision 0
Section 2.4 RELIEF REQUESTS FOR SYSTEM PRESSURE TESTING NAPS Ul 14-ISI Plan 2-52 Revision 0
RELIEF REQUEST SPT-001 I. IDENTIFICATION OF COMPONENTS System: Reactor Coolant (RC)
Components: Partial Penetration Welds @ Bottom of Reactor Vessel ISI Class: 1 II. IMPRACTICAL CODE REQUIREMENTS Category B-P, Item No. B15.10, requires a visual (VT-2) examination of the bottom of the reactor vessel during the system leakage test of IWB-5220.
III. BASIS FOR RELIEF In order to meet the Section XI pressure and temperature requirements for the system leakage test of the reactor vessel, the reactor containment at North Anna Unit 1 is required to be at a sub-atmospheric pressure. Station administrative procedures require that self contained breathing apparatus be worn for containment entries under these conditions. This requirement significantly complicates the visual (VT-2) examination of the bottom of the reactor vessel during testing. Access to the bottom of the reactor vessel requires that the examiner descend several levels by ladder and navigate a small entrance leading to the reactor vessel. In addition to these physical constraints, the examiner must contend with extreme environmental conditions: elevated air temperatures due to reactor coolant at temperatures above 500 degrees F and limited air circulation in the vessel cubicle. In addition, the examiner is limited to the approximate 30 minute capacity of the breathing apparatus for containment entry, the VT-2 examination, and containment exit.
IV. ALTERNATE TESTING The Improved Technical Specifications (ITS) establish limits on RCS leakage to one gallon per minute of unidentified leakage and no identified leakage in the pressure boundary. To monitor for leakage, the ITS also require that a) one containment sump (level or discharge flow) monitor, and b) one containment atmosphere radioactivity monitor (gaseous or particulate) be operable during modes 1, 2, 3, and 4. In addition, the plant must verify RCS operational leakage is within limits by performance of a RCS inventory balance at a frequency not exceeding 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. The ITS also require that channel check be performed of the required containment atmosphere radioactivity monitor at a frequency not exceeding 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. The incore sump room has a level alarm in the control room requiring operator action. These actions would identify any integrity concerns associated with this area. A VT-2 examination will be conducted when containment is at atmospheric conditions each refueling for evidence of boric acid corrosion. These proposed alternatives will ensure that the overall level of plant quality and safety will not be compromised.
NAPS U1 14-ISI Plan 2-53 Revision 0
RELIEF REQUEST SPT-002 I. IDENTIFICATION OF COMPONENTS Approximately 20, small diameter (< 1 inch), Class 1, reactor coolant system (RCS) pressure boundary vent and drain, sample, test, and instrumentation connections.
II. IMPRACTICABLE CODE REQUIREMENTS Section XI Examination Category B-P, Item No. B 15.10 requires system pressure testing and associated VT-2 visual examination of all Class 1 pressure retaining piping and valves. IWB-5222(b) requires that the system pressure test conducted at or near the end of the inspection interval extend to all Class 1 pressure retaining components within the system boundary.
III. ISI BASIS FOR RELIEF REQUEST The subject piping segments are equipped with valves that provide for double isolation of the reactor coolant system (RCS) pressure boundary. These valves are maintained closed during normal operation and the piping outboard of the first isolation valve is, therefore, not normally pressurized. The proposed alternative provides an acceptable level of safety and quality based on the following:
- 1) ASME Section XI Code, paragraph IWA-4540, provides the requirements for pressure testing of piping and components after repairs by welding to the pressure boundary. IWA-4540(b)(6) excludes component connections, piping, and associated valves that are 1 inch nominal pipe size and smaller from the pressure test. Consequently, pressure testing and the associated visual examination of these < 1 inch diameter RCS vent/drain/test/sampling connections once each 10-year interval is unwarranted considering that a repair/replacement weld on the same connections is exempted by the ASME 1 XI Code.
- 2) The non-isolable portion of the RCS vent and drain connections will be pressurized and visually examined as required. Only the normally isolable portion of these small diameter vent and drain connections will not be pressurized.
Piping connections are typically socket-welded, and the welds received a surface examination after installation. The piping and valves are nominally heavy wall (schedule 160 pipe and 1500# valve bodies). The piping and valve/flanges are toward the free end of a cantilever configuration (stub end isolated by either a valve or a flange). There is no brace or support for this portion of the pipe. Consequently, this portion does not experience any thermal loading. This portion of the line is isolated during normal operation and does not experience pressure loading unless there is a leak at the first isolation valve. The valves do not have an extended operator, so the rotational accelerations at the valve do not produce significant stress. Since the lines are designed to the Code, the stresses toward the free end of the cantilever due to other types of loading are only a small fraction of the applicable Code allowable. As a result, this portion of the lines is not subjected to high stress or high intensity cyclic loading.
NAPS U1 14-ISI Plan 2-54 Revision 0
SPT-002 (continued)
The Improved Technical Specifications (ITS) require RCS leakage monitoring (TS 4.4.6.2.1) during normal operation. Should any of the ITS limits be exceeded, then appropriate corrective actions, which may include shutting the plant down, are required to identify the source of the leakage and restore the RCS boundary integrity.
During 1998 North Anna Unit 1 refueling outage similar piping segments were pressurized by removing a flange and connecting a test rig. A majority of these piping segments are located in close proximity to the RCS main loop piping thus requiring personnel entry into high radiation areas within the containment. The dose associated with this testing was 1.5 man-rem.
IV. ALTERNATE PROVISIONS As an alternative to the Code required pressure test of the subject Class 1 reactor coolant system pressure boundary connections the following is proposed:
- 1) The RCS vent, drain, instrumentation, test, and sample connections will be visually examined for leakage and any evidence of past leakage, with the isolation valves in the normally closed position each refueling outage during the ASME XI Class 1 System Leakage Test (IWB-5221 & IWB-5229(a)).
- 2) The RCS vent, drain, instrumentation, test and sample connections will also be visually examined with the isolation valves in the normally closed position during the 10-year ISI pressure test (1WB-5221 & IWB-5222(b)). This examination will be performed with the RCS at nominal operating pressure and at near operating temperature.
In addition, ITS establish limits on RCS leakage to one gallon per minute of unidentified leakage and no identified leakage in the pressure boundary. To monitor for leakage, the ITS also require that a) one containment sump (level or discharge flow) monitor, and b) one containment atmosphere radioactivity monitor (gaseous or particulate) be operable during modes 1, 2, 3, and 4. In addition, the plant must verify RCS operational leakage is within limits by performance of a RCS inventory balance at a frequency not exceeding 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
The ITS also require that a channel check be performed of the required containment atmosphere radioactivity monitor at a frequency not exceeding 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. These proposed alternatives will ensure that the overall level of plant quality and safety will not be compromised.
By a letter dated September 3, 1998 the NRR approved a similar relief request for Edwin I.
Hatch Plant, Units 1 and 2. In addition, similar relief requests were approved for the third inspection interval of North Anna Units 1 and 2.
NAPS UI 14-1ST Plan 2-55 Revision 0
RELIEF REQUEST SPT-003
- 1. IDENTIFICATION OF COMPONENTS System: Residual Heat Removal (RHR)
Components: Class 1 components and piping between:
1-RH-MOV-1700 and 1-RH-MOV-1701 (RHR suction) on drawing 11715-CBM-094A-3, sheet 1 of 2 ISI Class: 1 II. CODE REQUIREMENT IWB-5200, 2004 Edition of ASME Section XI, System Leakage Test IWB-5222, Boundaries, subparagraph (b)
III. BASIS OF REQUEST FOR RELIEF North Anna Unit 1, for its fourth ISI inspection interval utilizing the requirements of ASME Section XI, 2004 Edition. This document requires that a system leakage test be conducted at or near the end of the inspection interval which extends to all Class 1 pressure retaining components within the system boundary.
Normal reactor coolant pressure at 100% rated power is approximately 2235 psig. The piping in question is separated from this reactor coolant pressure by a single closed valve, and as such does not normally see this pressure. Opening valve 1-RH-MOV-1700 is prevented by a pressure interlock, which prevents opening, when pressure in the reactor coolant system is above 418 psig. The interlock protects the low pressure RHR system from being over-pressurized by the higher pressure reactor coolant system. There is no other valve that would allow pressurization of the area from an external source. The system design prevents Code compliance in this area and it is therefore considered a hardship, since a plant modification would be needed, to meet code requirements.
IV. ALTERNATE PROVISIONS The area in question is examined (VT-2) each refueling as part of the normal Class 1 system leakage test (normal valve line-up) for evidence of leakage. Additionally, it is proposed that the area be examined as part of the Class 2 system inservice test pressure boundary using the Class 2 test requirements associated with the adjoining Class 2 piping. This would result in an additional pressure test each period at the Class 2 RHR system nominal operating pressure with the associated visual VT-2 examination.
It is requested per 10 CFR 50.55a(a)(3)(ii) that the tests described above for the fourth inspection interval be alternatively performed. A similar relief request was approved for North Anna Units 1 and 2 for the third inspection interval of each unit.
NAPS U I14-ISI Plan 2-56 Revision 0
Relief Request SPT-004 I. IDENTIFICATION OF COMPONENTS System: Safety Injection (SI)
Components: Class 1 components and piping between:
1-SI-195, 1-SI-197 and 1-SI-199 on drawing 11715-CBM-096B-4, sheet 4 of 4, and 1-SI-MOV-1890C and 1-SI-MOV-1890D on drawing 11715-CBM-096A-4, sheet 2 of 3 [low head safety injection to the reactor coolant cold legs]
1-SI-211, 1-SI-209 and 1-SI-213 on drawing 11715-CBM-096B-4, sheet 4 of 4, and 1-SI-MOV-1890A and 1-SI-MOV-1890B on drawing 11715-CBM-096A-4, sheet 2 of 3 [low head safety injection to the reactor coolant hot legs]
ISI Class: 1 II. CODE REQUIREMENT IWB-5220, 2004 Edition of ASME Section XI, System Leakage Test IWB-5222, Boundaries, subparagraph (b)
III. BASIS OF REQUEST FOR RELIEF North Anna Unit 1, for its fourth ISI inspection interval is utilizing the requirements of ASME Section XI, 2004 Edition. This document requires that a system leakage test be conducted at or near the end of the inspection interval which extends to all Class 1 pressure retaining components within the system boundary.
Normal reactor coolant pressure at 100% rated power is approximately 2235 psig. The piping in question is separated from this reactor coolant pressure by check valves, and as such does not normally see this pressure. The Class 1 boundary for Section XI matches the construction code (B31.7 1969 with the 1970 Addenda) Class 1 (Qi) classification. This earlier classification followed closely the definition of reactor coolant system pressure boundary for the Class 1 boundary. This meant for systems connected to the reactor coolant system, the boundary extended to the outermost containment isolation valve in system piping which penetrates primary reactor containment. As such, more than two valves separate the reactor coolant system from certain parts of the extended Class 1 boundary. External pressurization would be necessary to meet either the ASME Code hydrostatic test requirement or the alternative code case requirement of normal reactor coolant pressure. Since check valves would be part of the test boundary, a pressure differential would be required between the reactor coolant system and the area in question to maintain check valve closure.
Maintaining the differential pressure and ensuring no test fluid intrusion into the reactor coolant system (reactivity control issue) is considered unusually difficult to meet with no compensating increase in quality or level of safety when considering the alternative below.
NAPS UI 14-ISI Plan 2-57 Revision 0
Relief Request SPT-004 (continued)
IV. ALTERNATE PROVISIONS The areas in question are examined (VT-2) each refueling as part of the normal Class 1 system leakage test (normal valve line-up) for evidence of leakage. Additionally, it is proposed that the areas identified above be visually examined (VT-2) based upon a Class 2 system leakage test at or near the end of the interval. The test would be performed at reduced pressure based upon low head safety injection pump pressure and flow to a pressurized or unpressurized reactor coolant system. The pressure, although reduced, would simulate actual system pressure in an accident situation. Additionally, it only involves Class 1 piping beyond the second isolation valve from the reactor coolant system to the first isolation valve outside containment. This piping based upon 10 CFR 50.55a(c)(2)(ii) would now allow a Class 2 classification, if constructed today.
It is requested per 10 CFR 50.55a(a)(3)(ii) that the tests described above for the fourth inspection interval be alternatively performed. A similar relief request was approved for North Anna Units 1 and 2 for the third inspection interval of each unit.
NAPS U I 14-ISI Plan 2-58 Revision 0
RELIEF REQUEST SPT-005 I. IDENTIFICATION OF COMPONENTS System: Reactor Coolant (RCS)
Components: Class 1 components and piping between:
1-RC-R-1 (reactor inner O-ring), 1-RC-32 and I-RC-HCV-1544 on drawing 11715-CBM-093A-3, sheet 1 of 3 ISI Class: 1 II. CODE REQUIREMENT LWB-5200, 2004 Edition of ASME Section XI, System Leakage Test IWB-5222, Boundaries, subparagraph (b)
III. BASIS OF REQUEST FOR RELIEF North Anna Unit 1, for its fourth ISI inspection interval, is utilizing the requirements of ASME Section XI, 2004 Edition. This document requires that a system leakage test be conducted at or near the end of the inspection interval which extends to all Class 1 pressure retaining components within the system boundary.
Normal reactor coolant pressure at 100% rated power is approximately 2235 psig. The components and piping being addressed are associated with the reactor head and flange leakage detection system. They are used to support identification of inner O-ring leakage. An increase in temperature above ambient is an indication of inner O-ring seal leakage. High temperature actuates an alarm. On indication of inner O-ring leakage, the isolation valve in the leak-off line can be closed to put the outer 0-ring into the pressure retention mode, and the inner O-ring leak detection system would be pressurized to reactor coolant pressure up to the closed isolation valve, These lines can only be tested externally, since during normal operation they are separated from RCS pressure by the inner O-ring. Pressurizing the lines externally would put pressure on the inner O-ring in a direction opposite that it was designed for. This could move the inner O-ring from its normal position against the outer channel wall of the reactor vessel flange potentially affecting the O-ring leak tightness and requiring that maintenance be performed.
This is considered an unnecessary hardship without a compensating increase in quality or safety when considering the system design and the monitoring capability of the system.
NAPS U1 14-ISI Plan 2-59 Revision 0
Relief Request SPT-005 (continued)
IV. ALTERNATE PROVISIONS The area in question is examined (VT-2) each refueling as part of the normal Class 1 system leakage test for evidence of leakage. Additionally, leakage past the inner 0-ring must occur to potentially pressurize the components and piping being addressed. This leakage would be identified by an alarm or by RCS inventory balance calculations and addressed by procedures.
The leakage would also be limited by the passive inner 0-ring. Any leakage is normally directed to the primary drain transfer tank unless the system is isolated by operator action.
These activities would be closely monitored by the procedurally controlled operator actions allowing identification of any further compensatory actions required.
It is requested per 10 CFR 50.55a(a)(3)(ii) that the test, monitoring, and operator actions is described above for the fourth inspection interval be alternatively performed. A similar relief request was approved for North Anna Units 1 and 2 for the third inspection interval of each unit.
NAPS U1 14-ISI Plan 2-60 Revision 0
RELIEF REQUEST SPT-006 II. IDENTIFICATION OF COMPONENTS System: Residual Heat Removal (RHR) and Safety Injection (SI)
Components: Class 1 components and piping between:
1-SI-127, 1-SI-125 and 1-SI-126 on drawing 11715-CBM-096B-3 Sht. 1 of 4 1-SI-144, I-SI-142 and I-SI-143 on drawing 11715-CBM-096B-3 Sht. 2 of 4 1-RH-MOV-1720A on drawing 11715-CBM-094A-3 Slit. 2 of 2 1-SI-161, 1-SI-159 and 1-SI-160 on drawing 11715-CBM-096B-3 Sht. 3 of 4 1-RH-MOV-1720B on drawing 11715-CBM-094A-3 Slit. 2 of 2 Note: The Class 1 areas between I-SI-126 and 1-SI-HCV-1850B, 1-SI-143 and 1-SI-HCV-1850D, and 1-SI-160 and 1-SI-HCV-1850F are not part of this relief request.
ISI Class: 1 III. CODE REQUIREMENT IWB-5222, 2004 Edition of ASME Section XI, System Leakage Test IWB-5222, Boundaries, subparagraph (b)
IV. BASIS OF REQUEST FOR RELIEF North Anna Unit 1, for its fourth ISI inspection interval, is utilizing the requirements of ASME Section XI, 2004 Edition. This document requires that a system leakage test be conducted at or near the end of the inspection interval which extends to all Class 1 pressure retaining components within the system boundary.
Normal reactor coolant pressure at 100% rated power is approximately 2235 psig. The piping in question is separated from this reactor coolant pressure by a single check valve, and as such does not normally see this pressure. The area in question is pressurized during normal operation to approximately 660 psig from the passive safety injection accumulators. The accumulator pressure is monitored from the control room throughout the operating cycle. An external pressurization source would be necessary to meet either the ASME Code hydrostatic test requirement or the alternative code case requirement of normal reactor coolant pressure.
Since the check valve would be part of the test boundary; a pressure differential would be required between the reactor coolant system and the area in question to maintain check valve closure. Maintaining the differential pressure and ensuring no test fluid intrusion into the reactor coolant system (reactivity control issue) is considered unusually difficult to meet with no compensating increase in quality or level of safety when considering the proposed alternative.
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Relief Request SPT-006 (continued)
This request for relief proposes to use the alternative provided by Code Case N-73 1, which allows for "systems that are continuouslypressurized during an operating cycle, the pressure associatedwith a statically-pressurizedpassive safety injection system of a pressurized water reactormay be used." The ASME based its technical acceptance of this code case on research performed by Argonne National Laboratory and documented in PVP Vol. 238, Codes and Standards and Applications for High Pressure Equipment, ASME 1992,"Alternative Rules for ASME Section XI 10-year High Pressure Testing of Class 1 and 2 Systems", S.R.
Gosselin. ASME summarized this research as follows:
Detection of leakage from a through-weld flaw is affected by pressure, temperature, and time. However, to detect leakage from such a flaw, it is possible with any pressure at any temperature, but the controlling factor for leakage detection is the time that the component is under pressure, and that pressure and temperature were linear in regards to flow rates observed over time.
It was the objective of the ASME Code to allow the use of this code case in systems that are continuously pressurized for the period of 18-24 months at pressures typically between 280 psig and 660 psig. The components identified in part I of this request satisfy this expectation.
IV. ALTERNATE PROVISIONS As an alternative to the identified requirements of the 2004 Edition of the ASME Section XI, it requested that the requirements of Code Case N-73 1, "Alternative Class 1 System Leakage Test Pressure Requirements", be approved.
NAPS Ul 14-1S1 Plan 2-62 Revision 0
Section 3 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN COMPONENT SUPPORTS FOURTH INSPECTION INTERVAL NAPS Ul 14-ISI Plan 3-1 Revision 0
3.0 INSERVICE INSPECTION PROGRAM FOR COMPONENT SUPPORTS 3.1 Program Description The Inservice Inspection program for Class 1, 2 and 3 component supports meets the requirements of Section XI of the ASME Boiler and Pressure Vessel Code, 2004 Edition.
3.2 Component Support Relief Requests NRC approved component support relief requests are included in this section.
NAPS UI 14-ISI Plan 3-2 Revision 0
RELIEF REQUEST CS-001 IDENTIFICATION OF COMPONENTS Class 1, 2, and 3 Snubbers II. CODE REQUIREMENT The ASME Section XI, 2004 Edition (Section XI), paragraphs 1WF-5200(a) & (b) and 1WF-5300(a) & (b) require the use of the ASME/ANSI OM, Part 4 Code to perform the preservice and inservice examinations and tests of Class 1, 2, and 3 snubbers.
III. BASIS FOR ALTERNATIVE Integration of Section XI and OM (or alternatively ISTD) Codes into an effective, coherent testing program along with associated required changes to the Technical Requirements Manual (TRM) (the snubber requirements were formerly in Technical Specifications) would require a significant amount of administrative activity (e.g.,
administrative procedure changes, reconciliation of code requirement differences, technical procedure changes, etc.)
An alternative approach to establishing these administrative requirements for the inservice examination and functional testing would be to revise the TRM to reference the appropriate paragraphs of the OM or ISTD document. However, many of the requirements being removed from the existing TRM would be very similar, if not identical to the requirements being added. Again, this results in a significant amount of administrative activity, without enhancement in quality and safety. A third approach, which is proposed, provides a means to accomplish the examination and testing required by the Code and regulation with a minimum additional burden.
The current testing and examination requirements of TRM Section 3.7.5 formed the basis of the North Anna Unit 1 inservice examination and testing program for snubbers for the past two ISI intervals (the 2nd and 3rd intervals).
A change made in the third interval permits a "C" value of one to be utilized in the sampling formula of the TRM. The change from C=2 to C=1 was desirable to take advantage of the historically low number of snubber failures experienced at North Anna.
There has not been more than one failure from the required surveillance test group NAPS U1 14-ISI Plan 3-3 Revision 0
Relief Request CS-O01 (continued) during any inspection cycle since 1992. The "C" value established the initial sample size; and when exceeded, the snubber functional test expansion requirements.
To demonstrate that reducing the allowable number of small bore snubber functional test failures from two to one would continue to provide an adequate degree of testing, a comparison of the current TRM formula to the ASME OMa (ISTD) formula [ASME OMa Code - 1995 w/1996 Addenda, Subsection ISTD, "Preservice and Inservice Examination and Testing of Dynamic Restraints (Snubbers) in Light-Water Reactor Power Plants"] has been performed assuming similar failure rates.
The current formula used in TRM Section 3.7.5 to determine the initial number of small bore snubbers to be functionally tested each cycle is as follows: "At lease once per 18 months during shutdown, a representative sample of small bore snubbers, which follows the expression 35[1+c/2] where c = 1 is allowable number of small bore snubbers not meeting the acceptance criteria selected by the operable, shall be functionally tested either in-place or in a bench test.
The equation used in the TRM to define expanded sample size is 35(1 + C/2)(2/(C + 1))2(A-C) where C is the allowable number of function failure (currently equal to one)
A is the total number of functional test failures in the initial sample size.
This equation is used when A exceeds C. Two functional test failures are required before an expanded sampling happens with C = 1. With C = 2 the number of functional test failures required before expanded sampling begins will change to three. The TRM is based on guidance given in NUREG 0452, Standard Technical Specifications for Westinghouse Pressurized Water Reactors, Revision 3 issued Fall 1980. NUREG 0452, Section 4.7.9 states in part "The value C will be arbitrarily chosen by the applicant and incorporated into the expressions for the representative sample and for the resample prior to the issuance of the Technical Specifications." The TRM establishes a "C" to account for a certain number of failures before the testing population has to be expanded.
This builds a failure rate into the group to be tested each outage before scope expansion would be required. The Code does not concern itself with this built in failure rate. It is only concerned with testing an adequate number of snubbers to satisfy safety requirements. ASME OMa Code (subsection ISTD 7.9.2) states that the additional sample size shall be a least one-half the size of the original sample. So the total number of snubbers to be tested, including initial test group, is:
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Relief Request CS-O01 (continued)
N > 0. in + C(O. 1n/2) where N is the total number of snubbers to be tested, n is total number of snubbers in defined test group plan, and C is the number of unacceptable snubbers found through functional test Reviewing the ASME OMa formula it can be seen that the Code does not define a pre-set number of allowable failure as the TRM does. The code only requires that a minimum number of snubbers be tested based on the population [the "0. in" factor] and an additional number of snubbers be tested for scope expansion based on the number found inoperable by testing [the "C(O. ln/2) "factor]. Substituting the number of snubbers for unit 1 this reduces to:
Unit 1 N > 32.6 = 16.3C.
The initial sizes and expanded sample sizes once the allowable number of functional test failures is exceeded is provided for comparison in the table below.
TRM Formula ASME OMa Code Values Functional C=2 C= 1 Unit 1 Test Failures (Initial Value) (Current Value)
A=3 102 158 82 A=2 70 106 66 A = 1 70 53 49 A=0 70 53 33 (Note: The value "A" or functional test failures as defined by the TRM would be equivalent to the value "C" in the ASME Code formula.)
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Relief Request CS-001 (continued)
From the above table it can be seen that the TRM formula with C = 2 or C = 1 will require testing of essentially the same or more snubbers than the ASME OMa (Code.
The comparison in the table demonstrates that the change of value "C" from 2 to 1 in the third period still provides an adequate degree of testing when compared to the ASME OMa Code. Based on the above snubber testing/sample size comparison, North Anna believes that TRM Section 3.7.5 functional testing requirements provides an acceptable level of quality and safety for inservice testing of snubbers. Additionally, the continued implementation of a program based on the TRM requires minimal administrative program change or TRM changes.
However, to satisfy the preservice examination and testing requirements of Section XI, additional testing and examination activity is required beyond the above proposal for inservice snubber testing activities. Therefore, North Anna proposes that the inclusion of the snubber testing requirements contained in the ASME OMa Code paragraph ISTD 4, "Preservice Examination" (excluding 4.3), and ISTD 5, "Preservice Operability Testing", into the current snubber surveillance program provides an alternative with an acceptable level of safety and quality for the preservice testing requirements. The inclusion of these requirements into the snubber surveillance program achieves the preservice testing requirements of the Code with only small administrative impact. No other requirements of ISTD will be implemented as part of this alternative.
Paragraph 4.3 is not proposed as it addresses requirements best suited for the initial heat up and cool down of the plant. It would be a burden to try and impose these requirements on an operating plant such as North Anna Unit 1, which is constructed with a sub-atmospheric, containment. As an alternative to the requirements of paragraph 4.3, North Anna Unit 1 will follow the guidance of 1WF-2220(b) for systems that operate at a temperature greater than 200 degrees F. IWF-2220(b) requires the Owner to perform an additional preservice examination on the affected component supports during or following the subsequent system heat up and cooldown cycle unless determined unnecessary by evaluation. This examination shall be performed during operation or at the next refueling outage. ThisSection XI action has been accepted as providing acceptable quality and safety.
IV. PROPOSED ALTERNATIVE TO CODE REQUIREMENTS North Anna proposes as an alternative to Section XI requirements stated in Section II of this request, a snubber examination and testing program comprised of the following elements:
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Relief Request CS-001 (continued)
- 1) The continued implementation of examination and functional testing requirements of TRM Section 3.7.5, "Snubbers" (C=1) without change.
- 2) The preservice examination and testing requirements of ISTD paragraph 4, "Preservice Examination", excluding paragraph 4.3; and ISTD paragraph 5, "Preservice Operability Testing,"
- 3) As alternative to paragraph ISTD paragraph 4.3, for systems that operate at a temperature greater that 200 degrees F, North Anna Unit 1 will perform an additional preservice examination on the affected snubbers during or following the subsequent system heat up or cool down cycle unless determined unnecessary by evaluation.
The examination may be performed during operation of the plant or at the next refueling outage. This is consistent with the requirements of IWF-2220(b). No other requirements of ISTD will be implemented as pat of this alternative.
- 4) The implementation of the other applicable requirements of the ASME,Section XI Code, 2004 Edition without addenda, unless specific approval has been obtained to do otherwise pursuant to the requirements of 10 CFR 50.55a. This includes using the VT-3 Visual Examination, method described in IWA-2213 for the performance of preservice and inservice examinations.
Dominion submits that the above alternative snubber program will continue to provide an acceptable level of Quality and safety without the administrative changes that add little or no value to quality and safety, or the burden of performing snubber assessments under sub-atmospheric conditions. (Note: Very similar requests for relief were approved for implementation in the third inspection intervals for both units 1 and 2 of North Anna Power Station.)
NAPS IUI 14-1S Plan 3-7 Revision 0
Section 4 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN MISCELLANEOUS DOCUMENTATION FOURTH INSPECTION INTERVAL NAPS U1 14-ISI Plan 4-1 Revision 0
4.0 Miscellaneous Documentation (RESERVED FOR LATER USE)
NAPS U1 14-IST Plan 4-2 Revision 0
Section 5 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN PARTIAL COVERAGE RELIEF REQUESTS FOURTH INSPECTION INTERVAL NAPS U1 14-ISI Plan 5-1 Revision 0
5.0 Partial coverage Relief Requests (RERSERVED FOR LATER USE.)
NAPS UI 14-ISI Plan Revision 0
Section 6 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN CODE CASES FOURTH INSPECTION INTERVAL NAPS U I 14-ISI Plan 6-1 Revision 0
6.0 CODE CASES 6.1 Code Cases Utilized in the Fourth Inservice Inspection Interval Case N-416-3 "Alternative Pressure Test Requirement For Welded Repairs or Installation of Replacement Items by Welding, Class 1, 2, and 3",
Section XI, Division 1.
Case N-432-1 "Repair Welding Using Automatic or Machine Gas Tungsten-Arc Welding (GTAW) Temper Bead Technique",Section XI, Division 1 Case N-460 "Alternative Examination Coverage for Class 1 and Class 2 Welds",
Section XI, Division 1.
Case N-494-3 "Pipe Specific Evaluation Procedures and Acceptance Criteria for Flaws in Class 1 Ferritic Piping that Exceeds the Acceptance Standards of IWB-3514.2 and in Austenitic Piping that Exceeds the acceptance Standards of IWB-3514.3",Section XI, Division 1 Case N-504-3 "Alternative Rules for Repair of Class 1, 2, and 3 Austenitic Stainless Steel Piping,Section XI, Division 1" The following condition is a requirement for use:
The provisions of Section XI, Non-mandatory Appendix Q, "Weld Overlay Repair of Class 1, 2, and 3 Austenitic Stainless Steel Piping Weldments," must also be met. The appendix is available on the ASME Board on Nuclear Codes and Standards web site at:
http://cstools.asme.org/csconnect/CommnitteePages.cfm?Committee=O 10 000000 Case N-513-2 "Evaluation Criteria for Temporary Acceptance of Flaws in Moderate Energy Class 2 or 3 Piping,Section XI, Division 1" Case N-526 Alternative Requirements for Successive Inspections of Class 1 and 2 Vessels",Section XI, Division 1 Case N-532-4 "Alternate Requirements to Repair and Replacement Documentation Requirements and Inservice Summary Report Preparation and Submission as Required by IWA-4000 and IWA-6000",Section XI, Division 1.
Case N-552 "Alternative Methods - Qualification for Nozzle Inside Radius Section from the Outside Surface,Section XI, Division 1" The following conditions are requirements for use:
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To achieve consistency with the 10 CFR 50.55a rule change published September 22, 1999 (64 FR 51370), incorporating Appendix VIII, "Performance Demonstration for Ultrasonic Examination Systems," to Section XI, add the following to the specimen requirements:
"At least 50 percent of the flaws in the demonstration test set must be cracks and the maximum misorientation must be demonstrated with cracks. Flaws in nozzles with bore diameters equal to or less than 4 inches may be notches."
Add to detection criteria, "The number of false calls must not exceed three."
Case N-566-2 "Corrective Action for Leakage Identified at Bolted Connections,Section XI, Division 1" Case N-586 -1 "Alternative Additional Examination Requirements for Classes 1, 2, and 3 Piping, components, and Supports" Case N-597-2 "Requirements for Analytical Evaluation of Pipe Wall Thinning,Section XI, Division 1.
This code case must be used with the following conditions:
1 Code Case must be supplemented by the provisions of EPRI Nuclear Safety Analysis Center Report 202L-R2, April 1999, "Recommendations for an Effective Flow Accelerated Corrosion Program," for developing the inspection requirements, the method of predicting the rate of wall thickness. As used in NSAC-202L-R2, the terms "should" is to be applied as "shall" (i.e., a requirement).
2 Components affected by the flow-accelerated corrosion to which this Code Case are applied must be repaired or replaced in accordance with the construction code of record and Owner's requirements or a later NRC approved edition of Section III 'Rules for Construction of Nuclear Power Plant Components" of the ASME Code prior to the value of tp reaching the allowable minimum wall thickness, tmin, as specified in -3622. 1(a)(1) of this Code Case.
Alternatively, use of the Code Case is subject to NRC review and approval per 10 CFR 50.55(a)(3).
3 For Class 1 piping not meeting the criteria of -3221, the use of evaluation methods and criteria is subject to NRC review and approval per 10 CFR 50.55(a)(3).
4 For those components that do not require immediate repair or replacement, the rate of wall thickness loss is to be used to determine a suitable inspection frequency so that repair or replacement occurs prior to reaching allowable minimum wall thickness, tmin.
5 For corrosion phenomenon other than flow accelerated corrosion, use of the Code Case is subject to NRC review and NAPS U1 14-ISI Plan 6-3 Revision 0
approval. Inspection plans and wall thinning rates may be difficult to justify for certain degradation mechanisms such as MIC and pitting.
Case N-613-1 "Ultrasonic Examination of Penetration Nozzles in Vessels, Examination Category B-D, Item Nos. B3.10 and B3.90, Reactor Nozzle-to-Vessel Welds, Figs. IWB-2500-7(a), (b), and (c),Section XI, Division 1" Case N-624 "Successive Inspections,Section XI, Division 1" Case N-638-1 "Similar and Dissimilar Metal Welding Using Ambient Temperature Machine GTAW Temper Bead Technique,Section XI, Division 1" The following condition is a requirement for use:
UT volumetric examinations shall be performed with personnel and procedures qualified for the repaired volume and qualified by demonstration using representative samples which contain construction type flaws. The acceptance criteria of NB-5330 in the 1998 Edition through 2000 Addenda of Section III apply to all flaws identified within the repaired volume.
Case N-641 Alternative Pressure-Temperature Relationship and Low Temperature Overpressure Protection System Requirements Case N-651 "Ferritic and Dissimilar Metal Welding Using SMAW Temper Bead Technique Without Removing the Weld Bead Crown for the First Layer,Section XI, Division 1" Case N-658 "Qualification Requirements for Ultrasonic Examination of Wrought Austenitic Piping Welds,Section XI, Division 1" Case N-661 "Alternative Requirements for Wall Thickness Restoration of Classes 2 and 3 Carbon Steel Piping for Raw Water Service,Section XI, Division 1" The following conditions are requirements for use:
- 1) If the root cause of the degradation has not been determined, the repair is only acceptable for one cycle.
- 2) Weld overlay repair of an area can only be performed once in the same location.
- 3) When through-wall repairs are made by welding on surfaces that are wet or exposed to water, the weld overlay repair is only acceptable until the next refueling outage.
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Case N-663 "Alternative Requirements for Class 1 and 2 Surface Examinations" Case N-683 "Method for Determining Maximum Allowable False Call When Performing Single-Sided Access Performance Demonstration in Accordance with Appendix VIII, Supplements 4 and 6",Section XI, Division 1 Case N-686 "Alternative Requirements for Visual Examinations, VT-1, YT-2, and VT-3",Section XI, Division 1.
Case N-696 "Qualification Requirements for Appendix VIII Piping Examinations Conducted from the Inside Surface",Section XI, Division 1 Case N-706 "Alternative Examination Requirements of Table IWB-2500-1 and Table IWC-2500-1 for PWR Stainless Steel Residual and Regenerative Heat Exchangers",Section XI, Division 1 Case N-706-1 * "Alternative Examination Requirements of Table IWB-2500-1 and Table IWC-2500-1 for PWR Stainless Steel Residual and Regenerative Heat Exchangers",Section XI, Division 1(See RR NDE-006. *If NDE-006 is approved allowing the use of CC N-706-1, then CC N-706 will be dropped from this section>)
Code Case N-73 1* "Alternative Class 1 System Leakage Test Pressure Requirements",Section XI, Division 1 (See RR SPT-006)
Code Cases identified with an asterisk (*) are not approved by Regulatory Guide 1.147, Revision 15, for use. The NRC must grant relief to implement these Code Cases.
NAPS U I 14-ISI Plan 6-5 Revision 0
Section 7 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN Risk Based Inspection FOURTH INSPECTION INTERVAL NAPS UI 14-ISI Plan 7-1 Revision 0
7.0 Risk Based Inspection (RESERVED FOR LATER USE.)
NAPS Ul 14-IST Plan 7-2 Revisi]on 0
Section 8 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN PLAN CHANGES FOURTH INSEPCTION INTERVAL NAPS UI 14-ISI Plan 8-1 Revision 0
8.0 Plan Changes (RESERVED FOR LATER USE)
NAPS U1 14-ISI Plan 8-2 Revision 0
Section 9 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
NORTH ANNA POWER STATION UNIT 1 INSERVICE INSPECTION PLAN CLASSIFICATION AND IDENTIFICATION OF COMPONENTS FOURTH INSEPCTION INTERVAL NAPS Ul 14-ISI Plan 9-1 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-0103AT /1 1/2-CH-398 / FLANGE A FLANGE BOLTING 11715-WMKS-0103AT / 2-CH-96 I HSS-807 STD-LSS-MECH 11715-WMKS-0103AT / 2-CH-96 / HSS-808 STD-ASS-MECH 11715-WMKS-0103AT I 2-CH-96 R-10 FAB-VC LC-MECH 11715-WMKS-0103AT / 2-CH-96 R-11I FAB-VC LC-MECH 1 1715-WMKS-0103AT / 2-CH-96 / R-14 FAB-VC-MECH 11715-WMKS-0103AT I 2-CH-96 / R-15 FAB-VC LC-MECH 11715-WMKS-0103AT / 2-CH-96 / R-24 FAB-VC-MECH 11715-WMKS-0103AT I 2-CH-96 / R-37 FAB-EW-MECH 1 1715-WMKS-0103AT I 2-CH-96 / R-38 FAB-VC EW-WELD 11715-WMKS-0103AT / 2-CH-96 I R-5 FAB-VC LC AC-WELD 11715-WMKS-0103AT I 2-CH-96 R-6 R FAB-VC-MECH 11715-WMKS-0103AT / 2-CH-96 I R-7 FAB-VC LC-MECH 11715-WMKS-0103AT / 2-CH-96 / R-9 FAB-VC-MECH 11715-WMKS-0103AU /1 1/2-CH-397 / FLANGE A FLANGE BOLTING 11715-WMKS-0103AU / 2-CH-94 I R-10 FAB-VC LC-MECH 11715-WM KS-0103AU I 2-CH-94 I R-12 FAB-VC LC-MECH 11715-WM KS-0103AU / 2-CH-94 /R- 18 FAB-VC LC-MECH 11715-WMKS-0103AU I 2-CH-94 R-5 R FAB-VC LC-MECH 11715-WMKS-0103AV /1 1/2-CH-396 / FLANGE A FLANGE BOLTING 11715-WMKS-0103AV / 2-CH-92 / HSS-814 STD-LSS-MECH 11715-WMKS-0103AV / 2-CH-92 / R-14 FAB-VC NS-MECH 11715-WMKS-0103AV I 2-CH-92 I R-19 FAB-VC-MECH 11715-WMKS-0103AV / 2-CH-92 / R-3 FAB-VC-MECH 11715-WMKS-0103AV I 2-CH-92 I R-5 FAB-VC LC-MECH 11715-WM KS-0103BC I 2-CH-8 I A-36 SUPPORT 11715-WMKS-0103BC / 2-CH-8 / R-41A SUPPORT 11715-WMKS-0103BD / 2-CH-9 / A-5 SUPPORT 11715-WMKS-0103BD / 2-CH-9 / R-6 SUPPORT 1 1715-WMKS-0103BD I 2-CH-9 / R-8 SUPPORT 1 1715-WMKS-0103BE / 2-CH-l10 R-2 SUPPORT 1 1715-WMKS-0103BE / 2-CH-10 R-5 R SUPPORT NAPS U I 14-ISI Plan 9-2 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-0103BE /2-CH-10 / R-6 SUPPORT 11715-WMKS-0103BF / 2-CH-8 I HSS-803A SUPPORT 11715-WMKS-0103BF / 2-CH-8 / R-1 SUPPORT 11715-WMKS-0103BF / 2-CH-8 / R-20 SUPPORT 11715-WMKS-0103BF / 2-CH-8 / R-31 SUPPORT 11715-WMKS-0103BF / 2-CH-8 / R-40 SUPPORT 11715-WMKS-0103BF / 2-CH-8 / R-5 SUPPORT 11715-WMKS-0103CD / 2-CH-A-02 / R-17 SUPPORT 11715-WMKS-0103CD / 2-CH-A-02 / R-9 SUPPORT 11715-WMKS-0103CD /3-CH-A-01i R-1 SUPPORT 11715-WMKS-01 11 BA / 2-CH-68 / HSS-859 SUPPORT 11715-WMKS-01 1IBA / 2-CH-68 / R-2 SUPPORT 11715-WMKS-0111 BA / 2-CH-68 I R-3 SUPPORT 11715-WMKS-01 11BA / 2-CH-68 / R-5 SUPPORT 1 11 715-WMKS-0 111 BA / 2-CH-68 / R-6 SUPPORT 1 11 715-WMKS-01 11 BA / 2-CH-68'/ R-8 SUPPORT 1 11 715-WMKS-01 11 BA / 2-CH-68 / SH-9 SUPPORT 1 11715-WMKS-0111BB /3-CH-1 /19 VALVE-ELBOW 1 11715-WMKS-0111 BB / 3-CH- / R-2 LC 1 11715-WMKS-01 11BB / 3-CH-1 / R-3 VC 1 11715-WMKS-01 11BB / 3-CH-1 / R-7 LC 1 11715-WMKS-01 11BB / 3-CH-1 / R-8 LC 1 11715-WMKS-CH-E-3 / 1-CH-E-3 / 10 SHELL-TO-TUBSHT WELD 1 11715-WMKS-CH-E-3 / 1-CH-E-3 / 11 TUBSHT-TO-SHELL WELD 1 11715-WMKS-CH-E-3 / 1-CH-E-3 / 12 SHELL-TO-HEAD WELD 1 11715-WMKS-CH-E-3 / 1-CH-E-3 / 9 HEAD-TO-SHELL WELD 1 11715-WMKS-CH-E-3 / 1-CH-E-3 / SUPT-BRACKET SUPPORT 1 11715-WMKS-0103AF /6-RC-18/ 1 ELBOW-WELDOLET 1 11715-WMKS-0103AF / 6-RC-18 / 2 VALVE-ELBOW 1 11715-WMKS-0103AJ /6-RC-16/ 15 ELBOW-VALVE 1 11715-WMKS-0103AJ /6-RC-16/ 16 ELBOW-WELDOLET 1 11 715-WM KS-0103AQ / 2-RC-46 / FE- 1481 FLOW ELEMENT BOLTING NAPS IJ1 14-1ST Plan 9-1 Revisinn C)
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 1 11715-WMKS-OO3AR / 2-RC-45 FE-1480 FLOW ELEMENT BOLTING 1
11715-WMKS-0103AS / 2-RC-44 / FE-1482 FLOW ELEMENT BOLTING 11715-WM KS-0103BB-1 I 2-RC-216 I HSS-839 STD-SKS-WELD 11715-WMKS-O103BB-1 / 2-RC-216 I HSS-840 STD-SKS-MECH 11715-WMKS-OO3BB-1 I 2-RC-53 / HSS-837 STD-LSS-MECH 11715-WMKS-O103BB-1 / 2-RC-53 I HSS-838 STD-LSS-MECH 11715-WM KS-0103BB- 1 I 2-RC-53 / SH-43 STD-SH-MECH 11715-WM KS-O 103BB-2 I 2-RC-218 / HSS-833 SUPPORT 11715-WMKS-O103BB-2 / 2-RC-218 / R-1 SUPPORT 11715-WMKS-O103BB-2 / 2-RC-57 / HSS-832 SUPPORT 11715-WMKS-O103BB-2 / 3-RC-217 / HSS-835 SUPPORT 11715-WMKS-O103BB-3 / 2-RC-220 / HSS-827 SUPPORT 11715-WMKS-O103BB-3 I 3-RC-219 / HSS-830 SUPPORT 11715-WMKS-O103BE / 2-RC-200 / R-1 SUPPORT 11715-WMKS-O103BH I 2-RC-53 I A-12 SUPPORT 11 715-WMKS-O103BH / 2-RC-53 / HSS-821 SUPPORT 11715-WMKS-O103BH / 2-RC-53 I R-18 SUPPORT 11715-WMKS-0103BH / 2-RC-53 / R-20 SUPPORT 11715-WMKS-O103BH I 2-RC-53 / R-21 SUPPORT 11715-WM KS-O 103BH / 2-RC-53 / R-23 SUPPORT 11715-WM KS-O 103BH / 2-RC-53 I R-24 SUPPORT 11715-WMKS-O103BH / 2-RC-53 / R-31 SUPPORT 1 1715-WMKS-O103BH / 2-RC-53 / R-32 SUPPORT 11715-WMKS-O103BH / 2-RC-53 / R-33 SUPPORT 11715-WMKS-O103BH / 2-RC-53 / R-36 SUPPORT 11715-WM KS-0103BH / 2-RC-53 I R-37 SUPPORT 11715-WMKS-O103BH / 2-RC-53 I R-39 SUPPORT 11715-WMKS-O103BH I 2-RC-53 / R-6 SUPPORT 11715-WMKS-0103N I 6-RC-17 /20 VALVE-PIPE 1!715-WMKS-0103N I 6-RC-17 /21 PIPE-COUPLING 11715-WMKS-0103N I 6-RC-17 / SW-22 PIPE-ELBOW 11715-WMKS-0103N / 6-RC-17 / SW-23 ELBOW-PIPE NAPS Ul 14-ISI Plan 9-4 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 1 11715-WMKS-0103W /6-RC-20 /41 VALVE-ELBOW 1 11715-WMKS-0103W / 6-RC-20 /42 PIPE-COUPLING 1 11715-WMKS-0103W I 6-RC-20 I SW-43 ELBOW-PIPE 1 11715-WMKS-0103Y / 6-RC-19/ 13 VALVE-ELBOW 1 11715-WMKS-0103Y / 6-RC-19/ 14 ELBOW-COUPLING 1 11715-WMKS-0109A /8-RC-11 / SW-1 ELBOW-PIPE 1 11715-WMKS-0109B / 8-RC-12 /'SW-1 ELBOW-PIPE 1 11715-WMKS-0109C 88-RC-13 / SW-1 ELBOW-PIPE 1 11715-WMKS-0109D/ 14-RC-10 /39 PIPE-PIPE 1 11715-WMKS-0109D/ 14-RC-10 /45H INTEGRAL ATTACHMENT WELD 1 11715-WMKS-0109D I 14-RC-10 / SW-48 PIPE-ELBOW 1 11715-WMKS-0109D I 14-RC-10 I SW-51 NOZZLE-SAFE END 1 11715-WMKS-0109E-1 /27 1/2-RC-3 / 10 PIPE-VALVE 1 11715-WMKS-0109E-1 / 27 1/2-RC-3 / 12 NOZZLE-SAFE END 1 11715-WMKS-0109E-1 /29-RC-1 /1 NOZZLE-SAFE END 1 11715-WMKS-0109E-1 / 31-RC-2 /6 SG NOZZLE-SAFE END 1 11715-WMKS-0109E-2 / 27 1/2-RC-3 / SW-41 WELDOLET-PIPE 1 11715-WMKS-0109F- / 27 1/2-RC-6 / 24 ELBOW-NOZZLE 1 11715-WMKS-0109F-1 / 27 1/2-RC-6 / 38 PUMP-PIPE 1 11715-WMKS-0109F-1 / 29-RC-4 / 13 NOZZLE-PIPE 1 11715-WMKS-0109G-I / 27 1/2-RC-9 / 34 PIPE-VALVE 1 11715-WMKS-0109G-I / 27 1/2-RC-9 / 36 PIPE-NOZZLE 1 11715-WMKS-0109G-1 / 29-RC-7 / 25 NOZZLE-PIPE 1 11715-WMKS-0109G-1 / 31-RC-8 / 30 NOZ - SAFE END 1 11715-WM KS-0109G-2 / 27 1/2-RC-9 / SW-43 WELDOLET-PIPE END 1 11715-WMKS-0 11OA / 3-RC-206 / HSS-i117 SUPPORT 1 11715-WMKS-0 11A / 3-RC-35 / HSS-1 16A SUPPORT 1 11715-WMKS-0 11A / 3-RC-35 / HSS-1 16B SUPPORT S11715-WMKS-0 110A / 3-RC-35 / M OV-1535 BOLTING VALVE BOLTING 1 11715-WMKS-011 OA /3-RC-35 / PCV-1456 BOLTING VALVE BOLTING I 11715-WMKS-0110A/3-RC-61 /3H INTEGRAL AT[ACHMENT WELD 1 11715-WMKS-01 1iA / 3-RC-61 / HSS-1 15A SUPPORT NAPS UI I4-1S1 Plan 9-5 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 1 11715-WMKS-011 GA / 3-RC-61 / HSS-1 15B SUPPORT 1 11715-WMKS-0110A / 3-RC-61 / MOV-1536 BOLTING VALVE BOLTING 11715-WMKS-01 10A / 3-RC-61 I PCV-1455 BOLTING VALVE BOLTING 1 11715-WMKS-01 IGA / 3-RC-61 / R-38 SUPPORT 1 11715-WMKS-011OA /4-RC-34/ 1H INTERGAL ATTACHMENT WELD 1 11715-WMKS-0110A /4-RC-34/ 30 PIPE-PIPE 1 11715-WMKS-01 10A / 4-RC-34 I HSS-1 19A SUPPORT 1 1 1715-WMKS-011GA / 4-RC-34 / HSS-119B SUPPORT 1 11715-WMKS-011GA / 4-RC-34/ HSS-120 SUPPORT 1 1 1715-WMKS-0110A / 4-RC-34 / SH-39 SUPPORT 1 1 1715-WMKS-011GA / 4-RC-34 / SW-64 NOZZLE-SAFE END 1 1 1715-WMKS-011iA / 6-RC-37 /25 PIPE-ELBOW 1 1 1715-WMKS-011GA / 6-RC-37 / FB-1551C BOLTING FLANGE BOLTING 1 11715-WMKS-0110A / 6-RC-37 / SV-1551C BOLTING VALVE BONNET BOLTING 1 11715-WMKS-011GA / 6-RC-37 / SV-1551C-BODY VALVE BODY 1 1 1715-WMKS-011GA / 6-RC-37 / SW-38 NOZZLE-SAFE END 1 1 1715-WMKS-11iGA / 6-RC-38 /21 PIPE-ELBOW 1 1 1715-WMKS-G11iA / 6-RC-38 / FB-1551B BOLTING FLANGE BOLTING 1 1 1715-WMKS-011GA / 6-RC-38 / SV-1551B BOLTING VALVE BONNET BOLTING 1 1 1715-WMKS-011GA / 6-RC-38 / SV-1551 B-BODY VALVE BODY
.1 11715-WMKS-0110A / 6-RC-38 / SW-30 NOZZLE-SAFE END 1 11715-WMKS-0110A/6-RC-39/ 17 PIPE-ELBOW 1 11715-WMKS-0110A / 6-RC-39 / A-47 SUPPORT 1 11715-WMKS-01 1A / 6-RC-39 I FB-1551A BOLTING FLANGE BOLTING 1 11715-WMKS-01 10A / 6-RC-39 / SV-1551A BOLTING VALVE BONNET BOLTING 1 1 1715-WMKS-011GA / 6-RC-39 / SV-1551A-BODY VALVE BODY 1 11715-WMKS-0110A / 6-RC-39 / SW-31 NOZZLE-SAFE END 1 1 1715-WMKS-O11GB-1 / 1 1/2-RC-105 / HSS-892 SUPPORT 1 11715-WMKS-011GB- / 1 1/2-RC-105 / SH-3 SUPPORT 1 11715-WMKS-0110B-1 /4-RC-15 / 11 PIPE-PIPE 1 11715-WMKS-011GB-1 / 4-RC-15 / 57H INTEGRAL ATTACHMENT WELD 1 11715-WMKS-O11GB-1 / 4-RC-15 / HSS-107 SUPPORT NAPS U1 14-ISI Plan 9-6 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-011GB-I /4-RC-15 HSS-109 SUPPORT 11715-WMKS-01101B-i 1 4-RC-15 R-20 SUPPORT I I715-WMKS-O110GB- / 4-RC-15 R-22 SUPPORT 1 1715-WMKS-0110GB-1 /4-RC-15 R-30 SUPPORT 11715-WMKS-0110B- / 4-RC-15 SH-17 SUPPORT 11715-WMKS-0110GB- / 4-RC-15 SH-18 SUPPORT 11715-WMKS-0110GB- / 4-RC-15 /SH-21 SUPPORT 11715-WMKS-0110GB-i / 4-RC-15 I SW-71 NOZZLE-SAFE END 11 715-WMKS-0 110B-2 /4-RC-14 I 59H INTERGAL ATTACHMENT WELD 11715-WMKS-011GB-2 / 4-RC-l14 A-8 SUPPORT 11715-WMKS-01 I1B-2 I 4-RC-14 / R-52 SUPPORT 11715-WMKS-0110B-2 / 4-RC-14 / SH-14 SUPPORT 11715-WMKS-01 13A-4 / 12-RC-22 / SW-Il ELBOW-PIPE 11715-WMKS-01 13C-3 / 12-RC-24 / SW-31 ELBOW-PIPE 11715-WMKS-RC-1C.2 I 29-RC-7 / N-SE29 IN. NOZ - SAFE END 11715-WMKS-RC-E-1A.1 I 1-RC-E-IA I A TUBSHT-TO-HEAD WELD 11715-WMKS-RC-E-1A.1 1-RC-E-1A CL-MANWAY SG CL MANWAY BOLTS 11 715-WMKS-RC-E-1A.1 I 1-RC-E-1AI FRAME SUPPORT 11715-WMKS-RC-E-1A.1 I1-RC-E-1A HL-MANWAY SG HL MANWAY BOLTS 11 715-WMKS-RC-E-1A.1 1-RC-E-1A RRING SUPPORT 11 715-WMKS-RC-E-1A.i1 1-RC-E-1A TUBING H/L STM GEN TUBES 1 11715-WMKS-RC-E-1A.2 I -RC-E-1A /1 INIRA SG PRIMARY SIDE - NIR 1 11715-WMKS-RC-E-1A.2 1-RC-E-1A 12NIRA SG PRIMARY SIDE - NIR 1 11715-WMKS-RC-E-1A.2 1-RC-E-1A HSS-001A SUPPORT 1 11715-WMKS-RC-E-1A.2 I -RC-E-1A HSS-003A SUPPORT 1 11715-WMKS-RC-E-1A.2 I -RC-E-1 A HSS-010A SUPPORT 1 11 715-WMKS-RC-E-1 A.2 I1-RC-E-1A HSS-01 1A SUPPORT I I 715-WMKS-RC-E-1A.2 1-RC-E-1A R-002A SUPPORT S1 1715-WMKS-RC-E-IA,2 1-RC-E-IAA R-004A SUPPORT 1 11715-WMKS-RC-E-1A.2 29-RC-1 / N-SE29 IN. SG NOZZLE-SAFE END 1 11715-WMKS-RC-E-1B.1 1-RC-E-IBB CL-MANWAY SG CL MANWAY BOLTS 1 11715-WMKS-RC-E-1B.1 1-RC-E-1B / HL-MANWAY SG HL MANWAY BOLTS NAPS U I14-ISI Plan 9-7 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 1 11715-WMKS-RC-E-1B.1 / 1-RC-E-1B / TUBING H/L SG TUBES 11715-WMKS-RC-E-1B.2 / 1-RC-E-1B / 11 NIRA SG NIR 11715-WMKS-RC-E-1B.2 / 1-RC-E-1B / 12NIRA SG NIR 11715-WMKS-RC-E-1B.2 / 29-RC-4 / N-SE29 IN; NOZ - SAFE END 11715-WMKS-RC-E-1B.2 / 31-RC-5 / N-SE31 IN. NOZ - SAFE END 11715-WMKS-RC-E-1C.1 1-RC-E-1C / CL-MANWAY SG CL MANWAY BOLTS 11715-WMKS-RC-E-1C.1 1-RC-E-1C / HL-MANWAY SG HL MANWAY BOLTS 11715-WMKS-RC-E-1C.1 1-RC-E-1C /TUBING H/L STM GEN TUBES 11715-WMKS-RC-E-1C.2 1-RC-E-1C / I1NIRA SG NIR 11715-WMKS-RC-E-1C.2 I 1-RC-E-1C / 12NIRA SG NIR 11715-WMKS-RC-E-2 I 1-RC-E-2 / 09NIR PZR NIR 11715-WMKS-RC-E-2 / 1-RC-E-2 /1 LONG SHELL WELD 11715-WMKS-RC-E-2 / 1-RC-E-2 /10 NOZZLE-TO-VESSEL 11715-WMKS-RC-E-2 / 1-RC-E-2 / 10NIR PZR NIR 11715-WMKS-RC-E-2 I 1-RC-E-2 / 11 NOZZLE-TO-VESSEL 11715-WMKS-RC-E-2 I 1-RC-E-2 / 11 NIR PZR NIR 11715-WMKS-RC-E-2 I 1-RC-E-2 /12 NOZZLE-TO-VESSEL 11715-WMKS-RC-E-2 I 1-RC-E-2 I 12NIR PZR NIR 11715-WMKS-RC-E-2 I 1-RC-E-2 /13 NOZZLE-TO-VESSEL 11715-WMKS-RC-E-2 I 1-RC-E-2 / 13NIR PZR NIR 11715-WMKS-RC-E-2 1-RC-E-2 / 14 NOZZLE-TO-VESSEL 11715-WMKS-RC-E-2 1-RC-E-2 / 14NIR PZR NIR 11715-WMKS-RC-E-2 I 1-RC-E-2 /3 LONG SHELL WELD 11715-WMKS-RC-E-2 1-RC-E-2 / 4 CIRC. SHELL WELD 11715-WMKS-RC-E-2 1-RC-E-2 /7 CIRC, SHELL WELD 11715-WMKS-RC-E-2 /1-RC-E-2 / 8 INTERGAL A1TACHMENT WELD 11715-WMKS-RC-E-2 1-RC-E-2 / 9 NOZZLE-TO-VESSEL 11715-WMKS-RC-E-2 /1-RC-E-2 / HEAT ELEM PZR HTR PEN WELDS 1 11715-WMKS-RC-E-2 1-RC-E-2 / MANWAY PZR MANWAY BOLTS 1
11715-WMKS-RC-E-2 1-RC-E-2 / RING SUPPORT 1
11715-WMKS-RC-E-2 1-RC-E-2 / SAMPLE NOZZLES SAMPLE NOZZLES NAPS UI 14-ISI Plan 9-8 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-RC-E-2 / 1-RC-E-2 / WS-1 INTERGAL ATTACHMENT WELD 11715-WMKS-RC-E-2 /I 1-RC-E-2 / WS-2 INTERGAL ATTACHMENT WELD 11715-WMKS-RC-E-2 I l-RC-E-2 I WS-3 INTEGRAL ATTACHMENT WELD 11715-WMKS-RC-E-2 I 1-RC-E-2 I WS-4 INTEGRAL ATTACHMENT WELD 11715-WMKS-RC-MOV1590 I 1-RC-MOV-1590 I BOLTING NUT-1-24 11715-WMKS-RC-MOV1590 I 1-RC-MOV-1590 / BOLTING STUD-1-24 1 11715-WMKS-RC-MOV1591 I 1-RC-MOV-1591 BOLTING NUT-1-24 11715-WMKS-RC-MOV1591 I 1-RC-MOV-1591 BOLTING STUD-1 -24 11715-WMKS-RC-MOV1592 / 1-RC-MOV-1592 BOLTING NUT-1-24 11715-WMKS-RC-MOV1592 I 1-RC-MOV-1592 BOLTING STUD-1-24 11715-WMKS-RC-MOV1593 I 1-RC-MOV-1593 BOLTING NUT-1-24 11715-WMKS-RC-MOV1593 / 1-RC-MOV-1593 BOLTING STUD-1-24 11715-WMKS-RC-MOV1594 I 1-RC-MOV-1594 BOLTING NUT-1-24 11715-WM KS-RC-MOV 1595 I1 -RC-MOV-1595 BOLTING NUT-1-24 11 715-WMKS-RC-P-1A.1 I 1-RC-P-1A FRAME SUPPORT 11 715-WMKS-RC-P-1A.2 / 1-RC-P-lAA BO1 RCP MAIN FLANGE BOLT 11 715-WMKS-RC-P-1A.2 / 1-RC-P-lAA B02 RCP MAIN FLANGE BOLT 11 715-WMKS-RC-P-1A.2 I 1-RC-P-1A B03 RCP MAIN FLANGE BOLT S11715-WMKS-RC-P-1A.2 1-RC-P-1A B04 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 1-RC-P-1 A B05 RCP MAIN FLANGE BOLT 11 715-WMKS-RC-P-1A.2 1-RC-P-lAA B06 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 1-RC-P-lAA B07 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 1-RC-P-1AI B08 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 1-RC-P-1AI B09 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 1-RC-P-1A B10 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 1-RC-P-1A B 11 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 1-RC-P-1A B12 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 1-RC-P-1A B13 RCP MAIN FLANGE BOLT 1 1715-WMKS-RC-P-1A.2 1-RC-P-1A B14 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 1-RC-P-lAA B15 RCP MAIN FLANGE BOLT NAPS U I 14-ISI Plan 9-9 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-RC-P-1A,2 / 1-RC-P-1 A/ B16 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 / 1-RC-P-1A / B17 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 / 1-RC-P-1A / B18 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2/ 1-R-P-1A!/ B19 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 / 1-R-P-1A!/ B20 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 I 1-RC-P-1A / B21 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 /I 1-RC-P-1A / B22 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 / 1-RC-P-1A / B23 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 / 1-RC-P-1A / B24 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1A.2 / 1-RC-P-1A / LSHB SEAL HOUSE BOLTS 11715-WMKS-RC-P-1B.2 / 1-RC-P-lBI BO1 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1 B.2 / 1-RC-P-1B /B02 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-'RC-P-1B /B03 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-RC-P-lB /B04 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-RC-P-lBB B05 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-RC-P-1B /B06 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-RC-P-lB /B07 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-RC-P-1B / B08 RCP MAIN FLANGE BOLT 1 1715-WMKS-RC-P-1 B.2 1-RC-P-lB / B09 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B8.2 1-RC-P-1B / B10 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-RC-P-1B /8B1 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 /1-RC-P-B/'B 12 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 /1-RC-P-lB / 813 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 /1-RC-P-lB / 814 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-RC-P-lB / 815 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 /1-RC-P-lB / 816 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-RC-P-1B / 817 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1 B.2 / -RC-P-lB / 818 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-RC-P-lB / 819 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 1-RC-P-lB / B20 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 /1-RC-P-lB / B21 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 /1-RC-P-lB / B22 RCP MAIN FLANGE BOLT NAPS Ul 14-ISI Plan 9-10 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-RC-P-1B.2 / I-RC-P-lB / B23 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 / 1-RC-P-1B / B24 RCP MAIN FLANGE BOLT 11715-WMKS-RC-P-1B.2 / i-RC-P-1B / LSHB SEAL HOUSE BOLTS 1 1715-WMKS-RC-P-1 C.1 /1-RC-P-1C / 1 RC PUMP CASING WELD 11715-WMKS-RC-P-i C.2 / i-RC-P-1C / LSHB SEAL HOUSE BOLTS 11715-WM KS-RC-R- 1.1 / 1-RC-R-i / 09 NOZZLE-TO-VESSEL 11715-WMKS-RC-R-1.1 / I-RC-R-1 /09NIR RV OUTLET NIR 11715-WMKS-RC-R-1.1 / I-RC-R-1 /1 SHELL TO FLNG WELD 11715-WMKS-RC-R-1.1 / I -RC-R- 1 /10 NOZZLE-TO-VESSEL 11715-WMKS-RC-R-1.1 /1-RC-R-i / ONIR RV INLET NIR 11715-WMKS-RC-R-1.1 / 1-RC-R- / 11 NOZZLE-TO-VESSEL 11715-WMKS-RC-R-1,1 / i-RC-R-1 / I1NIR RV OUTLET NIR 11715-WMKS-RC-R-1.1 i-RC-R-1 /1 2 NOZZLE-TO-VESSEL 11715-WMKS-RC-R-1.1 1-RC-R-1 / 12NIR RV INLET NIR 11715-WMKS-RC-R-1.1 i-RC-R-1 / 13 NOZZLE-TO-VESSEL 11715-WMKS-RC-R-1.1 / -RC-R-i / 13NIR RV OUTLET NIR 11715-WMKS-RC-R-1.1 1-RC-R-1 / 14 NOZZLE-TO-VESSEL 11715-WMKS-RC-R-1.1 / -RC-R-1 / 14NIR RV INLET NIR 11715-WMKS-RC-R-1.1 i-RC-R-1 / 2 CIRC. SHELL WELD 11715-WMKS-RC-R-1.1 i-RC-R-1 /3 CIRC. SHELL WELD 11715-WMKS-RC-R-1.1 / -RC-R-1 / 4 CIRC, SHELL WELD 11715-WMKS-RC-R-1.1 1-RC-R-1 /5 MERID. SHELL WELD 11715-WMKS-RC-R-1.i1 1-RC-R-I / 6 MERID. SHELL WELD 11715-WMKS-RC-R-1.1 1-RC-R-1 / 7 MERID. SHELL WELD 11715-WMKS-RC-R-1.1 / 1-RC-R-1 / 8 MERID. SHELL WELD 11715-WMKS-RC-R-1.1 / I-RC-R-1 / CSS CORE SUPT STUCTURE 11715-WMKS-RC-R-1.1 / 1-RC-R-1 / IAOBR INT ATACH OUT. B.R.
11715-WMKS-RC-R-1.1 / i-RC-R-1 /INST. NOZZLES INSTRUMENTATION NOZZLES 11715-WMKS-RC-R-1.t / 1-RC-R-1 / INT RV INTERIOR 11715-WMKS-RC-R-1.1 / i-RC-R-1 / PAD-I SUPPORT 11715-WMKS-RC-R-1.1 / i-RC-R-1 /PAD-2 SUPPORT 11715-WMKS-RC-R-1.1 /i-RC-R-1 /PAD-3 SUPPORT NAPS UI 14-1S- Plan 9-11 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 1 1171 5-WMKS-RC-R- 1.1/ I1-RC-R-1 I PAD-4 SUPPORT 1
I I715-WM KS-RC-R- 1.1/ 1 -RC-R-1 I PAD-5 SUPPORT 11715-WMKS-RC-R- 1,1/ 1-RC-R-1I PAD-6 SUPPORT 11715-WMKS-RC-R-1.2/ 1-RC-R-1 /I1 HEAD-TO-FLANGE WELD 11715-WMKS-RC-R-1.2 / 1-RC-R-1 / CRD-57 CRDM HOUSING WELD 11715-WMKS-RC-R-1.2 / 1-RC-R-1 / CRD-63 CRDM HOUSING WELD 11715-WMKS-RC-R-1.2 / 1-RC-R-1 / CRD-64 CRDM HOUSING WELD 11715-WMKS-RC-R-1.2/ 1-RC-R-1 / CRDM HOUSING CRDM HOUSING WELD 11715-WMKS-RC-R-1.2 / 1-RC-R-1 / MC-01 MARMON CLAMP 11715-WMKS-RC-R-1.2 I i-RC-R-1 I RX VESSEL VENT RV VENT PIPE 11715-WMKS-RC-R-1.3 I 1-RC-R-1 IS-01 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 I 1-RC-R-1 /S-02 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 I 1-RC-R-1 / S-03 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 I 1-RC-R-1 / S-04 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 I 1-RC-R-1 / S-05 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 / -RC-R-1 / S-06 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / S-07 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 I 1-RC-R-1 /S-08 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 I 1-RC-R-1 IS-09 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 / 1-RC-R-1 IS-10 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 I i-RC-R-1 /S-1I RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 I 1-RC-R-1 /S-12 RV CLOSURE HEAD STUD 1 1715-WMKS-RC-R-1.3 /1-RC-R-i S-13 RV CLOSURE HEAD STUD 11 715-WMKS-RC-R-1.3 / 1-RC-R- / S-14 RV CLOSURE HEAD STUD 11 715-WMKS-RC-R-1.3 /1-RC-R-1i S-15 RV CLOSURE HEAD STUD 11 715-WMKS-RC-R-1.3 /1-RC-R-1 S-16 RV CLOSURE HEAD STUD 11 715-WMKS-RC-R-1.3 /1-RC-R-1 /S-1 7 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 /1-RC-R-1 /S-18 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 /1-RC-R-1i S-19 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 /1-RC-R-1 / S-20 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 /1-RC-R-1i S-21 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 I 1-RC-R-1 / S-22 RV CLOSURE HEAD STUD NAPS U1 14-ISI Plan 9-12 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11171 5-WMKS-RC-R- .3 / 1-RC-R- S-23 RV CLOSURE HEAD STUD 1 11 715-WMKS-RC-R-1.3 / 1-RC-R-1 / S-24 RV CLOSURE HEAD STUD 1 11 715-WMKS-RC-R-1.3 / 1-RC-R-1 / S-25 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / I-RC-R-I /S-26 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / i-RC-R-1 / S-27 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / S-28 RV CLOSURE HEAD STUD 1 ii 715-WMKS-RC-R-1.3 / 1-RC-R-1 /S-29 RV CLOSURE HEAD STUD 1 I1715-WMKS-RC-R-i1.3 / I-RC-R-I / S-30 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / I-RC-R-I /S-31 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / I-RC-R-1 / S-32 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / I-RC-R-1 / S-33 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / S-34 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / 1-RC-R-1 /S-35 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / 1-RC-R-1I /S-36 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / S-37 RV CLOSURE HEAD STUD 1 11 715-WMKS-RC-R-1.3 / 1-RC-R-1 /S-38 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / 1-RC-R-1 /S-39 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3/ 1-RC-R-1 /S-40 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 /1-RC-R-1 / S-41 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 /I-RC-R-1 / S-42 RV CLOSURE HEAD STUD 11715-WMKS-RC-R- 1.3 / 1-RC-R-i / S-43 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / S-44 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / S-45 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / S-46 RV CLOSURE HEAD STUD 111715-WMKS-RC-R-1.3 / i-RC-R-1 / S-47 RV CLOSURE HEAD STUD 11715-WMKS-RC-RP-.3/ I-RC-R-1 /S-48 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / i-RC-R-1 / S-49 RV CLOSURE HEAD STUD 1 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / S-5O RV CLOSURE HEAD STUD 11 715-WMKS-RC-R-1.3 / I-RC-R-1 / S-51 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 / I-RC-R-1 / S-52 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3/ I-RC-R-1 /S-53 RV CLOSURE HEAD STUD I 11715-WMKS-RC-R-1.3/ i-RC-R-1 /S-54 RV CLOSURE HEAD STUD NAPS U I 14-ISI Plan 9-13 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 1 11715-WMKS-RC-R-1.3 1-RC-R-1 / S-55 RV CLOSURE HEAD STUD 1
11715-WMKS-RC-R-1.3 1-RC-R-1 / S-56 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 I -RC-R-1 / S-57 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 1-RC-R-1 / S-58 RV CLOSURE HEAD STUD 11715-WMKS-RC-R-1.3 1-RC-R-1 / TIF-01 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 I -RC-R-1 / TIF-02 RV THREAD IN FLANGE 11715-WMKS-RC-R&1.3 I1-RC-R-1 / TIF-03 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 I1-RC-R-1 / TIF-04 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-05 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-06 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-07 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-08 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-09 RV THREAD IN FLANGE 1 1715-WMKS-RC-R-1.3/ I-RC-R-1 / TF-10 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF- 11 RV THREAD IN FLANGE
.11715-WMKS-RC-R-1.3 / 1-RC-R-1 TIF-12 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 /1-RC-R-1 / TIF-13 RV THREAD IN FLANGE 11715-WMKS-RC-R-1,3 /1-RC-R-1 / TIF-14 RV THREAD IN FLANGE 11 715-WMKS-RC-R-1.3 /1-RC-R-1/ TIF-15 RV THREAD IN FLANGE 11 715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-16 RV THREAD IN FLANGE' 11715-WMKS-RC-R-1.3 / 1-RC-R-1 /TIF-17 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 /TIF-18 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-19 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-20 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / i-RC-R-1 / TIF-21 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 /TIF-22 RV THREAD IN FLANGE 11715-WM KS-RC-R-i1.3 / 1-RC-R-i / TIF-23 RV THREAD IN FLANGE 11715-WMKS-RC-R-i1.3 / i-RC-R-1 / TIF-24 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-25 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 /TIF-26 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-27 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-28 RV THREAD IN FLANGE NAPS U I14-ISI Plan 9-14 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-29 RV THREAD IN FLANGE 11715-WMKS-RC-R-i1.3 / 1-RC-R-1 / TIF-30 RV THREAD IN FLANGE 11 715-WMKS-RC-R-1.3/ 1-RC-R-1 / TIF-31 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-32 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-33 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 /1 -RC-R-1 / TIF-34 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-C--R-1 TIF-35 RV THREAD IN FLANGE 11715-WMKS-RC-R-l .3 / 1-RC-R-1 TIF-36 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-i / TIF-37 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-38 RV THREAD.IN FLANGE 11715-WMKS-RC-R- 1.3 I 1-RC-R-1 / TIF-39 RV THREAD IN FLANGE 1171 5-WMKS-RC-R-1.3 /1-c-P-i TIF-40 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 1-RC-R-1 / TIF-41 RV THREAD IN FLANGE 11715-WMKS-RC-R- 1.3 1-RC-R- / TIF-42 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 1-RC-R-1 /TIF-43 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 i-RC-R-1 /TIF-44 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 i-RC-R-1i/ TIF-45 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 1-RC-R-1 / TIF-46 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 1-RC-R-1 / TIF-47 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 1-RC-R-1 / TIF-48 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 i-RC-R-1 /TIF-49 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 1-RC-R-1 / TIF-50 RV THREAD IN FLANGE 11715-WMKS-RC-R-i1.3 1-RC-R-1 / TIF-51 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 / 1-RC-R-1 / TIF-52 RV THREAD IN FLANGE 11 715-WMKS-RC-R-i1.3 / 1i-RC-R- / TIF-53 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 I-RC-R-1 / TIF-54 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 1-RC-R-1 I TIF-55 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 1-RC-R-1 / TIF-56 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 1-RC-R- / TIF-57 RV THREAD IN FLANGE 11715-WMKS-RC-R-1.3 1-RC-R-1 / TIF-58 RV THREAD IN FLANGE 11715-WMKS-RC-R- 1.4 1-RC-R-1 CCW-01 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 I 1-RC-R-1 CCW-02 RV CONCAVE WASHER NAPS Ul 14-ISI Plan 9-15 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-RC-R-1.4 / 1-RC-R-1 / CCW-03 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / I-RC-R-1 / CCW-04 RV CONCAVE WASHER 11715-WMKS-RC-R- 1.4 1i-RC-R-i1 CCW-05 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 I CCW-06 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4/ I-RC-R-1 / CCW-07 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 / CCW-08 RV CONCAVE WASHER 11715-WMKS-RC-R- 1.4 / i-RC-R-1 / CCW-09 RV CONCAVE WASHER 11 715-WMKS-RC-R-1.4 / 1-RC-R-1 / CCW-10 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 /1-Re-R-i CCW- 11 RV CONCAVE WASHER 11 715-WMKS-RC-R-i1.4/ 1-RC-R-i I CCW-12 RV CONCAVE WASHER 11 715-WMKS-RC-R-1.4 /I -RC-R-1 CCW-13 RV CONCAVE WASHER 11 715-WMKS-RC-R-1.4 / -RC-R-1 / CCW-14 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 I 1-RC-R-1 / CCW-15 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 / 1-RC-R-1 / CCW-16 RV CONCAVE WASHER 11 715-WMKS-RC-R-i1.4 / i-RC-R- / CCW- 17 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 /1-RR-1 / CCW-1 8 RV CONCAVE WASHER 11 715-WMKS-RC-R-1.4 /i-RC-R-1 / CCW-19 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 / i-RC-R-i / CCW-20 RV CONCAVE WASHER 11715-WM KS-RC-R- 1.4 /1 -RC-R- 1 CCW-21 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 /I -RC-R-1/ CCW-22 RV CONCAVE WASHER 11715-WMKS-RC-R- 1.4 / i-RC-R-1 / CCW-23 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 / i-RC-R-i / CCW-24 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 /1 -RC-R-i / CCW-25 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / -RC-R-1 / CCW-26 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 I-RC-R-1 / CCW-27 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 1-RC-R-i / CCW-28 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 1-RC-R-i / CCW-29 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 /1-RC-R-1 / CCW-30 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 I-RC-R-1 / CCW-31 RV CONCAVE WASHER 11715-WMKS-RC-R- 1.4 1-RC-R-i / CCW-32 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 1-RC-R-1 / CCW-33 RV CONCAVE WASHER 11715-WMKS-RC-R-1,4 1-RC-R-1 / CCW-34 RV CONCAVE WASHER NAPS UI 14-ISI Plan 9-16 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-RC-R-i1.4 / 1-RC-R-1 / CCW-35 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 / 1-RC-R-i / CCW-36 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / I -RC-R-1 / CCW-37 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 / CCW-38 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 / 1-RC-R-i / CCW-39 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1i CCW-40 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-i / CCW-41 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 / 1-RC-R-i / CCW-42 RV CONCAVE WASHER 11715-WMKS-RC-R- 1.4 / 1-RC-R-1 / CCW-43 RV CONCAVE WASHER 11715-WM KS-RC-R- 1.4 / 1-RC-R-i / CCW-44 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 /I -RC-R-1 CCW-45 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 /I -RC-R-i/ CCW-46 RV CONCAVE WASHER 11715-WM KS-RC-R- 1.4 / 1-RC-R-1. / CCW-47 RV CONCAVE WASHER 11715-WMKS-RC-R- 1.4 / i-RC-R-1 / CCW-48 RV CONCAVE WASHER 11715-WMKS-RC-R- 1.4 / i-RC-R-1 / CCW-49 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-i / CCW-50 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-i ICCW-51 RV CONCAVE WASHER 11715-WMKS-RC-R-14 /1 -RC-R-i/ CCW-52 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 / CCW-53 RV CONCAVE WASHER 11715-WM KS-RC-R- 1.4 / i-RC-R-i / CCW-54 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 / i-RC-R-i / CCW-55 RV CONCAVE WASHER 1 1715-WMKS-RC-R-i1.4 / i-RC-R-i / CCW-56 RV CONCAVE WASHER 11715-WMKS-RC-R-i1.4 / i-RC-R-i / CCW-57 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-i / CCW-58 RV CONCAVE WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-i / CVW-0I RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 / CVW-02 RV CONVEX WASHER 11715-WMKS-RC-R-i1.4 / i-RC-R-i / CVW-03 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-i / CVW-04 RV CONVEX WASHER 11715-WMKS-RC-R-i1.4 / i-RC-R-1 / CVW-05 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 / CVW-06 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-i / CVW-07 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 / CVW-08 RV CONVEX WASHER NAPS I1I 14-1I1 Plan 9-17 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-RC-R-1.4/ 1-RC-R-1 / CVW-09 RV CONVEX WASHER 11715-WMKS-RC-R-i1.4/ 1-RC-R-i / CVW-IO RV CONVEX WASHER 11715-WMKS-RC-R-1.4/ I -RC-R-1 / CVW-11 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / -RC-R-1 / CVW-12 RV CONVEX WASHER 11715-WMKS-RC-R-i1.4 / 1-RC-R-1 I CVW-13 RV CONVEX WASHER 11715-WMKS-RC-R-i1.4 / i-RC-R-1 I CVW-14 RV CONVEX WASHER 11 715-WMKS-RC-R-i1.4 / 1-RC-R-1 I CVW-15 RV CONVEX WASHER 11 715-WMKS-RC-R-1.4/ 1-RC-R-1 / CVW-16 RV CONVEX WASHER 11 715-WMKS-RC-R- 1.4 / 1-RC-R-1 / CVW- 17 RV CONVEX WASHER 11715-WMKS-RC-R-1.4/ 1-RC-R-1 /CVW-18 RV CONVEX WASHER 11 715-WMKS-RC-R-1.4 / 1-RC-R-1 CVW-19 RV CONVEX WASHER 11715-WMKS-RC-R-i1.4 / i-RC-R-i CVW-20 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 CVW-21 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 CVW-22 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-i CVW-23 RV CONVEX WASHER 11 715-WMKS-RC-R-1.4 / 1-RC-R-1 CVW-24 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 CVW-25 RV CONVEX WASHER 11 715-WMKS-RC-R-i1.4 / 1-RC-R-i1 CVW-26 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 CVW-27 RV CONVEX WASHER 11715-WMKS-RC-R- 1.4 / i-RC-R-i1 CVW-28 RV CONVEX WASHER 11715-WMKS-RC-R-1.4/ 1-RC-R-1 CVW-29 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 CVW-30 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 CVW-31 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 CVW-32 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 CVW-33 RV CONVEX WASHER 1 1715-WMKS-RC-R-i1.4 / i-RC-R-i1 CVW-34 RV CONVEX WASHER 11715-WMKS-RC-R-i1.4 / i-RC-R-i CVW-35 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 /CVW-36 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 CVW-37 RV CONVEX WASHER 11715-WMKS-RC-R- 1.4 / i-RC-R-i CVW-38 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 CVW-39 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 CVW-40 RV CONVEX WASHER NAPS UI 14-ISI Plan 9-18 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11 715-WMKS-RC-R-1.4 / i-RC-R-1 / CVW-41 RV CONVEX WASHER 11715-WMKS-RC-R-1,4 / I-RC-R-1 / CVW-42 RV CONVEX WASHER 11715-WMKS-RC-R- 1.4 / 1-RC-R-1 / CVW-43 RV CONVEX WASHER 1 1715-WMKS-RC-R-i1.4/ 1-RC-R-1 / CVW-44 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 / CVW-45 RV CONVEX WASHER 11715-WMKS-RC-R- 1.4 / 1-RC-R-1 / CVW-46 RV CONVEX WASHER 1 1715-WMKS-RC-R-i1.4 / 1-RC-R-1 / CVW-47 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 / CVW-48 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 / CVW-49 RV CONVEX WASHER 11715-WM KS-RC-R- 1.4 / 1-RC-R-i / CVW-50 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 /1 -RC-R-1 / CVW-51 RV CONVEX WASHER 11715-WMKS-RC-R-i1.4/ 1-RC-R-i / CVW-52 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 / CVW-53 RV CONVEX WASHER 11715-WMKS-RC-R- 1.4 / 1-RC-R-1 / CVW-54 RV CONVEX WASHER 11715-WM KS-RC-R-i1.4 / 1-RC-R-i I CVW-55 RV CONVEX WASHER 1 1715-WMKS-RC-R- 1.4 / i-RC-R-iI CVW-56 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 CVW-57 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / i-RC-R-1 CVW-58 RV CONVEX WASHER 11715-WMKS-RC-R-1.4 / 1-RC-R-1 N-01 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / -RC-R-i N-02 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / i-RC-R-1 N-03 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-i1.4 / i-RC-PR-i1 N-04 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / 1-RC-R-1 N-05 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / i-RC-R-1 N-06 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-i1.4 / i-RC-R-i N-07 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / i-RC-R-1 N-08 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / 1-RC-R-1 N-09 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / 1-RC-R-1 N-l0 RV CLOSURE HEAD NUT 1 1715-WMKS-RC-R-i1.4 / i-RC-R-i N-Il RV CLOSURE HEAD NUT 11715-WMKS-RC-R-i1.4 / i-RC-R-i N-12 RV CLOSURE HEAD NUT 11 715-WMKS-RC-R- 1.4 / i-RC-PR-i1 N-13 RV CLOSURE HEAD NUT 11 715-WMKS-RC-R-1.4 / i-RC-R-1 N-14 RV CLOSURE HEAD NUT NAPS U I14-ISI Plan 9-19 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-RC-R-1.4 /1-RC-R-1i N-15 RV CLOSURE HEAD NUT 11 715-WMKS-RC-R-i1.4 / 1-RC-R-1 / N-16 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 /1-RC-R-i N-17 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4/ I-RC-R-1 / N-1 8 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 /i-RC-R-1i N-19 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-i1.4 /1-RC-R-i N-20 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / 1-RC-R-1/ N-21 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / 1-RC-R-1 / N-22 RV CLOSURE HEAD NUT 11715-WMKS-RC-R- 1.4/ 1-RC-R-I / N-23 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-i1.4/ i-RC-R-1 / N-24 RV CLOSURE HEAD NUT 11715-WM KS-RC-R- 1.4 / i-RC-R-1 / N-25 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / i-RC-R-1 / N-26 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / i-RC-R-1 / N-27 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / 1-RC-R-1 / N-28 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / i-RC-R-1 / N-29 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-14 / i-RC-R-1 / N-30 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / i-RC-R-1 / N-31 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4/ i-RC-R-1 / N-32 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / i-RC-R-1 / N-33 RV CLOSURE HEAD NUT 11 715-WMKS-RC-R-1.4 / 1-RC-R-1 / N-34 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / i-RC-R-1 / N-35 RV CLOSURE HEAD NUT 1 I715-WMKS-RC-R-1.4 / i-RC-R-i / N-36 RV CLOSURE HEAD NUT 11715-WM KS-RC-R- 1.4 / i-RC-R- I / N-37 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1,4 / -RC-R-1 / N-38 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1,4 / i-RC-R-1 / N-39 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / I-RC-R-1 / N-40 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-i1.4 / i-RC-R-I / N-41 RV CLOSURE HEAD NUT 11 715-WMKS-RC-R-i1.4 / i-RC-R-I / N-42 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-i1.4 / i-RC-R-1 I N-43 RV CLOSURE HEAD NUT 1 11715-WM KS-RC-R- 1.4 / i-RC-R-1 / N-44 RV CLOSURE HEAD NUT 1
11715-WMKS-RC-R-1.4 / i-RC-R-1 / N-45 RV CLOSURE HEAD NUT 1
11715-WMKS-RC-R-1.4 / i-RC-R-1 / N-46 RV CLOSURE HEAD NUT NAPS U1 14-ISI Plan 9-20 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-RC-R-1.4 /1-RC-R-1 N-47 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / 1-RC-R-1 N-48 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 /1 -RC-R-1 / N-49 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / 1-RC-R-1 /N-50 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-i1.4/ 1-RC-R-1 N-51 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 /1-RC-R- I N-52 RV CLOSURE HEAD NUT 11715-WM KS-RC-R-i1.4/ 1-RC-R- I N-53 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.4 / I-RC-R-1 /N-54 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-i1.4 / i-RC-R-i / N-55 RV CLOSURE HEAD NUT 1 1715-WMKS-RC-R-i1.4 / 1-RC-R-i / N-56 RV CLOSURE HEAD NUT 1 1715-WMKS-RC-R-1.4 / i-RC-R-i / N-57 RV CLOSURE HEAD NUT 1 1715-WMKS-RC-R-1.4 / 1-RC-R-i / N-58 RV CLOSURE HEAD NUT 11715-WMKS-RC-R-1.5 / 1-RC-R-1 / R-02 SEISMIC SUPPORT 11715-WMKS-RC-R- 1.5 !1 -RC-R-1 / R-03 SEISMIC SUPPORT 11715-WMKS-RC-R-1.5 / i-RC-R-1 / R-04 SEISMIC SUPPORT 11715-WMKS-RC-R-1.5 / i-RC-R-1 / R-05 SEISMIC SUPPORT 11715-WMKS-RC-R-1.5 / i-RC-R-1 / R-06 SEISMIC SUPPORT 11715-WMKS-RC-R-1.5 / i-RC-R-1 / R-07 SEISMIC SUPPORT 11715-WMKS-01 13A-1 / 14-RH-1 / HSS-109D SUPPORT 11715-WMKS-01 13A-1 / 14-RH-1 / HSS-1 16A SUPPORT 11715-WMKS-01 13A-1 / 14-RH-1 / MOV-1700 BOLT VALVE BONNET BOLTING 11 715-WMKS-01 13A-1 / 14-RH-1 /MOV-1 701 BOLT VALVE BONNET BOLTING 11715-WMKS-0113A-1 / 14-RH-1 !SW-20W ELBOW-PIPE 11715-WMKS-01 13A-1 / 14-RH-1 / SW-29W ELBOW-PIPE 11715-WMKS-0113B / 10-RH-12 / MOV-1720A BOLT VALVE BONNET BOLTING 11715-WMKS-01 13C-3 / 1O-RH-14 / MOV-1720B VALVE BONNET BOLTING BOLTING 11 715-WMKS-01 13C-3 / 1O-RH-14 / P-1 SUPPORT 11715-WM KS-0103AC / 6-SI- 130 / 4 PIPE-ELBOW 11715-WMKS-0103AC / 6-SI-130 / 5 TEE-TEE 11715-WMKS-0103AC / 6-S1-130 / SW-90 PIPE-ELBOW 1 1715-WMKS-0103AC / 6-SI-16 / 29H INTERGAL ATTACHMENT WELD 11715-WM KS-0103AC / 6-SI- 16 / R-208 FAB-LC-MECH NAPS U I 14-ISI Plan 9-21 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 1 11715-WMKS-0103AC / 6-SI-16 / SH-207 STD-SH-WELD 1 11715-WMKS-0103AC I 6-SI-16 I SW-1 PIPE-ELBOW 1 11715-WMKS-0103AC / 6-S1-19 / 21 PIPE-ELBOW 1 11715-WMKS-0103AC I 6-S1-19 /24 PIPE-ELBOW 1 11715-WMKS-0103AC / 6-SI-21 I R-18D FAB-VC LC-MECH 1 11715-WMKS-0103AC / 6-SI-21 / R-19D FAB-VC LC-MECH 1 11715-WMKS-0103AC / 6-SI-21 I SW-5 ELBOW-TEE 1 11715-WMKS-0103AD / 2-SI-63 I R-4 FAB-EW NS-MECH 1 11715-WMKS-0103AD / 2-SI-63 / SH-5 STD-SH-WELD 1 11715-WMKS-0103AD / 6-RC-21 /18 ELBOW-WELDOLET 1 11715-WMKS-0103AD I 6-RC-21 I SW-21 ELBOW-PIPE 1 11715-WMKS-0103AD /6-SI-16 /47H INTERGAL ATTACHMENT WELD 1 11715-WMKS-0103AD I 6-S1-16 / R-2 FAB-LC VC-MECH 1 11715-WMKS-0103AD / 6-SI-16 /SI-103 BOLTING VALVE BONNET BOLTING 1 11715-WMKS-0103AD / 6-SI-16 / SI-213 BOLTING VALVE BONNET BOLTING 1 11715-WMKS-0103AD / 6-SI-16 I SW-59 PIPE-ELBOW 1 11715-WMKS-0103AE-1 / 3-SI-139/ A-253 FAB-ANC-WELD 1 11715-WMKS-0103AE-1 / 3-SI-139 / A-7E FAB-ANC-WELD 1 11715-WMKS-0103AE-1 / 3-S1-139 / R-245 FAB-VC-MECH 1 11 715-WM KS-0103AE- 1 ! 3-SI-57 I A-254 FAB-ANC-WELD 1 .1 1715-WMKS-0103AE-1 3-SI-57 / SH-252 STD-SH-MECH 1 11715-WMKS-0103AE-4 2-SI-61 / A-24 FAB-ANC-WELD 1 11715-WMKS-0103AE-4 2-SI-61 I R-25 FAB-VC-MECH 1 11715-WMKS-0103AE-4 / 2-SI-61 / R-26 FAB-VC LC-MECH 1 11715-WMKS-0103AE-4 / 2-SI-61 / R-27 FAB-VC-MECH 1 11715-WMKS-0103AE-4 / 2-SI-61 R-28 R FAB-VC LC-MECH 1 11715-WMKS-01 03AE-4 / 2-SI-61 / R-31 FAB-LC-WELD 1 11715-WMKS-0103AF / 6-SI-19 / 26H INTERGAL ATTACHMENT WELD 1 11715-WMKS-0103AF / 6-SI-19 /Si-211 BOLTING VALVE BONNET BOLTING 1 11715-WMKS-0103AF /6-SI-19 / SI-95-BOLTING VALVE BONNET BOLTING 1 11715-WMKS-0103AG / 2-SI-59 / R-13 FAB-VC-MECH 1 11715-WMKS-0103AG / 2-SI-59/ R-8 FAB-VC LC-MECH NAPS Ul 14-IST Plan 9-22 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-0103AH / 6-SI-21 / S-23D FAB-VS-MECH 11715-WMKS-0103AH / 6-SI-21 / S-24D FAB-VS-MECH 11715-WMKS-0103AH / 6-SI-21 / S-25D FAB-VS-MECH 11715-WMKS-01 03AJ / 6-SI-21 I A-29D FAB-ANC-WELD 11715-WMKS-0103AJ / 6-SI-21 / R-169 STD-RH-MECH 11715-WMKS-0103AJ / 6-SI-21 / R-170 STD-VC AC-WELD 11715-WMKS-0103AJ / 6-SI-21 I R-171 FAB-VC LC-MECH 11715-WMKS-0103AJ / 6-SI-21 / R-2 FAB-VC-WELD 11715-WMKS-0103AJ / 6-SI-21 I S-30D FAB-VS-MECH 11715-WMKS-0103AJ I 6-SI-21 SI-209 BOLTING VALVE BONNET BOLTING 11715-WMKS-0103AJ /6-SI-21/ SI-209-BODY VALVE BODY 11715-WMKS-0103AJ / 6-SI-21 /SI-99 BOLTING VALVE BONNET BOLTING 11715-WMKS-0103AJ / 6-SI-21 / SW-13 PIPE-ELBOW 11715-WMKS-0103AJ /6-SI-21 I SW-15 PIPE-ELBOW 11715-WMKS-0103AK /2-SI-611 R-12 FAB-VC-MECH 11715-WMKS-0103AL I 2-SI-61 I R-20 FAB-VC-MECH 11715-WMKS-0103AL I 2-SI-61 I R-22 FAB-VC-MECH 11715-WMKS-0103K / 6-SI-131 /R-197. SUPPORT 11715-WMKS-0,103K / 6-SI-131/ SI- 195 BOLTING BOLTING 11715-WMKS-0103K I 6-SI-132 I SI-199 BOLTING BOLTING 11715-WMKS-0103K I 6-SI-133 /1 VALVE-ELBOW 11715-WMKS-0103K I 6-S1-133 I SI-197 BOLTING BOLTING 11715-WMKS-0103L /6-S1-131/ 29H INTEGRAL ATTACHMENT WELD 11715-WMKS-0103L I 6-S1-131 I A-5 SUPPORT 11715-WMKS-0103L I 6-SI-131 I RH-200 SUPPORT 11715-WMKS-0103L/6-SI-131 /S-24E SUPPORT 11715-WMKS-0103L /6-SI-131 /S-30E SUPPORT 11715-WMKS-0103N I 6-S1-131 I HSS-109 SUPPORT 11715-WMKS-0103N I 6-SI- 131/ SI-83 BOLTING, VALVE BOLTING 11715-WMKS-0103T /6-SI-132/ 2J INTERGAL ATTACHMENT WELD 11715-WMKS-0103T I 6-S1-132 I R-180 SUPPORT 11715-WMKS-0103T / 6-S1-132 / R-181A SUPPORT NAPS IT1 14-1SI Plan 9-23 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-0103T / 6-SI-132 / RH-186 SUPPORT 11715-WMKS-0103T / 6-SI-132 / RH-188 SUPPORT 11715-WMKS-0103T / 6-SI-132 / RH-191 SUPPORT 11715-WMKS-0103U / 6-SI-132 / 47H INTERGAL ATTACHMENT WELD 11715-WMKS-0103U I 6-SI-132 I A-3 SUPPORT 11715-WMKS-0103U / 6-SI-132 / RH-176 SUPPORT 1 1715-WMKS-0103U / 6-SI-132 / RH-177 SUPPORT 11715-WMKS-0103W / 6-SI-132 / R-1 SUPPORT 11715-WMKS-0103W / 6-SI-132 / R-2 SUPPORT 11715-WMKS-0103W / 6-SI-132 / SI-89 BOLTING VALVE BOLTING 11715-WMKS-0103Y/6-SI-133/ 18H INTERGAL ATTACHMENT WELD 11715-WMKS-0103Y / 6-SI-133 / 19H INTERGAL ATTACHMENT WELD 11715-WMKS-0103Y / 6-SI-133 / A-3 SUPPORT 11715-WMKS-0103Y / 6-SI-133 / R-2 SUPPORT 11 715-WMKS-0103Y 6-SI-133 RH-i SUPPORT 11715-WMKS-0103Y / 6-SI-133 / RH-204 SUPPORT 11715-WMKS-0103Y / 6-SI-133 / SI-86 BOLTING VALVE BOLTING 11715-WMKS-0103YA- I60-S-13 / SW- 7I PIPE-REDUCER 11715-WMKS-0104A-1 I 10-SI-15 I SW-19 PIPE-ELBOW 11 715-WMKS-0104A-1 / 10-SI-15 / SW-24 ELBOW-PIPE 11715-WMKS-0104A-1 / 6-SI-16 / 11 REDUCER-PIPE 11715-WMKS-0104A-2 / 10-S1-140 /20 VALVE-PIPE 11715-WMKS-0104A-2 I 10-SI-140 I HSS-106 SUPPORT 11715-WMKS-0104A-2 I 10-SI-140 I R-36 SUPPORT 11715-WMKS-0104A-2 / 10-SI-140 / SW-1I PIPE-ELBOW 11715-WMKS-0104A-2 I 10-S1-1401 SW-82 ELBOW-PIPE 11715-WMKS-0104A-2 /10-SI-18/ 7A VALVE-TEE 11715-WMKS-0104A-2 / 10-SI-18/ SW-16 PIPE-ELBOW
.11,715-WMKS-0104A-2 I 10-SI-238 / 61 ELBOW-TEE 11715-WMKS-0104A-2 / 10-SI-238 /66 PIPE-ELBOW 11715-WMKS-0104A-2 / 10-SI-238 I 70H INTERGAL ATTACHMENT WELD 11715-WMKS-0111Q / 3-SI-17 / SW-4 PIPE-ELBOW NAPS Ul 14-ISI Plan 9-24 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-0 1IXF / 2-SI-53 /A-1 SUPPORT 11715-WMKS-0 111 XF / 2-SI-53 / A-17 SUPPORT 11715-WMKS-01IIXF / 2-SI-53 /A-21 SUPPORT 11715-WMKS-01 1 IXF / 2-SI-53 / A-6 SUPPORT 11715-WMKS-0 111 XF / 2-SI-53 / R-10 SUPPORT 11715-WMKS-0 111 XF / 2-SI-53 / R-12 SUPPORT 11715-WMKS-01 1IXF / 2-SI-53 / R-7 SUPPORT 1 1715-WMKS-0 1 IXF / 2-SI-53 / R-9 SUPPORT 1 1715-WMKS-0 1 IXF / 2-SI-53 / SH-3 SUPPORT I 11715-WMKS-0 1 IXG / 2-SI-55 /A-I SUPPORT 1 1715-WMKS-0 111 XG I 2-SI-55 I R-2 SUPPORT 1 1715-WMKS-01 I IXG / 2-SI-55 / R-5 SUPPORT 11715-WMKS-0 111 XG / 2-SI-55 / R-6 SUPPORT 11715-WMKS-0I 11XH / 2-SI-51 / R-10 SUPPORT 11715-WMKS-01 1IXH / 2-SI-51 / R- 1I SUPPORT 11715-WMKS-01 11XH /2-SI-51i R-13 SUPPORT 11715-WMKS-0I 11XJ / 3-SI-57 I SW-69 PIPE-ELBOW 11715-WMKS-01 I1XL /3-S1-138/ 3 PIPE-VALVE 11715-WMKS-01 I1XL /3-S1-138 /50 PIPE-PENETRATION 11715-WMKS-011IXL /3-SI-138 /A-8D SUPPORT 11715-WMKS-01 11XM /3-S1-138/ A-552 SUPPORT 11715-WMKS-0 11XM / 3-SI-138 / SW-II PIPE-ELBOW 11715-WMKS-01 1 IXN / 2-SI-51 / 66 PIPE-REDUCER 11715-WMKS-0 1IXN / 3-SI-17 /1 PIPE-VALVE I 1715-WMKS-0 111 XN / 3-SI-17 / 2 PIPE-VALVE 11715-WMKS-01 13A-4 / 12-RC-22 / S1-127 BOLTING VALVE BONNET BOLTING 11715-WMKS-01 13A-4 / 12-SI-67 / HSS-105A SUPPORT 11715-WMKS-01 13A-4 / 12-SI-67 / R-14 SUPPORT 11715-WMKS-01 13A-4 / 12-SI-67 / R-15 SUPPORT 11715-WMKS-01 13A-4 / 12-SI-67 / SI-125 BOLTING VALVE BONNET BOLTING 11 715-WMKS-01 13B / 12-RC-23 / SW-21 ELBOW-PIPE 11715-WMKS-01 13B / 12-SI-68 / 28H INTERGAL ATTACHMENT WELD NAPS U I14-ISI Plan 9-25 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description I I715-WMKS-01 13B / 12-SI-68 / HSS-100 SUPPORT 11715-WMKS-01 13B / 12-SI-68 / HSS-1O0C SUPPORT 11715-WMKS-01 13B /12-SI-68/ R-4 SUPPORT 11 715-WMKS-01 13B / 12-SI-68 / R-5 'SUPPORT 1 1715-WMKS-bl 13B / 12-SI-68 / RH-2 SUPPORT 11715-WMKS-01 13B / 12-SI-68 /SI-142 BOLTING VALVE BONNET BOLTING 11715-WMKS-01 13B / 12-SI-68 / SI-144 BOLTING VALVE BONNET BOLTING 11715-WMKS-01 13C-3 /12-SI-69/ HSS-104 SUPPORT 11715-WMKS-01 13C-3 /12-SI-69 /RH-8 SUPPORT 11715-WMKS-01 13C-3 / 12-SI-69/ RH-9 SUPPORT 11715-WMKS-01 13C-3 / 12-SI-69/ SI-159 BOLTING VALVE BONNET BOLTING 11715-WMKS-01 13C-3 I 12-SI-69 SI-1 61 BOLTING VALVE BONNET BOLTING 2 11 715-WMKS-01 1lAB / 6-CH-18 /46 PIPE-ELBOW 2 11715-WMKS-01 1lAB / 6-CH-1 8 A-21 SUPPORT 2 11715-WMKS-01 IlAB / 6-CH-18 SW-7W PIPE-TEE 2 11 715-WMKS-01 1lAB / 6-CH-19 1 PIPE-VALVE 2 11715-WMKS-011 lAB / 6-CH-19 SH-29 SUPPORT 2 11715-WMKS-01 1lAB I 6-CH-19 SW-20W PIPE-FLANGE 2 11715-WMKS-011 lAB I 6-CH-19 SW-80 PIPE-ELBOW 2 11715-WMKS-01 1 lAB / 6-CH-72 R-18A SUPPORT 2 11715-WMKS-01 1 lAB / 6-CH-72 SW-12W PIPE-FLANGE 2 11715-WMKS-0111BC /3-CH-941 / 18 PIPE-ELBOW 2 11715-WMKS-01110 / 8-CH-17 / A-3 SUPPORT 2 11715-WMKS-0I 110/ 8-CH-17 / R-7 SUPPORT 2 11715-WMKS-01 110 / 8-CH-17 / SW-28 PIPE-ELBOW 2 11715-WMKS-0111C /8-CH-204 /17H INTERGAL ATTACHMENT WELD 2 11715-WMKS-01 11 / 8-CH-204 I SW-39 PIPE-ELBOW 2 11715-WMKS-0 11C / 8-CH-204 / SW-40 PIPE-TEE 2 11715-WMKS-01 1 ICA / 6-CH-19 / SW-18W ELBOW-ELBOW 2 11715-WMKS-01 1 iCA / 6-CH-19 / SW-68 PIPE-ELBOW 2 11715-WMKS-01 1 ICA / 6-CH-19 I SW-71 PIPE-ELBOW 2 11715-WMKS-011IXA /3-CH-11 / 18J INTERGAL ATTACHMENT WELD 2 11715-WMKS-01 1 iXA /3-CH-1 / SW-lW ELBOW-TEE NAPS U1 14-ISI Plan 9-26 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 2 1'1715-WMKS-01 11XA / 3-CH-2 / SW-16W PIPE-ELBOW 2 11715-WMKS-011 tXA/ 3-CH-2 /SW-17W ELBOW-REDUCER 2 11715-WMKS-01 11XA / 3-CH-267 / R-1 19 SUPPORT 2 11715-WMKS-01 1IXA / 3-CH-267 / R-120 SUPPORT 2 11715-WMKS-0111XA/ 3-CH-3 /2 ELBOW-VALVE 2 11715-WMKS-01 1iXA 3-CH-3 I 22H INTERGAL ATTACHMENT WELD 2 11715-WMKS-01 11 XA 3-CH-3 /78 PIPE-ELBOW 2 11715-WMKS-0111XA/ 3-CH-3 /A-173A SUPPORT.
2 11715-WMKS-01 11 XA / 3-CH-3 I SW-33W ELBOW-REDUCER 2 11715-WMKS-011IXA 3-CH-81 / 10A ELBOW-VALVE 2 11715-WMKS-0111XA 3-CH-81 /1W ELBOW-TEE 2 11715-WMKS-0111XA 3-CH-81 /2W PIPE-TEE 2 11715-WMKS-011 1XA /3-CH-81 /R-101 SUPPORT 2 11715-WMKS-0111XA /3-CH-81 /SW-94 PIPE-ELBOW 2 11715-WMKS-0111XA /4-CH-80/ 19 PIPE-ELBOW 2 11 715-WMKS-01 1 IXA / 4-CH-80 I 20A PIPE-ELBOW 2 11 715-WMKS-01 1 IXA/ 4-CH-80 / SW-49 PIPE-ELBOW 2 11 715-WMKS-01 1 1XD / 2-CH-266 / A-3 SUPPORT 2 11715-WMKS-0111XD /3-CH-69 /SW-84 PIPE-ELBOW 2 11715-WMKS-0111XD /3-CH-69 /SW-88 PIPE-ELBOW 2 11715-WMKS-01 11XD / 3-CH-70 / SW-94 PIPE-ELBOW 2 11715-WMKS-0111XD /3-CH-71 /A-179 SUPPORT 2 11715-WMKS-0111XD /3-CH-71 /R-178 SUPPORT 2 11715-WMKS-0111XD 3-CH-71 /SW-1W PIPE-ELBOW 2 11715-WM KS-0111XD /4-CH-89 /20 PIPE-TEE 2 11715-WMKS-0111XE /2-CH-114/ 19H INTERGAL ATTACHMENT WELD 2 11715-WMKS-0111XE /2-CH-114 /A-1 SUPPORT 2 11715-WMKS-01 1IXE / 2-CH-22 / A-3 SUPPORT 2 11715-WMKS-0111XE 3-CH-377 / 13 PIPE-PIPE 2 11715-WMKS-O111XE/3-CH-377/24 PIPE-ELBOW 2 11715-WMKS-01 1 IXE / 3-CH-377 / 35 PIPE-REDUCER 2 11715-WMKS-0111XE / 3-CH-378 / SW-lW PIPE-ELBOW NAPS Ul 14-1;T Plan 9-27 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 2 11715-WMKS-CH-P-1A/ 1-CH-P-1A / SUPT-BASE SUPPORT 2 11715-WMKS-CH-P-1A/ 1-CH-P-1A / WS-01 INTERGAL ATTACHMENT WELD 2 11 715-WMKS-CH-P-1A / 1-CH-P-1A / WS-02 INTEGRAL ATTACHMENT WELD 2 11 715-WMKS-CH-P-1A I 1-CH-P-1A / WS-03 INTEGRAL ATTACHMENT WELD 2 11715-WMKS-CH-P-1A / 1-CH-P-1A / WS-04 INTERGAL ATTACHMENT WELD 2 11715-WMKS-0104G 88-QS-4 I A-]8 SUPPORT 2 11715-WMKS-0104G I 8-QS-4 / R-19 SUPPORT 11715-WMKS-0107C ! 6-QS-19 /23 ELBOW-FLANGE 11715-WMKS-0107C / 6-QS-19 / SW-67 FLANGE-STRAINER 1 1715-WMKS-0107C I 6-QS-19 / SW-68 REDUCER-FLANGE 11715-WM KS-0107C I 6-QS- 19 /SW-86 FLANGE-STRAINER 11715-WM KS-0107C / 6-QS- 19 I SW-87 REDUCER-FLANGE 1 1715-WMKS-0107C / 8-QS-4 I 27H INTERGAL ATTACHMENT WELD 1 1715-WMKS-0107C I 8-QS-4 I 34H INTEGRAL ATTACHMENT WELD 11715-WMKS-0107D I 1-QS-P-lA / A-P1A SUPPORT 1 1715-WM KS-0107D I 6-QS-12 / SW-68 FLANGE-STRAINER 11715-WM KS-0107D I 6-QS- 12 I SW-69 REDUCER-FLANGE 1 1715-WM KS-0107D / 6-QS- 12 / SW-71 PIPE-ELBOW 11715-WMKS-0107D / 8-QS-3 I RH-70 SUPPORT 11715-WM KS-0107D / 8-QS-3 I SW-66 REDUCER-FLANGE 11715-WMKS-0107D I 8-QS-3 / SW-67 FLANGE-STRAINER 11715-WMKS-0107F I 10-QS-2 / R-67B SUPPORT 11715-WM KS-0107 F I 10-QS-2 I SH-67A SUPPORT 11715-WMKS-0107GD / 6-QS-32 / 30A PIPE-TEE 11 715-WM KS-RC-E- 1A.1 I 1-RC-E- 1A / WS-2A INTEGRAL ATTACHMENT WELD 2 11715-WMKS-RC-E-1A.2 I 1-RC-E-1A 10NIR SG MAIN STEAM NIR 2 11715-WMKS-RC-E-1B.1 / 1-RC-E-1B / 8 HEAD SHELL WELD 2 11 715-WMKS-RC-E-1 B.2 I 1-RC-E-1 B /09 FW NOZZLE-TO-VESSEL 2 11715-WMKS-RC-E-1B.2 / 1-RC-E-1 B 09NIR SG FEEDWATER NIR 2 11715-WMKS-RC-E-1C.1 / 1-RC-E-1C / 2A TUBSHT-TO-SHELL WELD 2 11715-WMKS-RC-E-1C.1 / 1-RC-E-1C /6 CIRC. SHELL WELD 2 11715-WMKS-RC-E-1C.2 / 1-RC-E-1C /10 MS NOZZLE-TO-VESSEL NAPS U1 14-IST Plan 9-28 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 2 11715-WMKS-0113A-1 14-RH-2 11 PIPE-VALVE 2 1 1715-WMKS-01 13A-i1 14-RH-2 43 PIPE-TEE 2 11715-WMKS-01 13A-1 14-RH-2 72H INTERGAL ATTACHMENT WELD 2 11715-WMKS-01 13A- I 14-RH-2 R-16 SUPPORT 2 11715-WMKS-01 13A- I 14-RH-2 SW-I8W PIPE-ELBOW 2 11715-WMKS-0113A- I 14-RH-2 SW-89 ELBOW-ELBOW 2 11715-WMKS-01113A-2 14-RH-3 45 PIPE-TEE 2 11715-WMKS-01 13A-2 14-RH-3 53 PIPE-ELBOW 2 11715-WMKS-0113A-2 14-RH-3 /55 PIPE-ELBOW 2 11715-WMKS-01 13A-2 14-RH-3 /56 ELBOW-ELBOW 2 11715-WMKS-01 13A-2 14-RH-3 /64 PIPE-ELBOW 2 11715-WM KS-01 1'3A-2 14-RH-3 I 86H INTERGAL ATTACHMENT WELD 2 11715-WMKS-01 13A-2 14-RH-3 / HSS-1 13A SUPPORT 2 11715-WMKS-01 13A-2 14-RH-3 / HSS-1 13B SUPPORT 2 11715-WMKS-01 13A-2 14-RH-3 / SH-14 SUPPORT 2 11715-WMKS-01 13A-3 1O-RH-8 / RH-10 SUPPORT 2 11715-WMKS-01 13A-3 I 1O-RH-8 / SW-58 PIPE-REDUCER 2 11715-WMKS-01 13C-1 I IO-RH-13 I HSS-100E SUPPORT 2 11715-WMKS-01 13C-1 / IO-RH-32 / A-241 SUPPORT 2 11715-WMKS-01 13C-1 / 1O-RH-32 / SW-3 ELBOW-ELBOW 2 11715-WMKS-01 13C- / 12-RH-i l/ R-2 SUPPORT 2 11 715-WMKS-01 13C-2 / 10-RH-10 / HSS-103A SUPPORT 2 11715-WMKS-01 13C-2./ 1U-RH-10 / HSS-103B SUPPORT 2 11715-WMKS-01 13C-2 / 12-RH-Il / SH-5 SUPPORT 2 11715-WMKS-01 13C-2 / 12-RH-lI / SW-42 PIPE-FLANGE 2 11715-WMKS-RH-E-1A / 1-RH-E-1A / 1 HEAD-TO-SHELL WELD 2 11715-WMKS-RH-E-1A / 1-RH-E-lA / 2 SHELL-TO-FLNG WELD 2 11715-WMKS-RH-E-1A / 1-RH-E-1A / 3A PLATE-TO-SHELL WELD 2 1 1715-WMKS-RH-E-1A / -RH-E-lA / 3B PLATE-TO-SHELL WELD 2 11715-WMKS-RH-E-lA / 1-RH-E-1A / 4A PLATE-TO-SHELL WELD 2 11715-WMKS-RH-E-1A / 1-RH-E-1A / 4B PLATE-TO-SHELL WELD 2 11715-WMKS-RH-E-1A / 1-RH-E-1A / SUPT-INLE_T SUPPORT NAPS U1 14-ISI Plan 9-29 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-RH-E-1A / 1-RH-E-1A / SUPT-OUTLET SUPPORT 11715-WMKS-RH-E-1AI 1-RH-E-1A / WS-1 INTEGFRALLY WELDED 11715-WMKS-RH-E-1B I 1-RH-E-1B /3 NOZZLE-SHELL 11715-WMKS-RH-E-1B / 1-RH-E-1B / 4 NOZZLE-SHELL 11715-WMKS-RH-P-1A / 1-RH-P-1A / HSS-110C SUPPORT 11715-WMKS-RH-P-1A / 1-RH-P-1A / HSS-110D SUPPORT 11715-WMKS-RH-P-1AI 1-RH-P-1A / R-21 SUPPORT 11 715-WM KS-0104D-1 I 10-RS-9 I R-630 SUPPORT 11715-WMKS-0104D-1 I 10-RS-9 I SW-87 PIPE-ELBOW 11715-WMKS-0104D-2 I IO-RS-10 I 85A PIPE-ELBOW 11715-WMKS-0104D-2 I 10-RS-10 / 87A PIPE-ELBOW 11715-WMKS-0104E-1 I 12-RS-7 /23 PIPE-WELDOLET 11715-WMKS-0104E-1 I 12-RS-7 I SW-34 PIPE-ELBOW 1 1715-WMKS-0104E-1 I 12-RS-8 / 1 A PIPE-VALVE 1 1715-WMKS-0104E-2 / 8-RS-E16 I A-612 SUPPORT 11715-WMKS-0104E-2 / 8-RS-J68 /51 PIPE-FLANGE 11715-WMKS-0104E-3 / 8-RS-J67 /41 VALVE-WELDOLET 11715-WMKS-RS-P-2B / 1-RS-P-2B I SW-4 PUMP CASING WELD 11715-WMKS-0101A-1 /32-SHP-1 /10 PIPE-PIPE 11715-WMKS-0101A-1 /32-SHP-1 /9 PIPE-VALVE 1 1715-WMKS-0101A-1 I 32-SHP-1 / HSS-23A STD-VSS-MECH 1 1715-WMKS-0101A-1 /32-SHP-1 /HSS-23B STD-VSS-WELD 1 1715-WMKS-0101A-1 / 32-SHP-1 / R-214 FAB-VC-WELD 11715-WMKS-0101A-1 / 32-SHP-22 / SW-62 (SW-55) REINFORCING PAD 11715-WMKS-O101A-1 I 32-SHP-22 / SW-69 (SW-55) REINFORCING PAD 11715-WMKS-0101A-2 I 32-SHP-2 / R-216 FAB-VC-WELD 11715-WMKS-0101A-2 / 32-SHP-2 / R-316 FAB-EW-MECH 11715-WMKS-0101B 32-SHP-1 / 14 PIPE-PIPE 11715-WMKS-0101B 32-SHP-1 / 18A ELBOW-NOZZLE 11715-WMKS-0101B /32-SHP-1 / HSS-201A STD-SKS-WELD 11715-WMKS-0101B/32-SHP-1 /HSS-201B STD-SKS-WELD 11715-WMKS-0101B /32-SHP-1 / PEN-73 FAB-ANC-WELD NAPS UI 14-ISI Plan 9-30 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 2 11715-WMKS-0101B / 32-SHP-1 / R-43 FAB-VC-WELD 2 11715-WMKS-0101B/32-SHP-1 /R-44 FAB-VC-WELD 2 11715-WMKS-0101B / 32-SHP-1 / SH-42 STD-SH-MECH 2 11715-WMKS-0101 B / 32-SHP-1 / SW-29W PIPE-PIPE 2 11715-WMKS-O1O1 B / 32-SHP-1 / SW-46W INTERGAL ATTACHMENT WELD 2 11715-WMKS-O1O1C/32-SHP-2/ 14 PIPE-ELBOW 2 11715-WMKS-0101C / 32-SHP-2 / HSS-209A STD-SKS-MECH 2 1 1715-WMKS-0101C / 32-SHP-2 / HSS-209B STD-SKS-WELD 2 1 1715-WMKS-0101C / 32-SHP-2 / HSS-210 STD-VSS-WELD 2 11715-WMKS-0101C / 32-SHP-2 / SH-49 STD-SH-MECH 11715-WMKS-0101C / 32-SHP-2 / SW-22W PIPE-PIPE 11715-WMKS-0101C / 32-SHP-2 / SW-37W INTEGRAL ATTACHMENT WELD 11715-WMKS-0101C / 32-SHP-2 I SW-38W INTEGRAL ATTACHMENT WELD 1 1715-WMKS-0101D / 32-SHP-3 I 15 PIPE-ELBOW 11715-WM KS-0101D / 32-SHP-3 I SW-1 PIPE-ELBOW 11715-WMKS-0101D I 32-SHP-3 I SW-29W PIPE-PIPE 11715-WM KS-0101GA / 6-SH P-37 /26 PIPE-WELDOLET 11715-WMKS-0101GA/ 6-SHP-37 /32 PIPE-ELBOW 11715-WMKS-0101GA / 6-SHP-37 /33 PIPE-ELBOW 11715-WMKS-0101GA /6-SHP-37 /SH-118 STD-SH-WELD 11 715-WM KS-0101GA / 6-SH P-37 / SW-40 PIPE-ELBOW 11715-WMKS-0101GB / 6-SHP-38 /42 ELBOW-ELBOW 11715-WMKS-0101GB / 6-SHP-38 I HSS-240 STD-VSS-MECH 11715-WMKS-0101GB / 6-SHP-38 / SW-63 PIPE-ELBOW 11715-WMKS-0101GC I 6-SHP-39 / 24 ELBOW-ELBOW 11715-WMKS-0101GC / 6-SHP-39 / SW-35 PIPE-ELBOW 11715-WMKS-0104A-1 / 10-SI-141 /4 TEE-VALVE 11715-WMKS-0104A-1 / 10-SI-141 /5 VALVE-PIPE 11715-WMKS-0104A-1 10-SI-25 / 83A ELBOW-PIPE 1 1715-WMKS-0104A-1 / 1O-SI-25 I SW-95 ELBOW-TEE 11715-WMKS-0104A-1 / 8-SI-40 / HSS-101A SUPPORT 11715-WMKS-01 04A-2 / 10-SI-239 / 92H INTERGAL ATTACHMENT WELD NAPS U I14-ISI Plan 9-31 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-0104A-2 / 10-SI-239 / HSS-108 SUPPORT 11715-WMKS-0104A-2 110-SI-64 / SH-28 SUPPORT 11715-WMKS-0104B / 12-SI-14 /40 PIPE-ELBOW 11715-WMKS-0104B I 12-SI-14 / R-4 SUPPORT 11715-WMKS-0104B1 12-SI-14 /RH-5 SUPPORT 11715-WMKS-0104B/ 12-SI-14 /SW-21 PIPE-ELBOW 11715-WMKS-0104C /12-SI- / 15 ELBOW-VALVE 11715-WMKS-0104C /12-SI-1i 17 TEE-VALVE 11715-WMKS-0104C /12-SI-il 6 VALVE-PIPE 11715-WMKS-01 04C / 12-SI-14 / SW-24 ELBOW-PIPE 11715-WMKS-0104C /12-SI-2 /11 VALVE-TEE 11715-WMKS-0104C / 12-SI-2 /13 ELBOW-VALVE 11715-WMKS-0104C / 12-SI-215 / SW-36 ELBOW-TEE 11715-WMKS-0104C/ 12-SI-215 /SW-37 PIPE-ELBOW 11715-WMKS-0104K / 10-SI-214 / R-33E SUPPORT 11715-WMKS-0104K/ 12-SI-14 / A-6 SUPPORT 1 1715-WM KS-0104K / 12-SI-5 / 64A TEE-REDUCER 11715-WMKS-0i107B / 8-SI-49 / 81H INTERGAL ATTACHMENT WELD 11715-WM KS-0107B / 8-SI-49 / R-168A SUPPORT 11715-WMKS-0107B / 8-SI-49 / R-84A SUPPORT 1 1715-WMKS-0107H / 10-SI-8 / R-806 SUPPORT 1 1715-WMKS-0107M / 8-SI-40 / 82H INTERGAL ATACHMENT WELD 11715-WMKS-0107M / 8-SI-40 / R-93 SUPPORT 1 1715-WMKS-01 1 B /8-SI-40 / R-36 SUPPORT 11715-WMKS-0111 B / 8-SI-40 / SH-37 SUPPORT 11715-WMKS-01IIC / 10-SI-8 /RH-1I SUPPORT 2 11715-WMKS-0 111 / 8-SI-102 / R-9 SUPPORT 2 11715-WMKS-01 IID / 8-SI-40 / A-35 SUPPORT 2 11715-WMKS-01 11 / 3-SI-167 / SW-35 PIPE-ELBOW 2 11715-WMKS-01 110 / 3-SI-24 / R-543 SUPPORT 2 11715-WMKS-0 111 / 3-SI-24 / SW-36 PIPE-ELBOW 2 11715-WMKS-0111 XJ / 3-SI-136 / 8H INTERGAL ATACHMENT WELD NAPS UI 14-ISI Plan 9-32 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 2 11715-WMKS-01 1 1XJ / 3-SI-136 / A-558 SUPPORT 2 11715-WMKS-01 1 1XJ / 3-SI-136 / R-518 SUPPORT 11715-WMKS-01 1 IXJ / 3-SI-136 / SW-8 PIPE-ELBOW 11715-WMKS-0 111 XK / 3-SI-171 / SW-48 PIPE-TEE 11715-WMKS-0 111 XK / 3-SI-23 / SW-65 PIPE-ELBOW 11715-WMKS-01 11XK I 3-SI-23 / SW-67 PIPE-ELBOW 1 1715-WMKS-0111 XK / 6-SI-169 / SW-39 PIPE-TANK 11715-WMKS-0 111 XK / 6-SI-i170/ SW-38 PIPE-TANK 11715-WMKS-01 1 XM / 3-SI-137 / A-525 SUPPORT 11715-WMKS-0 111 XM I 3-SI-160 / A-142 SUPPORT 11715-WMKS-01 11XM I 3-SI-56 / A-527 SUPPORT 1 1715-WM KS-01 11XM / 4-SI-159 I SW-51 PIPE-REDUCER 11715-WMKS-SI-P-1BI 1-SI-P-1B / H-603A SUPPORT 11715-WMKS-SI-P-1 B / 1-SI-P-1 B I H-603B SUPPORT 11715-WMKS-SI-TK-2 /1-SI-TK-2 /1 HEAD-TO-SHELL WELD 11715-WMKS-SI-TK-2 1-SI-TK-2 /2 SHELL-TO-HEAD WELD 11715-WMKS-SI-TK-2 1-SI-TK-2 /3 NOZZLE-SHELL 11715-WMKS-SI-TK-2 1-SI-TK-2 /4 NOZZLE-SHELL 11715-WMKS-SI-TK-2 1-SI-TK-2 / LEG-1 SUPPORT 11715-WMKS-SI-TK-2 /1-SI-TK-2 / LEG-2 SUPPORT 11715-WMKS-SI-TK-2 /1-SI-TK-2 / LEG-3 SUPPORT 11715-WMKS-SI-TK-2 1-SI-TK-2 / LEG-4 SUPPORT 11715-WMKS-SI-TK-2 / -SI-TK-2 / I01 MANWAY BOLTING 11715-WMKS-SI-TK-2 1-SI-TK-2 / S02 MANWAY BOLTING 11715-WMKS-SI-TK-2 / -SI-TK-2 / S03 MANWAY BOLTING 11715-WMKS-SI-TK-2 1-SI-TK-2 / S04 MANWAY BOLTING 11715-WMKS-SI-TK-2 /1-SI-TK-2 / S05 MANWAY BOLTING 11715-WMKS-SI-TK-2 / -SI-TK-2 / S06 MANWAY BOLTING 11715-WMKS-SI-TK-2 / -SI-TK-2 / S07 MANWAY BOLTING 1 1715-WMKS-SI-TK-2 / -SI-TK-2 / S08 MANWAY BOLTING 1 1715-WMKS-SI-TK-2 /1-SI-TK-2 / S09 MANWAY BOLTING 11715-WMKS-SI-TK-2 1-SI-TK-2 / 10 MANWAY BOLTING NAPS Ul 14-ISI Plan 9-33 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 2 11715-WMKS-SI-TK-2 / 1-SI-TK-2 / S11 MANWAY BOLTING 2 11715-WMKS-SI-TK-2 / 1-SI-TK-2 / S12 MANWAY BOLTING 2 11715-WMKS-SI-TK-2 I 1-SI-TK-2 /S 13 MANWAY BOLTING 2 11715-WMKS-SI-TK-2 / 1-SI-TK-2 / S14 MANWAY BOLTING 2 11715-WMKS-SI-TK-2 I 1-SI-TK-2 /S 15 MANWAY BOLTING 2 11715-WMKS-SI-TK-2 I 1-SI-TK-2 / 16 MANWAY BOLTING 2 11715-WMKS-SI-TK-2 / -SI-TK-2 /WS-1 INTERGAL ATTACHMENT WELD 2 11715-WMKS-SI-TK-2 / 1-SI-TK-2 / WS-2 INTERGAL ATTACHMENT WELD 2 11715-WMKS-SI-TK-2 /I1-SI-TK-2 / WS-3 INTERGAL ATTACHMENT WELD 2 11715-WMKS-SI-TK-2 I 1-SI-TK-2 / WS-4 INTERGAL ATTACHMENT WELD 2 11715-WMKS-0102A 16-WFPD-24 17H INTERGAL ATTACHMENT WELD 2 11715-WMKS-0102A / 16-WFPD-24 59 PIPE-ELBOW 2 11715-WMKS-01 02A/ 16-WFPD-24 9A PIPE-NOZZLE 2 11715-WMKS-0102A I 16-WFPD-24 HSS-200 STD-SKS-WELD 2 11715-WMKS-0102A / 16-WFPD-24 HSS-201 STD-SKS-WELD 2 11715-WMKS-0102A / 16-WFPD-24 R-33 FAB-VC-WELD 2 11715-WMKS-01 02A /16-WFPD-24 SH-30 STD-SH-WELD 2 11715-WMKS-0102A / 16-WFPD-24 SW-35 INTERGAL ATTACHMENT WELD 2 11 715-WM KS-0102A I 16-WFPD-24 SW-41 PIPE-ELBOW 2 11715-WMKS-0102A / 16-WFPD-24 SW-49 INTERGAL ATTACHMENT WELD 2 11715-WMKS-0102B I 16-WFPD-23 I 16A PIPE-ELBOW 2 11715-WMKS-0102B / 16-WFPD-23 /54 PIPE-ELBOW 2 11715-WMKS-0102B / 16-WFPD-23 / HSS-212 STD-VSS-WELD 2 11715-WMKS-0102B / 16-WFPD-23 / R-38A FAB-NS EW-MECH 2 11715-WMKS-0102C / 16-WFPD-22 /14 PIPE-PIPE 2 11715-WM KS-0102C / 16-WFPD-22 I 18A PIPE-NOZZLE 2 11715-WM KS-0102C / 16-WFPD-22 /23 PIPE-ELBOW 2 11715-WMKS-0102C / 16-WFPD-22 I SH-43 STD-CS-MECH 2 11715-WMKS-0102C I 16-WFPD-22 / SW-39 PIPE-PIPE 2 11715-WMKS-FW-CKVALV / 16-WFPD-24 / 1-FW-47 VALVE BOLTING Bolting 3 11715-FV-9A / 1-CC-TK-1 / A-TK1 SUPPORT 3 11715-WMKS-0103B / 18-CC-329 / 13H INTEGRALLY ATTACHED WELD NAPS Ul 14-ISI Plan 9-34 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 3 11715-WMKS-0103B / 18-CC-329 / R-32C FAB-VC-MECH 3 11715-WMKS-0103E / 18-CC-327 / 51H INTEGRALLY ATTACHED WELD 3 1 1715-WM KS-0103E / 18-CC-327 / 53H INTEGRALLY ATTACHED WELD 3 11715-WM KS-0103E /18-CC-327 / R-32C SUPPORT 3 11715-WMKS-0103J / 18-CC-331/ R-152 SUPPORT 3 11715-WMKS-01 18A /8-CC-10/ R-36 SUPPORT 3 11715-WMKS-01 18A / 8-CC-10 / R-37 SUPPORT 3 11715-WMKS-01 I18A / 8-CC-U10 S-36A SUPPORT 3 11715-WMKS-01 18C / 24-CC-5/ A-7 SUPPORT 3 11715-WMKS-01 18C / 24-CC-5 / HSS-41 1 SUPPORT 3 11715-WMKS-0118D / 18-CC-32 / 10H INTERGAL ATTACHED WELD 3 11715-WMKS-0118F /8-CC-14 /2H INTERGAL ATTACHED WELD 3 11715-WMKS-01 18F / 8-CC-14 / 8H INTERGAL ATTACHED WELD 3 11715-WMKS-01 18F / 8-CC-14 / R-145 SUPPORT 3 11715-WMKS-01 18J / 1-CC-E-1A / A-272 SUPPORT 3 11715-WMKS-0118J / 1-CC-E-1A/ R-259 SUPPORT 3 11715-WMKS-0118J / 1-CC-E-1A/ R-291 SUPPORT 3 11715-WMKS-01 18J / 1-CC-E-1A / WS-1 INTERGAL ATTACHED WELD 3 11715-WMKS-01 18J / 1-CC-E-1A / WS-2 INTERGAL ATTACHED WELD 3 11715-WMKS-01 18J / 1-CC-E-1A / WS-3 INTERGAL ATTACHED WELD 3 11715-WMKS-01 18J / 1-CC-P-1A / A-P1A SUPPORT 3 11715-WMKS-0118N-3 / 24-CC-17 / 14H INTERGAL ATTACHED WELD 3 11715-WMKS-0118R / 12-CC-31 / A-124 SUPPORT 3 11715-WMKS-01 18XR / 6-CC-398 / 30H INTERGAL ATTACHED WELD 3 11715-WMKS-01 18XR / 6-CC-398 / A-378 SUPPORT 3 11715-WMKS-01 18XR / 6-CC-398 / R-361 SUPPORT 3 1 1715-WMKS-01 18XT / 6-CC-397 / R-376 SUPPORT 3 11 715-WMKS-01 18ZA / 10-CC-B-51 / SH-380 SUPPORT 3 11715-WMKS-CH-E-2 / 1-CH-E-2 / SUPT-C SUPPORT 3 11715-WMKS-CH-E-2 / 1-CH-E-2 / SUPT-D SUPPORT 3 11715-WMKS-CH-E-2 / 1-CH-E-2 / SUPT-UPPER SUPPORT 3 11715-WMKS-CH-E-2 / 1-CH-E-2 / WS-3 INTERGAL ATTACHED WELD NAPS IT] 14-TST Plan 9-35 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-CH-E-2 I 1-CH-E-2 I WS-4 INTERGAL ATTACHED WELD 1 1715-WMKS-CH-E-2 I 1-CH-E-2 / WS-5 INTERGAL ATTACHED WELD 11715-WMKS-CH-E-2 /I 1-CH-E-2 / WS-6 INTERGAL ATTACHED WELD II715-WMKS-CH-E-2 I 1-CH-E-2 I WS-7 INTERGAL ATTACHED WELD 11715-WMKS-CH-E-4 I 1-CH-E-4 / SUPT-FRONT SUPPORT 11715-WMKS-CH-E-4 1-CH-E-4 / SUPT-REAR SUPPORT 11715-WMKS-CH-E-4 I 1-CH-E-4 / WS-1 WELDED SUPPORT FOR SUPT-F 11715-WMKS-CH-E-4 I 1-CH-E-4 / WS-2 WELDED SUPPORT FOR SUPT-R 11715-WMKS-01 17A / 0-FC-6 / 20H INTERGAL ATTACHED WELD 11715-WMKS-0117A/ 12-FC-8 /SH-100 SUPPORT 11715-WMKS-RH-E-1 A/ 1-RH-E-1A / SUPT-UPPER SUPPORT 3 11715-WMKS-0121K / 6-RP-I'/ R-16 SUPPORT 3 11715-WMKS-0121K / 6-RP-1 I R-999C SUPPORT 3 1 1715-WMKS-0121K / 6-RP-1 / RH-155 SUPPORT 3 11715-WMKS-0107J I 1-RS-P-3B I A-P-3B SUPPORT 3 11715-WMKS-0107J / 6-RS-E-23 I 97H INTERGAL ATTACHED WELD 3 1 1715-WMKS-0107J / 6-RS-E-23 I R-7 SUPPORT 3 11715-WM KS-0107J / 6-RS-E-23 / SH- 10 SUPPORT 3 11715-WMKS-0107L I 1-RS-P-3A I A-P-3A SUPPORT 3 1 1715-WMKS-0107L / 6-RS-E-15 / 48H INTERGAL ATTACHED WELD 3 1 1715-WMKS-0107GA / 8-SHP-76 / 3H INTERGAL ATTACHED WELD 3 11715-WMKS-0107GA/ 8-SHP-76 / R-176 SUPPORT 3 11715-WM KS-0107GA / 8-SHP-77 / R-180 SUPPORT 3 11715-WMKS-0102FA / 6-WAPD-2 I 38H INTERGAL ATTACHED WELD 3 11715-WMKS-0102FA / 6-WAPD-2 / A-17 FAB-ANC-WELD 3 11715-WMKS-0102FC I 6-WAPD-2 / 66H INTERGAL ATTACHMENT WELD 3 11715-WMKS-0102FG / 4-WAPD-39 / 30H INTERGAL ATTACHMENT WELD 3 11715-WMKS-0102FH / 2-WAPD-19 I R-3 FAB-VC LC-MECH 3 11715-WMKS-0107GE-1 / 3-WAPD-9 / R-1 F SUPPORT 3 11715-WMKS-0107GE-1 / 3-WAPD-9 / R-1G SUPPORT 3 11715-WMKS-0107GE-1 I 3-WAPD-9 I R-1L SUPPORT 3 11715-WMKS-01 07GE-1 / 3-WAPD-9 / R-53A SUPPORT NAPS UI 14-ISI Plan 9-36 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Comp6nent Identification Description 3 11715-WMKS-0107GE-2 / 3-.WAPD-9 / R-191A SUPPORT 3 11 715-WMKS-0107GF-1 I 3-WAPD-1 1 I 42J INTERGAL ATTACHMENT WELD 3 11715-WMKS-0107GF-1 I 3-WAPD-11 I SFP-99 SUPPORT 3 11715-WMKS-0107GF-2 I 3-WAPD-1 / R-185B SUPPORT 3 11715-WMKS-0107GG-1 / 3-WAPD-13 / A-1C SUPPORT 3 11715-WMKS-0107GG-1 I 3-WAPD-13 I R-1P SUPPORT 3 11715-WMKS-0107GG-1 / 3-WAPD-13 / R-51C SUPPORT 3 11715-WMKS-0107GG-1 / 3-WAPD-13 / R-52C SUPPORT 3 11715-WMKS-0102E-1 / 8-WCMU-5 / R-2 FAB-VC-MECH 3 11 715-WMKS-0107GB / 6-WCMU-12 / R-53 SUPPORT 3 11 715-WM KS-0107GC I 6-WCM U- 12 I R-179 SUPPORT 3 11715-WM KS-0102FB 1-FW-P-3A / A-P-3A FAB-ANC-MECH 3 11715-WMKS-0102FG / 1-FW-P-2 / A-P-2 FAB-ANC-MECH 3 11715-WMKS-0105A/24-WS-101 /41H INTERGAL ATTACHMENT WELD 3 11715-WM KS-0105A /24-WS- 101 /46H INTERGAL ATTACHMENT WELD 3 11715-WMKS-0105A / 24-WS-101 / R-7 SUPPORT 3 11715-WMKS-0105AMA 24-WS-D-78 / PH-9032 SUPPORT 3 11715-WMKS-01 05AMA 24-WS-D-89 I PH-9019 SUPPORT 3 11715-WMKS-0105AMA 36-WS-D-73 I 54H INTEGRALLY ATTACHED WELD 3 11 715-WMKS-0105AMB 18-WS-D-95 I 3H INTERGAL ATTACHMENT.WELD 3 11715-WMKS-0105AMB 18-WS-D-95 / PH-9006 SUPPORT 3 11715-WMKS-0105AMB 18-WS-D-95 I PH-9041 SUPPORT 3 11715-WMKS-0105AMB 18-WS-D-96 I PH-9038 SUPPORT 3 11715-WMKS-0105AMB 24-WS-D-85 I PH-9023 SUPPORT 3 11715-WM KS-0105AMB I 36-WS-D-86 / PH-9022 SUPPORT 3 11715-WMKS-0105ARB-3 / 12-WS-E07 / PH-6019 SUPPORT 3 11715-WMKS-0105ARB-3 / 18-WS-D95 / PH-6026 SUPPORT 3 11715-WMKS-0105ARB-3 I 6-WS-187 / PH-6024 SUPPORT 3 11715-WM KS-0105ARC- 1 I 18-WS-D-82 / PH-3035 SUPPORT 3 11 715-WM KS-0105B / 24-WS-95 / 14H INTERGAL ATTACHMENT WELD 3 11715-WMKS-0105B / 24-WS-95 / R-13 SUPPORT 3 11715-WMKS-0105B / 24-WS-95 I R-14 SUPPORT NAPS UI 14-ISI Plan 9-37 Revision 0
NORTH ANNA POWER STATION, UNIT 1-FOURTH INSPECTION INTERVAL Classification and Identification of Components ASME Class Component Identification Description 11715-WMKS-0105C /I 1-SW-P-1A / A-P-1A SUPPORT 11 715-WM KS-0105C I 1-SW-P-lA / R-330D SUPPORT 11715-WMKS-0105C / 20-WS-5 I 43H INTERGAL ATTACHMENT WELD 11715-WMKS-0105C / 20-WS-5 I A-29 SUPPORT 11715-WMKS-0105C I 20-WS-7 I A-27 SUPPORT 11715-WMKS-0105D 1-SW-P-4 / A-P-4 SUPPORT 11715-WMKS-0105H-1 / 16-WS-38 / R-81 SUPPORT 11715-WMKS-0105H-1 I 16-WS-41 /R-317 SUPPORT 11715-WMKS-0105H-2 / 16-WS-39 / 62H INTERGAL ATTACHMENT WELD 11715-WM KS-0105H-2 I 16-WS-40 I R-84 SUPPORT S11715-WM KS-0105J- 1 / 16-WS-30 I SH-303 SUPPORT 11715-WM KS-0105J- 1 I 24-WS-28 / R-99 SUPPORT 11715-WMKS-0105J-2 I 24-WS-27 I R-1 11 SUPPORT 11715-WMKS-01 05R / 24-WS-48 / R-332 SUPPORT 1 1715-WMKS-01 18K-i I 1O-WS-20 I 15H INTERGAL ATTACHMENT WELD 11 715-WMKS-01 18K-1 I 1O-WS-20 / A-36 SUPPORT 11715-WMKS-0118N-1 / 1O-WS-22 I R-65 SUPPORT NAPS U1 14-ISI Plan 9-38 Revision 0