Text

App B to Ginna Nuclear Power Station Inservice Insp Program for 1990-1999 Interval.
	ML17261A900
Person / Time
Site:	Ginna
Issue date:	07/20/1989
From:	Anderson C; ROCHESTER GAS & ELECTRIC CORP.
To:	;
Shared Package
ML17261A898	List: ML17261A897; ML17261A900; ML17261A901;
References
	PROC-890720, NUDOCS 8907260180
	Download: ML17261A900 (460)
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{{#Wiki_filter:h i)i-SgP REV. PA/(. Qf: ij QUALITY ASSURANCE MANUAL 0 GINNA STATION EFFECTIVE DATE: January 1, 1'990 OCHESTER GAS & ELECTRIC CORPORATiON SIGNATURE DATV TITLE: PREPARED SY: APPENDIXRB GINNA NUCLEAR POWER STATION QUALITY ASSURANCE INSERVICE INSPECTION PROGRAM REVIEW . FOR THE 1990-1999.-INTERVAL l APPROVED '80:

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1.0 INTRODUCTION

L 1.1 General 1.2 Appl'icable Documents 1.2.1 ASME Boiler and Pressure Vessel Code 1.2.2, US Nuclear Regulatory Commission Re@. Guides 1.2.3 ASME Code Cases 1.'.2.3.1; USNRC Reg', Guide -1.147-Approved ASME Section XI* . -! '- 1.2.4 R.E. Ginna Updated Final S'afety Analysis Report (UFSAR) 1.2.5 Letter dated March 23, 2981, from D.G. Eisenhut 1.2.6 USAS B31.1.0-1967 "Power Piping" for High Energy! 1 2 7

              ~  ~     R.E. Ginna Technical Specification 4.2 1.2.8      R.E. Ginna Technical Specification 3.13 "Snubbers".

1.2.9 Letter Dated February 16, 1989 to Carl Stahle 1.2.10 RG&E ME-256 "Snubber Inspection and Test Program" 1:3 Inspection Intervals 1.4 Classification of Components 1.5 Responsibility 1.6 Records 1.7 Examination Methods 1.7.1 Visual Examination Method I 1.7.2 Surface Examination Method 1.7.3 Volumetric Examination Method 1.7.4 Alternative Examination Method

1. 7. 5 Evaluat;ion of Results 1.8 Repair Requirements 1.8.1 Performance of Repair 1.8.2 Examination/Test for Repairs 1.8.3 Surface Defects 1.9 Replacement Requirements 1.9.1 Replacement Performance 1.9.2 Alternatives 1.9.3 Examination/Test 1.9.4 Reports and Records 8907260180 89072i PDR ADOCK 05000244 9 PDC

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TITLEt REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 2 ill Table o Contents Con't 1.10 System Pressure Testing 1.10.1 General Requirements 1.10.2 Type of Pressure Tests 1.10.2.1 Leakage Pressure Test 1.10.2.2 Functional Pressure Test 1.10.2.3 Inservice Pressure Test 1.10.2.4 Hydrostatic Pressure Test 1.10.2.5 Pneumatic Pressure Test 1.10.2.6 Repair/Replacement Pressure Test 1.10.3 Examination Requirements 1.10.4 Test Requirements 1.10.4.1 General 1.10.4.2 Leakage Pressure Test Requirements 1.10.4.3 Functional. Pressure Test Requirements 1.10.4.4 Inservice Pressure Test Requirements 1.10.4.5 Hydro Pressure Test Requirements 1.10.4.6 Test Pressure Requirements for each Code Class 1.10.5 Test Implementation 1.10.6 Scheduling 1.11 Snubber Inspection and Test Program 1.11.1 General Requirements 1.11.2 Visual Inspections 1.11.3 Functional Tests 1.11.3.1 Functional Test Acceptance Criteria

                  '1.11.3.2 Functional Test Failure Analysis 1.11.3.3 Snubber Seal Services Life Monitoring 1.12 Steam Generator Tubes and Tube Sleeve Combinations 1.12.1 Repair Criteria for Steam Generator Tubes 1.12.2   Reporting 2.0  CLASS 1 PROGRAM PLAN 2.1  Basis  for Preparation 2.2  Components Subject to Examination 2.3  Extent and Frequency of Examinations 2.4  Exemption   Criteria 2.5  Examination of Reactor Coolant Pump Flywheels 2.6  Inservice Inspection Program Plan

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TITLE: REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION 0 MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 3.0 CLASS 2 PROGRAM PLAN 3.1 Basis for Preparation 3.2 Components Subject to Examination 3.3 Extent and Frequency of Examinations 3.4 Exemption Criteria 3.5 Inservice Inspection Program Plan 4.0 CLASS 3 PROGRAM PLAN 4.1 'asis for Preparation 4.2 Components Subject to Examination 4.3 Extent and Frequency of Examinations 4.4 Exemption Criteria 4.5 Inservice Inspection Program Plan 5.0 CLASS 1, CLASS 2 & CLASS 3 COMPONENT SUPPORTS 5.1 Basis for Preparation 5.2 Components Subject to Examination 5.3 Extent and Frequency of Examinations 5.4 Exemptions 5.5 Inservice Inspection Program Plan 6.0 AUGMENTED INSERVICE INSPECTION PROGRAM PLAN 6.1 Basis For Examination 6.2 Inservice Inspection Program Plan ~ 6.3 Welds Subject to Examination 6.4 Evalmation 7.0 RELIEF REQUESTS

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TITLEi REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 4 111 TABLES: Code Table Class 1 Components Code Table Class 2 Components Code Table Class 3 Components Code Table Class 1,2 and 3 (IWF) Support Components Safety Related Snubbers High Energy Welds Relief Request Summary ATTACHMENTS: Line Lists Class 1 Systems Class 2 Systems Class 3 Systems ISI P & ID Drawings Class-1 Non-exempted Systems Class 2 Non-exempted Systems Class 3 Non-exempted Systems Exempted System Drawings Allocation Tables Class ."1 Components Class 2 Components Class 3 Components SUPPLEMENT 1 TO APPENDIX B

Inservice Inspection Program Plan

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TITlE: REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 5 111

1.0 INTRODUCTION

General This appendix to the Quality Assurance Manual outlines the third interval inservice inspection examination (ISI) requirements for Class 1, Class 2, Class 3 systems and components for Rochester Gas & Electric, Corporation's (RGGE) R.E. Ginna Nuclear Power Station (Ginna Station). The third inspection interval begins on January 1, 1990, as permitted by Paragraph IWA-2400 of ASME Code Section XI, the second interval concluded at the end of December 1989. 1.1.1 This program was developed in accordan'ce with the documents identified in Section 1.2 and provides summary information outlining the ISI program for R.E. Ginna for the third inspection interval. This information includes: a~ Class 1, Class 2, and Class 3 systems, Component Supports, High Energy Piping Outside of Containment, Snubbers, Steam Generator Tubes and Tube Sleeve Combinations, Reactor 'Coolant Flywheels and System Pressure Testing'.

b. 'SME Section XI examination requirements of Subsections IWA, IWB, IWC, IWD, IWF. Inservice Testing of pumps (IWP) and valves (IWV) is performed in accordance with Appendix C of the Ginna Station Quality Assurance Manual.

Inservice Inspection and Testing of snubbers is performed in accordance with 1.11 and 5.0 of this Appendix; c ~ Method and extent of nondestructive examinations

d. Exemptions

e. Relief requests Regulatory Guides gi Code Cases

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TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 6 111

h. Special requirements 1' ' This program is based on the requirements of the 1986 Edition of the American Society for Mechanical Engineers (ASME) Boiler and Pressure Vessel Code, Section XI, Inservice Inspection of Nuclear Power Plant Components" as adopted by the Code of the Federal Regulations, 10 CFR Part 50, May 5, 1988.

1. 1.3 This program excludes the controls of the Authorized Nuclear Inservice Inspector, Enforcement Authority, Reporting System and N-Stamp.

1.2 Applicable Documents RG&E has adopted the following documents as the basis for the third inspection interval and is committed to satisfying their requirements. Any exceptions to these documents are identified and located in the "Relief Requests", Section 7.0 of this document. This program was developed in accordance with these documents: 1~2~1 ASME Boiler and Pressure Vessel Code Section XI, "Rules for Inservice Inspection of Nuclear Power Plant Components," 1986 Edition. 1.2 ' U.S. Nuclear Regulatory Commission (USNRC) Regulatory Guides a~ 1.14, Rev. 1, "Reactor Coolant Pump Flywheel Integrity"

b. 1.147, Latest Revision, "Inservice Inspection Code Case Acceptability ASME Section XI, Division 1" Co 1.150, Rev. 1, "Ultrasonic Testing of Reactor Vessel Welds During Preservice and Inservice Examinations"

d. 1.83, Rev. 1, "Inservice Inspection of Pressurized Water Reactor Steam Generator Tubes

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TITlE: REY, QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 7 111 1.2.3 ASME Code Cases In accordance with 10CFR50.55a, Footnote 6, ASME Section XI Code Cases referenced in Regulatory Guide 1.147, "Inservice Inspection Code Case Acceptability-ASME Section XI, Division 1," may be incorporated into the R.E. Ginna ISI Program. Those Code Cases incluled in Regulatory Guide 1.147 that will be implemented at R.E. Ginna are identified in this section. Each Code Case is preceded by information on the applicable component/area, ASME requirements, and how the Code Case will be implemented. Paragraph 1.2.3.1 lists those code cases that have been technically reviewed and endorsed, with our without conditions by the NRC in Regulatory Guide 1.147 and will be implemented during the 1990-1999 Inspection Interval. Use of any subsequent NRC endorsed code cases that are identified in revisions to the Regulatory Guide 1.147 may be incorporated in the program and used during the 1990-1999 Inspection Interval. 1.2.3.1 USNRC Regulatory Guide 1.147 Approved ASME Section XI Code Cases Code Case No. Sect. XI References Com onent Area N 307-1 IWB-2500-1 Studs and Bolts with Heater Holes N-416 IWA-4400 'Any repaired or replaced Class 2 piping component that cannot be isolated by valves or requires securing safety/ relief valves. N-401 IWA-2233 Eddy Current Examinations

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TITLEt RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL OF 8 111 Code Case No. Sect. XI References Com onent Area N-402 IWA-2233 Eddy Current Calibration Standard Material N-427* Code Cases Code Cases in inspection plans. N-437 IWA-5260 Pressure Measuring Instrumentation used during Class 1, 2,and 3 Pressure Tests. As amended by USNRC Regulatory Guide 1.147, May 1988. 1.2.4 R.E. Ginna Updated Final Safety Analysis Report (UFSAR) Section 5.4 For Class 1 Section 6.6 For Class 2 and 3 1.2.5 Letter dated March 23, 1981, from Darrell G. Eisenhut, Director, Division of Licensing, USNRC, regarding Technical Specification Revisions for Snubber Surveillance A 1.2.5.1 First Addeneda to ASME/ANSI OM-1987, Part 4 Published in 1988. 1.2.6 USAS B31.1.0-1967, "Power Piping" for High Energy Systems 1.2.7 R.E. Ginna Technical Specification 4.2. "Inservice Inspection". 1.2.8 R.E. Ginna Technical Specification 3.13 and 4.14 "Snubbers". 1.2.9 Letter dated February 16, 1989, to Mr. Carl Stahle, USNRC, PWR Project Directorate No. 1, regarding proposed changes to Snubber Technical Specification R.E. Ginna Nuclear Power Plant Docket No. 50-244.

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TITlE: REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 9 111 1.2.10 Rochester Gas and Electric Corporation Mechanical Engineering Specification, ME-256, Titled "Snubber Inspection and Test Program". 1' Inspection Intervals 1 ~ 3.1 The inservice inspection intervals for Class 1 components started on January 1, 1970, with the second interval staring on January 1, 1980. The third inspection interval shall start on January 1, 1990. 1.3.2 For Class 2 and Class 3, the first inspection interval started on May 1, 1973; the second on January 1, 1980; and the third shall start on January 1, 1990. The fourth inspection interval for Class 1, Class 2 and Class 3 will follow on January 1, 2000, in accordance with the edition of Section XI applicable at that time. 1' ' A 10-year examination plan (Supplement to Appendix B), will describe the distribution of examinations for Class 1, Class 2, and Class 3 components in accordance with the IWB-2400, IWC-2400, IWD-2400 and IWF-2400 of Section XI, "Rules for Inservice Inspection of Nuclear Power Plant Components," 1986 edition. 1 '.4 As allowed by IWA-2430 each decreased inspection interval may be or extended (but not cumulatively) by as much as one year. If R.E. Ginna is out of service continuously for 6 months or more, the inspection interval and associated period during which the outage occurred may be extended for a period of time ecpxivalent to'the outage. 1.4 Classification of Components The Program Plan components and piping have been classified by RG&E for purposes of inservice inspection based on definitions contained in 10CFR50.2 and in Article IWA-9000 of Section XI.

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TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL OF 10 111 1.5 Responsibility As specified in Paragraph IWA-1400 of ASME Section XI, RGGE bears the overall responsibility for implementation of an ISI program. Administrative Procedures, NDE Procedures, ISI Plans and Schedules are in place to control and implement these inservice inspection requirements. 1.6 Records Examination records and documentation of results provide the basis for evaluation and facilitate comparison with previous results and subsequent inspections. In accordance with Section XI, IWA-6000, these records will be maintained for the plant life. 1' Examination Methods Examination methods which will be used to satisfy Code examination requirements have been listed for nonexempt Class 1, Class 2, and Class 3 components, as applicable. Provided below is a brief explanation of the examination methods which will be performed to satisfy the Code requirements. Personnel performing nondestructive examinations will be qualified in accordance with written procedures prepared as required by Paragraph IWA-2300 of Section XI. Methods of examination are also described in the applicable sections of this Inservice Inspection Program. 1 ' ' Visual Examination Method Visual examinations (VT) will be performed in accordance with IWA-2210 of ASME Section XI. IWA-2210 defines the three types of VT examinations as follows:

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TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 11 111 r 1.7. 1. 1 VT-1 examinations are conducted to determine the condition of the part, component or surface examined. The examination shall determine conditions such as cracks, wear, corrosion, erosion, or physical damage on the surfaces of the part or components. This type of examination may be performed by direct or remote methods as defined in IWA-2211. 1 ~ 7.1 ~ 2 VT-2 examinations are conducted to detect leakage (or abnormal leakage) from pressure-retaining components during system pressure or functional tests as defined in IWA-2212. 1.7.1.3 VT-3 examinations are conducted to determine general

           'mechanical and structural conditions of components and their supports such as the presence of loose parts, debris, or abnormal corrosion products, wear, erosion, corrosion, and the loss of integrity at bolted or welded connections. Examinations are also conducted to determine conditions related to operability of components or devices, such as mechanical and hydraulic snubbers, components, supports, pumps, valves and spring-loaded and constant-weight hangers.

1.7.2 Surface Examination Method 1~7~2~1 A surface examination is performed to detect the presence of discontinuities open to the surface of a material. Techniques for surface examination include either magnetic particle (MT) or liquid penetrant (PT) methods. Surface examinations will be conducted as defined in IWA-2220. 1.7.3 Volumetric Examination Method 1-7-3 1 A volumetric examination is performed to detect the presence of discontinuities in the volume of a material. Such volumetric examinations include radiographic (RT), ultrasonic (UT), and eddy current (ET). Volumetric examinations will be conducted as defined in IWA-2230. 1~7 ~ 3'2 Radiography may be performed by utilizing either x-ray or gamma ray techniques.

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TITlE: RE V. QUALITY APPENDIX B ASSURANCE GINNA, NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION 1990-1999 INTERVAL FOR THE 12 ill 1.7.3.3 The UT examinations may be performed by utilizing either manual or mechanized UT (Mech UT) techniques in accordance with Appendix I of Section XI and Regulatory Guide 1.150, Rev.1 for the Reactor Vessel Examination only. 1.7.3.4 The ET Method will be utilized in the examination of heat exchanger tubing in accordance with Appendix IV and USNRC Regulatory Guide 1.83. 1.7.4 Alternative Examination Methods 1.7.4.1 Alternative examination methods may be performed to those described in 1.7.1, 1.7.2 and 1.7.3 as allowed in IWA-2240. These may include such things as newly developed techniques, provided that these alternative methods are shown by practical demonstration to be equivalent or superior to those of the specific method to the satisfaction of the Level III NDE Examiner. 1.7.5 Evaluation of Examination Results 1.7.5. 1 The evaluation of nondestructive examination results shall be in accordance with Article IWA-3000 of Section XI. All reportable indications will be subject to comparison with previous data to aid in cham'acterization and determination of origin. Class 1 components containing relevant .conditions will be considered acceptable for continued service providing an analytical evaluation performed demonstrates the component's acceptability and is subsequently examined in accordance with the requirements of IWB-3142.4 and IWB-3144(b). All other components containing relevant conditions will be considered acceptable for continued service providing an evaluation demonstrates the component's acceptability and is subsequently examined in accordance with IWC-3132.3 and IWC-3134(b).

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TITLEt RE V. QUALITY APPENDIX B,, ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 13 111 1.8 Repair Requirements The repair requirements of this program are applicable to Class 1, 2, 3, high energy piping systems, snubbers and supports as governed by 1.11 and 5.0 of this program. 1.8.1 Performance of Repair Repairs shall be performed in accordance with the requirements of IWA-4000 and IWF-4000 of ASME Section XI, 1986 Edition or later Edition/Addenda that is approved via 10CFR50.55a. Alternatively, repairs may be performed either to the requirements of the original Construction Code, which the component or was fabricated to, or to later approved 'ystem editions of the Construction Code, or later approved editions of ASME Section III along with any Code Cases approved via Regulatory Guide 1.147. 1 '.2 Examination/Test for Repairs 1.8.2.1 Applicable examination requirements of the Construction Code shall be met with the minimum requirement that new welds on pressure retaining components greater than 2 inches in diameter shall receive both surface and 100% volumetric examinations; or surface examination on pressure retaining components less than 2 inches in diameter. Examinations and testing of snubbers and supports that have been repaired shall be performed in accordance with 1.11 and 5 of this program. 1.8.2.2 The examination shall include the method that detected the flaw, if applicable. 1.8.2.3 Applicable examination requirements of ASME Section XI 1986 Edition shall also be met to serve as a new PSI baseline for future ISI examinations, unless the examination performed under paragraph 1.8.2.1 was conducted under conditions and with equipment and techniques equivalent to those required by Section XI.

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TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 14 111 1.8.2.4 A hydrostatic test, shall be performed in accordance with ASME Section XI, 1986 Edition, unless specifically exempted by Section XI Article IWA-4400 or Code Case N-416. 1.8.3 Surface flaws in Class 1, 2, or 3, bolts, studs, nuts and ligaments may be removed by mechanical means provided the removal of that flaw does not alter the basic configuration of the item. Bolts, studs, and nuts that have flaws that cannot be removed by mechanical means shall be replaced or reported for evaluation as indicated by Section XI Article IWA-3100. 1.9 Replacement Requirements Replacement requirements are applicable to Class 1, 2 and 3 and high energy pressure retaining components and piping systems and their supports, unless specifically exempted by ASME Section XI, 1986 Edition, Article IWA-7400. 1.9.1 Replacement Performance Replacements shall meet the requirements of ASME Section XI, 1986 Edition or a later Edition/Addenda approved via 10CFR50.55a. In addition, replacement items shall meet the requirements of the original Construction Code to which the original part was constructed. 1.9 '.1 A "Like" and "Kind" replacement is an item that meets the original requirements of the design and procurement documents for the item being replaced and does not require reconciliation, re-analysis or changes to the item's design and technical requirements. 1.9. 1. 2 An approved equivalent is a replacement that will result in a design or technical change to the original requirements based on reconciliation, re-analysis and/or testing per Paragraph 1.9.2.1.

TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE, GINNA STATION FOR THE 1990-1999 INTERVAL 15 111 1.9.2 Alternatively items used for replacement may meet all or portions of the requirements later additions of the Construction Code or Section III, when the construction code was not Section III. In order to use this alternate approach, the following additional requirements apply. 1.9.2. 1 Reconcile the requirements affecting the design, fabrication and examination of the replacement with the Design Analysis or Design Criteria or other methods of analysis that demonstrates the item is satisfactory for the specified design and operating conditions. 1.9.2.2 Mechanical interfaces, fits and tolerances that provide satisfactory performance are compatible with the system and component requirements. 1.9.2.3 Materials used are compatible with installation and system requirements. 1.9.2.4 If a replacement is because of a failure of the item being replaced, a design evaluation or analysis shall consider the cause of the failure and its impact on other similar items, and the necessary actions to be taken to preclude recurrence. 1.9.2.5 When welding is to be performed as part of the replacement, the rules of Section IX shall be followed to satisfy the requirements of IWA-7320 and,IWF-.7000. 1.9.2.6 Items identified in IWA 7400 will be exempt from the requirements of the replacement program. 1.9.3 Examination/Test'.9.3.1 The replacement item shall be examined and pressure tested in accordance with the Construction Code or it later Code provided. meets the requirements of 1.9.1 above. Snubbers shall be examined and tested in accordance to

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TITLE: REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 16 111 1.9.3.2 Where the attachment of the non-pressure-retaining item is welded to a pressure boundary, the weld shall be examined in accordance with the requirements of 1.8.2. 1.9.3.3 Applicable examination requirements of ASME Section XI, 1986 Edition shall also be met to serve as a new PSI baseline for future ISI examinations, unless the examination performed under 1.9.3.1 was conducted under conditions and with equipment and techniques equivalent to these required by Section XI. 1.9.3.4 Replacements installed by mechanical methods shall be pressure tested at nominal operating pressure, or for Class 1 systems, the pressure associated with 100% rated reactor power. 1.9.4 Reports and Records Reports and records to the extent required by the construction code and IWA 7520(a) (1 thru 7) as applicable for the replacement shall be completed for all replacements.

1. 10 System Pressure Testing

1. 10. 1 General Requirements 1.10.1.1 Pressure testing shall be conducted on all Class 1, 2, and 3 pressure retaining components in accordance with the requirements of Section XI Articles IWA-5000, IWC-5000, IWD-5000; and Section XI Table IWB-IWB-'000, 2500-1 Examination Category B-P, Table IWC-2500-1 Examination Category C-H, and Table 2500-1 Examination Category D-A, D-B and D-C.

In addition, "High Energy" Main Steam and Feedwater Piping shall also be pressure tested on these non-class systems in accordance with the rules of IWC-5000. 1.10.1.2 Pressure tests are conducted at normal operating pressure, or at a.pressure 104 to 254 above system pressure. The degree of pressurization and the test boundary depends upon the type of test being

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INSERVICE 'INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 17 '11 performed. A visual examination (VT-2 method) is performed in concert with the pressure test on pressure retaining components under test pressure.

Specific exceptions from achieving Section XI requirements are detailed in the Relief Request Section of this document.

1. 10.2 Type of Pressure Tests The various types of pressure tests which are required during the inspection interval are described in the following,:"

1.10.2.1. LEAKAGE PRESSURE TEST This test is limited to Class 1 systems, and is performed subsequent to refueling outages. The boundary subject to test pressurization and the associated VT-2 examination during a leakage pressure test. will extend to the pressure retaining components within the system boundary containing pressurized reactor coolant under the plant mode of normal reactor startup. 1.10.2.2 FUNCTIONAL PRESSURE TEST This test is limited to Class 2 and 3 systems and is performed once each inspection period. The boundary subject to test pressurization and the associated VT-2 examination during a system functional pressure test, will include only those pressure'etaining components within the system boundary pressurized under the test mode required during the performance of a periodic system/component'urveillance test. 1.10.2.3 INSERVICE PRESSURE TEST This test is limited to Class 2 and 3 systems and is performed once each inspection period. The. boundary subject, to a. test pressurization and th'e a'ssociated VT-2 examination during a system inservice pressure . test will include only those pressure retaining components under .operating pressure during normal system service.

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                       '-'ITLF REY, QUALITY                             APPENDIX B ASSURANCE                ;GINNA NUCLEAR POWER STATION MANUAL                    .INSERVICE INSPECTION PROGRAM      PAGE GINNA STATION           ; FOR- THE'990-1999 .INTERVAL 18    111 1.10.2.4     HYDROSTATIC PRESSURE TEST This test, is performed once each inspection interval.

The boundary subject to test pressurization and the associated VT-2 examination during a system hydrostatic pressure test includes all Class 1, 2 and 3 components and piping except as exempted by a relief request. 1.10.2.5 PNEUMATIC PRESSURE TEST This test is limited to Class 2 and 3 systems. The

           .boundary      limits subject to test pressurization and the associated VT-2 examination during a system pneumatic pressure test are the same as the associated inservice, functional or hydrostatic pressure test.

1.10.2.6 REPAIR/REPLACEMENT PRESSURE TESTS The boundary subject to test pressurization and the associated VT-2 examination is limited to the portion repaired or replaced, within the Class 1, 2 or 3 boundary. The specific type of pressure test is either a hydrostatic, pneumatic or a test at operating pressure such as the Leakage, Inservice or Functional. The specific type of test to be performed and the exemptions which apply to repair/replacement pressure testing are described in the Ginna Repair/Replacement program. 1.10.3 Examination Requirements

1. 10. 3. 1 During the conduct of pressure tests, certified VT-2 examination personnel, using RGGE approved NDE VT-2 examination procedure and the associated recording form, will examine the portions of piping under pressurization. The examination and test boundaries are depicted on the color-coded P&ID accompanying the associated test procedures. In some cases, the test.

boundary extends beyond the examination boundary due to valve location and/or check valve 'flow direction. In 'general, personnel will examine for evidence of leakage, inoperative leakage collection systems and evidence of corrosion.

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42 5RB TITLE: REV.. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 19 . 111 1.10.3.2 Insulation removal during the VT-2 examination is generally not required, however, in accordance with IWA-5242 (a) "systems borated for the purpose of controlling reactivity" shall have insulation removed at bolted connections during conduct of the VT-.2 examination. At Ginna, this requirement is considered to be applicable to borated lines only in the primary flow path of piping from the boric acid supply and CVCS Charging to the Reactor Vessel and return through CVCS Letdown, and is not applicable to branch lines connecting to the primary flow path. Because boric acid is not considered corrosive to austenitic stainless or high alloy materials, insulation removal is only applicable to bolted connections using carbon steel or low alloy bolting materials. In addition, this requirement is only applicable to those VT-2 examinations performed during a hydrostatic pressure test, since Leakage, Functional and Inservice tests are intended to be non-intrusive type tests. 1.10.4 Test Requirements 1.10.4.1 GENERAL The contained fluid in the system or fluid added to the system shall serve as the pressurizing or test medium. In steam systems either water or.air may be used. .Where air is used, the test procedures shall permit the detection and location of through wall leakages in components .of the system tested. The temperature of the test medium will be that of the available source unless otherwise specified by the implementing test procedure/document. The test medium will be of a quality which is equal to or better than the system operating medium. 1.10.4.1.1 During conduct of hydrostatic tests all

               .'ntrained,air will.be     vented from the system except in the following cases:

a. Atmospheric storage tanks

b. 0-15 psi storage tanks

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42 521 TITlE: REY, QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL 'INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 20 111 C~ Class.l'ystems where a mixture of steam, water and noncondensible gases are present in a proportion typical of normal startup conditions.

d. Normal steam systems 1.10.4.1.2 For Leakage, Functional and Inservice tests, the test instrumentation may be permanent plant installed instruments. For hydrostatic tests, any pressure measuring instrument or sensor, analog or digital, including the pressure measuring instrument of the normal operating system instrumentation (such-as. control room instruments) may be used provided the requirements of Section XI, IWA 5260 and Code Case 437 (" Pressure Measuring Instrumentation used during Class 1, 2, and 3 Pressure Tests" ), are met.

1.10.4.2 LEAKAGE PRESSURE TEST REQUIREMENTS The system leakage pressure test will be conducted at a test pressure which corresponds to the normal operating pressure seen by the system. The pressure and temperature will be attained at a rate in accordance with the heat-up limitations specified in the Ginna Technical Specifications for the component/piping system being tested. 1.10.4.3 FUNCTIONAL PRESSURE TEST REQUIREMENTS The system functional pressure test is normally performed during performance of a Periodic Surveillance Test (PT). The test is used to establish the test conditions, associated with normal system operating pressure and temperature, for performance of the system functional pressure test. 1.10.4.4 INSERVICE PRESSURE TEST'EQUIREMENTS I The operating pressure and temperature during normal system operation is used during performance of this test.

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42 528 TITLE: REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 21 111 1.10.4.5 HYDROSTATIC PRESSURE TEST REQUIREMENTS 1.10.4.5.1 General Test pressure requirements vary among each of the classifications. The minimum test pressure will be maintained for the entire duration of the test, with the exception of tests performed at temperatures greater than 200'F, where the examination phase may be performed at a lower pressure corresponding to 200'F. The test pressure shall not exceed the maximum allowable test pressure of any component within the test boundary. 1.10.4.5.2 The hydrostatic test pressure shall not exceed 106% of test pressure any where within the test boundary, except in cases where the high elevation and low elevation of the system/component cannot be isolated by an isolation valve; and where the pressure at the lowest elevation does not exceed the design pressure of the system/component. 1.10.4.6 The following sections list the test pressure requirements which will be met for each code classification: 1.10.4.F 1 Class 1 The system hydrostatic pressure test is conducted at a test pressure of 1.10 times the system nominal operating pressure (P.) that is associated with 1004 rated reactor power. When system hydrostatic pressure tests are performed at test temperatures (T,) in excess of 100'F the following table will be used to calculate the reduced test pressure. Note: Linear interpolation will be used and technical specification heatup/cooldown limits must be observed.

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TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 22 111 TABLE Test Tem erature Test Press. PSIG

                <199'F                             1.10  P, 200'F  299'F                     1.08  P, 3 00'F  3 99'F                   1.06  P, 4 00'F  499'F                    1.04  P, 500'F                             1.02  P, 1.10.4.6.2  Class   2  and 3 at    The   test pressure will be at least 1.10 times the system pressure for systems with a design temperature of 200'F or less, and at least 1.05 times the system pressure for systems with a-design temperature above 200'F. The system pressure is equivalent to the lowest pressure setting among the number of safety/relief valves provided for overpressure protection within the boundary of the system to be tested.

If safety/relief valves are not installed, the system design pressure will be used as the test pressure.

b. In the case of atmospheric storage tanks, the nominal hydrostatic pressure developed with the tank filled to its design capacity will be acceptable as the test pressure.

c ~ For 0 to 15 psi storage tanks, the test pressure will be 1.1 times the design pressure of vapor or gas space above liquid level for which overpressure protection is provided by the relief valves. If relief valves are not installed, the test pressure will be equal to 1.1 times the normal operating pressure.

d. For the purpose of the test, open ended portions of a suction or drain line from a storage tank extending to the first shut off valve are considered as an extension of the storage tank.

e. For open ended portions of discharge lines in nonclosed systems (such as containment spray header), a test that demonstrates unimpaired flow will be performed in lieu of a system hydrostatic pressure test.

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TITLEi RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 23 111 1.10.5 Test Implementation All pressure testing is implemented using both the VT-2 examination procedure and the specific test procedure for the type of test and portion of system being tested. 1.10.6 Scheduling When using the inspection plan, that during it should be noted a period or refueling outage in which a hydrostatic test is performed on a system or portion(s) of a system, the leakage test (Functional or Inservice) required for that period on the same system or portion of the system, may be deleted from that outage and period. The hydrostatic test will satisfy the requirements for that leakage test.
1. 11 Snubber Inspection and Test Program 1.11.1 General Requirements 1.11.F 1 Inspection and testing of all safety related snubbers shall be conducted to ensure the required operability of these snubbers during a seismic or other event initiating dynamic loads.
1.11.1.2 This program applies only to the snubbers listed in Table 5.
1. 11. l. 3 This program adheres to the requirements of ASME Section XI, 1986 Edition Article IWF and performed in accordance to the first addenda to ASME/ANSI OM-1987 Part 4 published in 1988.

l. 11. 1. 4 This program complies with the requirements of Technical Specifications Section 3.13 and 4.14. The program is implemented by the requirements of the Mechanical Engineering Specification ME-256 (and will be referred to ME-256 later on in this text), Ginna Station Maintenance Procedures M-40.11 and/or M-40.12 and'shall include:
TITLE: REV, QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 24 111 a~ Visual Inspection Requirements
b. Visual Inspection Failure Evaluation c ~ Visual Inspection Corrective Action and Impact on Examination Frequency.

d. Inspection Documentation

e. Functional Testing Requirements

f. Functional Test Sample g, Functional Test Failure Analysis

h. Functional Testing Corrective Action lo Functional Testing Methods Testing Documentation 1.11 ' Visual Inspections 1 '1 ' ' The snubbers identified in Table 5 shall be visually inspected based on the results of the previous inspections in accordance with the following schedule:
No. Inoperable Snubbers Subsequent Visual* er Ins ection Period Ins ection Period 0 18 months + 25% 1 12 months + 25% 2 6 months + 254 3,4 124 days + 25% 5,6,7 62 days + 25% 8 or more 31 days + 254 The inspection period shall not be lengthened more than one step at a time. Further, mechanical and hydraulic snubbers may be inspected independently in accordance with the above schedule. 1.11 ' ' Visual inspection (VT-3) shall verify (1) that there are no visible indications of impaired operability, (2) visible attachments to the foundation or supporting structure are secure, and (3) in those locations where snubber movement can be manually induced without disconnecting the snubber, that the snubber has freedom of movement and is not frozen up. Snubbers which are defined as inoperable as a result of visual inspections may be determined operable for the. purpose of establishing the next visual inspection interval, providing that (1) the cause of the
TITLE: REV, QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 25 111 rejection is clearly established and remedied for that particular snubber and for other snubbers that may be generically susceptible; or (2) the affected snubber is functionally tested in the "as found" condition and determined operable per Paragraph 1.11.3.2. However, when the fluid port of a hydraulic snubber is found to be uncovered, the snubber shall be determined inoperable and cannot be determined operable via functional testing for the purpose of establishing the next visual inspection interval. 1 '1.2.3 Snubbers which do not meet the visual inspection (VT-
3) requirements of Mechanical Engineering Specification ME-256, shall be reported to Mechanical Engineering (or designee) for visual inspection failure evaluation corrective action and impact on technical specifications Section 3.13. Corrective action may include replacement, modification or repair.
1.11.2.4 Records for the visual inspection (VT-3) shall be maintained on all snubbers listed in the Inservice Inspection Program. 1 '1 ' Functional Tests 1 '1 '.1 At least once per 18 months during shutdown, at least 104 of snubbers shall be functionally tested either in place or in a bench test. For each snubber that does not meet the functional test acceptance criteria in unrequired ME-256, an additional 10 percent of the mechanical and hydraulic snubbers shall be tested until no more failures are found or until "All" snubbers have been functionally tested. If additional sampling is due to failure of only one type of snubber which has failed the functional testing. The functional testing sample requirements are detailed in the Mechanical Engineering Specification (ME-256) Section 4.8. 1.11.3.2. Functional testing requirements for new installations or spares shall be equal to or more stringent than ME-256 Section 4.7, specifications.
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TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 26 111 1.11.3.3 Snubbers shall be subjected to a preservice functional test prior to installation using the same test procedures and equipment that is employed during inservice testing or requirements of 1.11.3.2 have been satisfied. 1.11.3.4 Snubber functional test requirement criteria is specified in ME-256 and Ginna Maintenance Procedures M40.11 and/or M40.12 as applicable. 1.11.3.5 Snubbers that do not meet the operability testing acceptance criteria in ME-256 shall be evaluated to determine the cause of the failure. Test failure mode Group(s) shall be established and include all unacceptable snubbers and all other snubbers subject to the same failure mode. This group will remain as defined until corrective action has been completed.
l. 11. 3. 6 Snubbers that have been found unacceptable for the testing acceptance criteria in ME-256 shall be subject to corrective action with its indicated impact on continued testing. Corrective actions for each type of test failure mode group is specified in ME-256 and snubbers will generally be replaced, modified or repaired. For any snubber which fail to meet functional test requirements, an engineering evaluation shall be performed on the components to which the unacceptable snubber is attached. This evaluation shall determine if the components were adversely affected by the unacceptable snubber and to insure that the component remains capable of meeting the designed service requirements.

l. 11.3 ~ 7 Hydraulic and mechanical snubbers shall each be treated as a different entity for the above surveillance programs.
1.11.3.8 Functional testing examination records shall be maintained on all snubbers listed in the Inservice Inspection Plan.
1. 11.4 The visual and functional testing schedule shall be defined in Supplement 1 to this Appendix titled "Snubbers".
42 528 TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE'990-1999 INTERVAL 27 " 111 1.11.5 Snubber Seal Service Life Monitoring 1.11.5.1 The service life of a snubber is evaluated via manufacturing input and engineering information through consideration of the snubber service conditions and functional design requirements. The only snubber components with service lives not expected to exceed plant life are seal and o-rings fabricated from certain seal materials. Therefore, a seal replacement program is required to monitor snubber seal and o-ring service life to assure snubber operability is not degraded due to exceeding component service life. 1.11 '.2 The seal service life of hydraulic snubbers shall be monitored and seals replaced as required to ensure that the service life is not exceeded between surveillance inspections during a period when the snubber is required to be operable. The seal replacement shall be documented and the documentation shall be retained in accordance with Technical Specification 6.10.2. 1.11.5.3 Records of the service lives of all hydraulic and mechanical snubbers listed in the Inservice Inspection Program including the date at which the service life commences, and associated installation and maintenance re'cords will be maintained.
42 ~ 5R8 TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 28 111
1. 12 Steam Generator Tubes and Tube Sleeve Combinations 1 '2.1 Repair criteria for steam generator tubes is based on the requirements of USNRC Regulatory Guide 1.121.

1. 12. 1. 1 Steam generator tubes that have imperfections greater than 40 percent through wall as indicated by eddy current, shall be repaired by plugging or sleeving.

1. 12. 1. 2 Steam generator sleeves that have imperfections greater than 30 percent through wall as indicated by eddy current shall be repaired by plugging.
1.12.2 Reporting 1.12.2.1 Within 15 days following the completion of the evaluation of each inservice inspection of steam generator tubes, the number of tubes required by Paragraph 1.12.1 above to the plugged or, sleeved in each steam generator shall be reported to the Commission in a Special Report pursuant to Technical Specification 6.9.3.4.
1. 12. 2. 2 The complete results of the steam generator tube inservice inspection shall be submitted to the Nuclear Regulatory Commission in a Special Report pursuant to Technical Specification 6.9.3.4 within 12 months following 'the completion of the inspection. This Special Report shall include:
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TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL OF 29 111 (a) Number and event of tubes inspected. (b) Location and percent of wall-thickness penetration for each indication of an imperfection, and 1.12.2.3 'f(c) Identification of tubes plugged or sleeved. the number of tubes in a generator falling into categories a or b below .exceeds the criteria, then results of the inspection shall be considered a Reportable Event pursuant to 10 CFR 50.73. Oral notification to the NRC Staff shall be accomplished within 48 hours, but no sooner than the next normal'-; working day after the final review of the eddy current results. A written followup report shall provide a description of investigations conducted to determine the course of the tube degradation and corrective measures taken to preclude recurrence. Categories (a) and (b) are: (a) More than 10 percent of the total tubes inspected are degraded (imperfections greater than 20 percent of the nominal wall thickness). However, previously degraded tubes must exhibit at least 10 percent further wall penetration to be included in this calculation. (b) More than 1 percent of the total tubes inspected are degraded (imperfections greater than the repair limit). 2.0 CLASS 1 PROGRAM PLAN 2.1 Basis for Preparation 2.1.1 Preparation of the Class 1 ISI program plan was based on the requirements of Articles IWB-1000 and IWB-2000 of Section XI. These articles provide rules and guidelines for exemptions, inspection schedules, and examination requirements for Class 1 pressure retaining components and their integral attachments.
7 ~ TITLE: REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 30 111 2.2 Components Subject to Examination 2 '.1 Based on the requirements of Section XI, the following Class 1 system's nonexempt pressure retaining com-ponents and their integral attachments will be subject to examination during the third inspection interval: 2 ~ 2.1.1 Vessels Reactor Pressure Vessel Pressurizer Steam Generators (Primary Side) Regenerative Heat Exchanger 2 '.1.2 Piping Reactor Coolant System Pressurizer Surge Line Residual Heat Removal System Safety Injection System Pressurizer Spray System Pressurizer Safety and Relief System Charging Lines Letdown Lines Drain Lines 2.2. 1.3 Pumps Reactor Coolant Pumps 2~2 ~ 1.4 Valves Safety Injection System Pressurizer Spray System Residual Heat Removal System Pressurizer Safety and Relief System Charging Lines Letdown Lines 2.3 Extent and Frequency of Examinations 2.3.1 Class 1 components, as listed in Table 1 shall be examined to the extent and frequency required in Table IWB-2500-1 and Figures IWB 2500 thru IWB 2500-20 of Section XI.
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TITLE: RE V. QUALITY APPENDIX B AS SURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 31 oF 111 2.4 Exemption Criteria 2~4~1 In accordance with IWB-1220, certain Class 1 components are exempt from examination. The following criteria were applied to exempt components from surface and volumetric examinations in accordance with Section XI: Exem tion Criteria Code Reference Piping of 1 inch nominal pipe IWB-1220 (b) (1) size (NPS) and smaller, except for steam generator tubing Components and their connections IWB-1220 (b) (2) in piping of 1 inch NPS and smaller 2.5 Examination of Reactor Coolant Pump Flywheels The Reactor Coolant Pump Flywheels shall be examined per the recommendations of Regulatory Guide 1.14, Rev.1 using both surface and volumetric examination methods. These examinations shall be scheduled in the Class 1 section of the ISI program plan. 2.6 Inservice Inspection Program Plan (Supplement 1 to Appendix B) This plan provides the examination requirements for Class 1 components per the 1986 Edition of Section XI. These requirements shall be satisfied during the third inspection interval. The plan also shows the results of examinations performed in the previous two intervals. A detailed description of the contents of the Class 1 Examination Plan can be found in the "Introduction", this immediately precedes the tables and the isometric and component drawings in the plan. From this plan an examination schedule is extracted for implementation of the examinations for each outage of the third interval.
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TITLE: REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 32 111 3.0 CLASS 2 PROGRAM PLAN 3.1 Basis for Preparation 3 ~ 1~1 Preparation of the Class 2 ISI program plan was based on the requirements of Articles IWC-1000 and IWC-2000 of Section XI. These articles provide rules and guidelines for exemptions, inspection schedule, and examination requirements for Class 2 pressure retaining components and their integral attachments. 3 ' Components Subject to Examination 3.2. 1 Based on the requirements of Section XI, nonexempt pressure-retaining components and their integral attachments for the, following Class 2 systems will be subject to volumetric and/or surface examination during the third inspection interval: 3 ~ 2 ~ 1.1 Vessels Steam Generators (Secondary Side) Non-regenerative Heat Exchanger Seal Water Return Filter Seal Water Injection Filter Residual Heat Exchangers A&B Pulse Dampener 3 ' ' ' Piping Safety Injection System Containment Spray System Residual Heat Removal System Main Steam System Feedwater System 3 ' Extent and Frequency of Examinations 3~3~1 Class 2 components, as listed in Table 2 shall be examined to the extent and frequency required in Table IWC 2500-1 and Figures IWC 2500-1 thru IWC 2500-13 of Section XI.
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TITlE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL l 3.4 Exemption Criteria IWC-1220 of Section XI provides the exemption criteria for Class 2 components. The following criteria were used to exempt Class 2 components from surface and volumetric examinations in accordance with IWC-1220. 3.F 1.1 The following components (or parts of components) of Residual Heat Removal (RHR), Emergency Core Cooling (ECC), and Containment Heat Removal (CHR), systems (or portions of systems) are exempt from the volumetric and surface examination requirements of IWC-2500: (a) vessels, piping, pumps, valves and other components 4 inches NPS and smaller in all systems except in high pressure safety injection systems of pressurized water reactor plants; (b) vessels, piping, pumps, valves, and other components 1-1/2 inches NPS and smaller in high pressure safety injection systems of pressurized water reactor plants; (c) component connections 4 inches NPS and smaller (including nozzles, socket fittings, and other connections) in vessels, piping, pumps, valves, and other components of any size in all systems except in high pressure safety injection systems of pressurized water reactor plants; (d) component connections 1-1/2 inches NPS and smaller (including nozzles, socket fittings and other connections) in vessels, piping, pumps, valves and other components of any size in high pressure safety injection systems of pressurized water reactor plants; (e) vessels, piping, pumps, valves, other components, and component connections of any size in statically pressurized, passive (i.e., no pumps) safety injection systems of pressurized water reactor plants; and
TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 34 111 (f) piping, and other components of any size beyond the last shutoff valve in open ended portions of systems that do not contain water during normal plant operating conditions. 3.4. 1.2 The following components (or parts of components) of systems (or portions of systems) other than RHR, ECC and CHR systems are exempt from the volumetric and surface examination requirements of IWC-2500: (a) vessels, piping, pumps, valves and other components 4 inches NPS and smaller; (b) component connections 4 inches NPS and smaller (including nozzles, socket fittings and other connections) in vessels, piping, pumps, valves and other components of any size; (c) vessels, piping, pumps, valves, other components and component connections of any size in systems or portions of systems that operate (when the system function is required) at a pressure equal to or less than 275 psig and at a temperature equal to or less than 200'F; and (d) piping and other components of any size beyond the last shutoff valve in open ended portions of 'systems that do not contain water during normal plant operating conditions. 3.5 Inservice Inspection Program Plan (Supplement 1 to Appendix B) This plan provides the examination requirements for Class 2 IWC components per the 1986 Edition of Section XI and R.E. Ginna Technical Specifications. These requirements shall be satisfied during the third inspection interval. The plan also shows the results of examinations performed in the previous two intervals.
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QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 35 111 A detailed description of the contents of the Class 2 Examination Plan can be found in the "Introduction". This immediately precedes the tables and the isometric and components drawings in the plan. From the plan an examination schedule is extracted for implementation of the examinations for each outage of the third interval. 4.0 CLASS 3 PROGRAM 4.1 Basis for Preparation 4.1.1 Preparation of the Class 3 ISI program was based on the requirements of Articles IWD-1000 and IWD-2000 of Section XI. These articles provide rules and guidelines for exemptions, inspection schedules, and examination requirements for Class 3 pressure retaining components and their integral attachments. 4.2 Components Subject to Examination 4.2.1 Based on the requirements of Section XI, nonexempt pressure-retaining components and their integral attachments for the following Class 3 systems will be subject to examination during the third inspection interval: 4.2.1.1 Syst:"ems a~ Auxiliary Feedwater System
b. Residual Heat Removal System C ~ Component Cooling System

d. Service Water Cooling System

e. Spent Fuel Pool Cooling 4.2. 1.2 "Other Class 3 systems are not subject to the examination requirements of ASME Section XI because they do not meet the system function requirements of Examination Categories D-A, D-B and D-C, where:
D-A Systems in support of Reactor Shutdown Function D-B Systems in support of Emergency Core Cooling, Containment Heat Removal, Atmosphere Clean-up and Reactor Residual Heat Removal.
TITLEi RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 36 ill D-C Systems in support of Residual Heat Removal from Spent Fuel Storage Pool". 4.3 Extent and Frequency of Examinations 4.3.1 Class 3 components, as listed in Table 3 shall be examined to the extent and frequency required in Table IWD 2500-1 and Figure IWD 2500-1 of Section XI. 4 ' Exemption Criteria 4.4.1 In accordance with IWD-1220, certain Class 3 components are exempt from examination. The following exemption criteria was applied to Class 3 systems as specified in IWD-1220: Exem tion Criteria Section XI Reference Integral attachments of supports IWD-1220.1 and restraints to components that are 4 inches NPS and smaller within the system boundaries of Examination Categories D-A, D-B, and D-C shall be exempt from the VT-3 examination, except for Auxiliary Feedwater. Integral attachments of supports and IWD-1220.2 restraints to components exceeding 4" nominal pipe size may be exempted from the visual examination VT-3 of Table IWD-2500-1 provided: (a) the components are located in systems (or portions of systems) whose function is not required in support of reactor residual heat removal, containment heat removal, and emergency core cooling; and (b) the components operate at a pressure of 275 psig or less and at a temperature of 200 degrees F or less.
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TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 4.5 Inservice Inspection Program Plan (Supplement 1 to Appendix B) This plan provides the examination requirements for Class 3 IWD components per the 1986 Edition of Section XI. These requirements shall be satisfied during the third inspection interval. The plan also shows the results of examinations performed in the previous two intervals. A detailed description of the contents of the Class 3 Examination Plan can be found in the "Introduction". This immediately precedes the tables and the isometric and component drawings'n the plan. From the plan an examination schedule is extracted for implementation of the examinations for each outage of the third interval. 5.0 CLASS 1/ CLASS 2g ANDCLASS 3 COMPONENT SUPPORTS 5.1 Basis for Preparation 5.1.1 Preparation of the component support ISI program was based on the requirements of Articles IWF-1000 and IWF-2000 of Section XI. These articles provide rules and guidelines for exemptions, inspection schedules, and axamination requirements for Class 1, Class 2, and Class 3 component supports. Inservice test requirements and VT-3 inspection requirements for snubbers shall be conducted in accordance with this program and Technical Specifications and Mechanical Specifications which implements the requirements of Article IWF-5000. 5.2 Components Subject to Examination l 5.2.1 Based on the requirements of Section XI, nonexempt component supports for the Class 1, Class 2 and Class 3 systems identified in Sections 2.2, 3.2 and 4.2 of this plan will be subject to examination during the third inspection interval. The component supports requiring examination shall be as follows:
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TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 38 111 5.2.1.1 Plate and Shell . Type Supports Supports-which are fabricated from plate and shell elements, such as vessel skirts and saddles, and are normally subjected to a biaxial stress. 5.F 1.2 Linear-Type Supports Supports acting under essentially a single component of direct stress. Such elements may also be subjected to shear stress. Examples of such structural elements are: tension.and compression struts; beams and columns subjected,to bending; trusses; frames; arches; rings; and cables. 5.2.1.3 Component Standard Supports A support assembly consisting of one or more generally mass-produced units usually referred to as catalog items. Examples of such items are shown in Figure IWF-1210-1 of Section XI. 5.3 Extent and Frequency of Examination 5.3.1 Component supports selected for examination shall be those components required to be examined under the requirements of 2.3, 3.3 and 4.3, IWF-2500. The inservice test requirements of Article IWF-5000 shall be satisfied by the requirements of 1.11. 5.3.2 In addition, snubbers identified in Table 5 will be functionally tested at the frequency required in 1-11.3 ~ 5.3.3 On piping systems where a piping seismic analysis boundary is beyond the safety class boundary, the component supports within the portion between those two boundaries shall be examined. The. extent of these examinations shall be consistent with the examination requirements of that safety class system. 5.3.4 High Energy Piping Component Supports shall be examined to IWC-2500 Category C-C and to IWF-2500 in an Augmented Program.
TITLE: REV. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 39 111 5.4 Exemptions 5.4.1 ASME Section XI, 1986 Edition, does not contain defined exemption criteria for component supports. 5 '.2 Exemption been used. criteria specified in IWB, IWC and IWD have 5.5 Inservice Inspection Program Plan (Supplement 1 to Appendix B) This plan provides the Class 1, Class 2 and Class 3 component supports shall be incorporated into the appropriate Class 1, Class 2 or Class 3 section of, the examination plan. These requirements shall be satisfied during the third inspection interval. The plan also shows the results of examinations performed in the previous two intervals. 6.0 AUGMENTED ISI PROGRAM FOR HIGH ENERGY PIPING 6.1 Basis For Examination 6.1.1 The inservice inspection program for high-energy piping outside of containment, as established in Rochester Gas and Electric Corporation's report "Effect of Postulated Pipe Breaks Outside the Containment Building," dated October 29, 1973, provides for the examination of all circumferential butt welds at design break locations and at discontinuity locations where a failure would result in unacceptable consequences. This inspection program consists of volumetric examinations utilizing the radiographic or ultrasonic methods and magnetic particle and visual examinations of these welds; these types of examinations are used to detect any change in condition or development of service induced flaws in advance of a potential failure. Surveillance of these welds by the inspection program provides assurance that the design basis or consequential Main Steam or Feedwater breaks will not occur.
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TITLEi RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 40 111 6.2 Inservice Inspection Program Plan 6.2.1 The 10-year inspection plan consists of three periods of 3, 4 and 3 years each, respectively. During each period of the 10-year interval, the inspection plan provides for examination of all welds at design basis break locations and one-third of all welds at locations where a weld failure would result in unacceptable consequences. 6.3 Welds Subject to Examination 6.3. 1 Table 6 of this plan lists all the welds by category and system. This table defines the inspection plan for the design basis break location welds, and the consequential break location welds. 6.4 Evaluation 6.4.1 The evaluation of the examinations of the high-energy piping welds outside of containment will be in accordance with Section XI IWC 3130 for visual examinations and IWC 3120 for magnetic particle examinations. Evaluations of radiographic results in accordance with the acceptance criteria for radiographic examinations referenced in USAS B31.1.0-1967.=, "Power Piping" and "ASME Section XI." Ultrasonic Examinations performed in accordance with the requirements of Appendix I and acceptance criteria in USAS B31.1.0 III and the 1967 (Radiography) .
TITLE: REV. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 41 111 7.0 RELIEF REQUESTS 7.1 Relief Requests In accordance with 10CFR50.55a(g)(5)(iv), RG&E has requested relief from those ASME Section XI requirements that have been, determined impractical for certain areas. This section summarizes each Relief Request submitted to the NRC for consideration. .Each request provides information on the component for which relief is requested, ASME requirements, proposed alternate method, and other pertinent information, as needed. Additional Relief Requests will be submitted to the NRC as appropriate. Table 7 presents a summary of the enclosed Relief Requests followed by the Relief Requests.
Table I H 0 SCHENE v~ CCOE CLASS NOTED I tea Exaalnaticn Cosponents and Parts Exaslnation Examination Requlresmnts for Exes inst lan Technique/Exam inst I on No, Cstesory To Be Examined Nethod Third inspection Interval Area Cceraents
<HQ O g I-I The ASHE Section XI Each type of examination The NOE method This cotton provides Information This cottony provides Information specific Iten No and area ls listed In this required to regsrdinB the number and/or percent of to examination techniques and examination Catesory of the coltnn. satisfy Code exaainaticns required to be perfonaed for areas.
coaponent are listed requirements Is the inspection Interval. ln these cottmns. listed in this Ixf H coiwn. $ I WOW KHgtTf LET O O X H W td I-I 0g M COB
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Table 1 H CI INSERVICE INSPECTION PROGRAll CLASSY) COHPONENTS (Cont'd) I tea Exasination Coaponents and Parts Exas inst Ion Exaaination Requfrceents for Exaainatlcn Technique/Exaainatfon No. Category To be Exasined Hethods Third Inspection Interval Area Ccalaents MMQ 0X M REACTOR PRESSURE VESSEL 5 f/) 'g 81.10 B.A Clrcusfefential and Voluaetric 100X of one clrcusferential ueld to be Exasinatlon of circusferentiel shell uelds 81.11 Longitudinal Shell Maids exaained at structural discontinuity In Mill be perfonaed uith UT techniques. ITI H 8'1.12 the beltline region. Exaainat iona Nay be There are no Iongitudirei Maids at R. E. I iz30 P perforeed at or near the end of the Ginna. inspect Ion interval. = LE)Mg+ 81.20 Clrcusferentfal Voiuaet r I c cD C hi 81.2'I 8 A Herl di one l end Head Maids The accessible length of one. clrcusferential ueld of each head to be Louer heed and closure head Maids Mill be exaained ut I I Izing UT techniques. There ga
81. 22 exasined. Exaainations Nay be perforced are no sx.rfdfcnat uelds at R. E. Ginna. LE) W ITj H at or near the erd of each inspection L() OOX interval for the lover head.
H fs3 I)3 81.30 8 A Shell-to.Flange Meld Vol uset r Ic IOOX of the ueid to be exasined. At 'Ihe shell-to-flange ueld Mill be exasined HOQ least 50X of the Veld shall be exaained fraa the vessel seal surface and fraa the fras the flange face by the end of the vessel uaII Inside surface uith UT. 0) first Inspection period erd the raaairder by the end of the third inspection period.
~ 9H Og BI.CO 8 A Head.to-Flange Meld Voiuaetr I c and IOOX of the ueld to be exaafned. The head-to-flange ueld vill be exaained Surface uith UT and surface exailnatlon techniques uhen the head is raaoved.
81.50 8 A Repair Maids N/A No repair ueids at R. E. Ginna. 81.51 83.90 B.D Nozzle-to-Vessel Maids Voluaetric 100X of nozzles. At least 25X but not The nozzle-to-vessel voids and nozzle 83.100 8.0 and Nozzle Inside Radius wore than 50X of the nozzles shall be inside radius sections vill be exaained Section exasined by the end of the first period ulth UT. and the raaafnder by the end of the Interval. 84.10 B.E Partial Penetration Visual (VT 2) At least 25X of each group of voids of Exasinat ion uill be perfonaed during the O 8(.11 Meldst cccparable size and fux:tfon to be systas hydrostatic test. VT exaainations SC.12 Vessel Nozzles exaained. ulII be per forsed In accordance uith SC.13 Control Rod Drive IMA.52(0. N Nozzies aN Instruaentation Nozzles CI
ivory'V4' O Table 1 H IMSERVICE INSPECT ION PROGRAH 0 ClASSa) CCHPOMENTS (Cont'd) I tes No. Exeainat Ion Category
~ts and Parts To be Exsafncd Exosinat Ion Hethods Exeaination Rcquiresents for Third Inspection Interval Exsainst lan Technique/Exeainat I on Area Coescnts ~ xIHQ QQH gf/) C 85 ~ 10 8 F Pr<<ssure-Retaining N/A Mo dlssisilar setol >>aids on RPV at R. E.
85.20 Disaisilar Hctal Nclds Ginna. 85.30 WH$ 86.10 S-G.I Closure Mead Nuts >2 Surface 100X of nuts to be exosincd. Exsainotlon Mute vill be exaslned with HT when resoved
& ix) O P Inches In Disaster say be perforscd at or neer thc end of the Inspection interval.
for refueling. eHRZ 0Q X 'g 86.20 B-G-I Closure Mead S'tudor In Ploce, >2 Inches in
. VotuaotrIC 100X of studs to be cxsained. Exsaina-tion soy be perforsed at or neer the cnd Closure stud exeainatfons say be perforscd "In place." Exsainatlons should be ached. tf) W 'T) a H
Dlascter of thc inspection interval. vied vhen studs are reaoved to reduce radiation exposure and allow the sost tC) OOX thorough exosinotlcn. Code Case N-307-1 shall apply H0HOW 5 86.30 8 ~ G-I Closure Mead Studs, @hen Voluaetric and 100X of studs to be exasincd. The studs vill be exeafncd with UT and KT. t3 f/) Rcsovcd, >2 Inches In Surface Exosinatfon say be perforsed at or near Code Case N-307-1 shall apply. Dlascter the end of the inspecticn Interval. 86.CD 8 G I Threads In Flange Voluaetric 100X of threaded holes to be exoslncd. Thc threads in flange vill be exeained free
>2 Inches In Disaster Exosinatfon say be perforscd at or near thc flange face with UT.
the end of the Inspection Interval. 86.50 8 0 I Prcssure-Retaining Visual (VT-I) All voahers and bushings to be exasined Closure llsshers ond upon stud reaoval, Exeaination say be
. Bushings >2 Inches in perfolscd ot or near the end of the Disaster inspection interval.
87.10 8.0.2 PresEurc-Retaining Visual (VI I) All bolts, studs, snd nuts to be The bolting soy be exsained In place under Bolting 82 Inches in cxeaincd. tension or shen dlsassesbled or reaoved. Diosetcr 87.80 8.0.2 CRD Housings Bolts, N/A Mo pressure-retaining CRD housing bolting C) Studs, and Nuts at R. E. Glrive.
88. 10 8~N Integral Attochscnts for N/A Mo Integrally welded attachscnts on RPV at RPV R. E. Ginna that scat the requlrcsents of g7 Category 8 ~ N. m
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Table I H INSERVICE INSPECTION PROGRAN 0 CLASSsf COHPONENIS (Cont'd) I ters Exaainatlon Cocponcnts and Parts Exarainat lan Exasinat ion Requircracnts for Exaainatlon Technique/Exrxainatlon No. Category To be Exarained Nethods Third Inspect Ion Interval Arcs Crxrraents MHQ OMH m 813.10 S.N Vessel Interior W(/) Z 1 Visual Acccsslblc sr'cas to bc cxrxslncd during (VT-3) each Inspection period. 813.50 B.N-2 Interior Attachacnts Vithin Bcltline Region Visual (VT-1) Accessible attachacnt rrclds to be exasrined. Exaainaticns Nay be crNpicted WH$ at or near the end of the inspection I ROW Interval. CHQ~< 813.60 S.N.2 Interior Attachaents c0 X X Beyond Beltline Region Visual (VT-3) Accessible attachacnt ucids to be exaained. Exaainat lone sray be cocpleted gU at or near the end of the inspection tO X < H interval. t() OOX LO + Q HW (3) 813.70 S.N.3 Core-Support Structure Visual (VT-3) Vlth core-srpport structure rcraoved, all accessible surfaces to be exaained. HOg Exaainations Nay be coeTr(etcd at or near (/) the end of .the Inspection interval. 814.10 8.0 Control Rod Drive Rousing Vo(uactrfc or Vclds ln IOX of the peripheral CRD Thc CRD housing rre(ds ui(I be exarsincd uith COB
~QH Voids Surface housings to be cxaained. Exaainations PT rsay be perforied at or near the end of the Inspection interval.
815.10 8 P All Pressure.Retaining Visual (VT.2) All cocponcnts to be cxaalned during VI exaainat lone VIII be pcrforracd In Boundaries for Vessel systcra leakage test. Exarslnat fons to be accordance uith IVA-52(0. Coclponcn t s perforracd in accordance uith IVS ~ 5221 prior to plant startup after each refueling outage. 815.11 8 P All Pressure-Retaining Visual (VT-2) All cocponents to be exsalncd during VT exarslnatlons ulll be perforrsed In Boundaries for Vessel systers hydrostatic test. Exaalnaticns to accordance uith IlrA 52(0. Coeponents be pcrforraed In accordance ulth IVB-5222 at or near the end of the inspection inter'val
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1 O Table I H INSERVI CE INSPECTION PROGRAH 0 CLASS,T COHPONENIS ICont'd) I tera Exsalnat I on Cocponents and Parts kxsalnatlon Exsainat ion Rcquirsaents for Exsalnatlon Technique/Exsaination No. Category To be Exsained Hethods Third Inspection interval Area Crxoacnts
>zi HQ QgH I/) C Q
PRESSURITER 82.10 8 8 . Circuafcrential and Voluaet ric Thc upper and lover head.to-shell rrctds Exsalnatlon ullt be perforacd uith Izi H 82.11 82.12 longitudinal Shell.to- to be exsained. One foot of one techniques. UT
&P5AW Nesd llelds long l tudlnal uctd intersecting each head-to-shell ucld to be exsained.
LO H g >CI 82.20 8-8 Circuaferent 1st and r Vo luce t I c There ere no pressurizer head uctds at oQgW 82.21 Hcrldlonal Kcsd Velds 82.22 R. E. Glrvra. LO hj Q H 5 83.'110 B.D Nozzle to Vessel llclds Votuaetr lc All nozzle-to-vessel uetds and Inside Exsainatlons Nit t be perforraed Kith tO 00X UT 83.120 and Nozzle Inside Radius radius sections to be exsaincd. At least techniques. H ta5 t)5 Sections 25X but not sore than 50X of the nozzles I-I 0 <<t5 shall be exsained by the end of the first period and the rcraainder by the cnd of the inspection Intcrvat. BC.20 B.E Neater Penetration lrelds Visual (VT.2) All pressurizer heater penetration uelds VT exsalnatlon Nit t be pcrforracd In 406 Nozzle shalt be exsained during systsa hydrostatic test In accordance rrith IVB-5222 at or near the end of the inspection interval. accordance ul th llrA-52CD.
'i' 85.IO 8 F Nozzle-to-Safe End Surface snd All butt uctds to be exsained. Exsalnations util be perforreed ulth PT and Dlsstraitar Hctal Voids Voluaetrlc UT techniques.
RC Inches NPS 85.50 8 F .to-Safe End Surface Alt butt uctds to be exsained. Exsalnations ut II be perforrecd Kith PT Dlsslaltar Natal Velds techniques.
<<C Inches NPS 85.60 B.f Nozzte-to.Safe End Socket N/A No dissiallar. setat socket uctds on Velds pressurizer at R. E. Glnna.
86.60 8 G I Pressure.Retaining N/A No bolting cn pressurizer >2 Inches In 86.70 Bolting >2 inches ln disaster at R. E. Ginns. Rl 86.80 Disaster O m
O Table 1 0 INSERV ICE INSPECTION PROGRAH +MAL CLASSY) CONPONENTS (Cont'd) Iten Exaninat lan Cccponents snd Parts Exavinatlon Exaaination Requlreaents for Exsainat I on Technique/Exaainat Ion No. Category To be Exeained Hethods Third Inspection Intervs( Area Ccetaents QHQ 0gH PRESSORITER Cont'd B7.20 B.0-2 Bolts, Studs, and Nuts Visual (VT-1) All bolts, studs, and nuts to be Bolting exaninati one aaay be perforncd In S2 Inches in Oieaeter cxtaal ncd place txxier tension or vhen dlsassccbied or td H rcnovcd
+%OP $
SS.20 B.H Integrally Ileidcd Voiuaetrlc or Pressurizer support skirt to be exavined. Exavlnation vill be perforecd per figure (C) H Iz) r() Attachacnts Surface IVB.2500.14. OC) X 615.20 B.P Pressure-Retaining Vfsual (VT-2) All pressurizer cocponents to be exaained VT cxaainatlon vill be perfonaed in U Boundaries Cccponents for Vessel during systen leakage test. Exaelnatfon to be perfonacd in accordance vith accordance vl th INB-5240. (C) g Q H (() OOR Ivs-5221 prior to plant startup after each refueling outage. H X'LZI HOW $ 15.21 B P Pressure-Retaining Visual (VT-2) All pressurizer coaponcnts to be exaained VT cxsainatlon vill be perforicd In M Boundaries for Vessel during systcn hydrostatic test. accordance v) th ! NA-52(0. Cccponents Exaainat ion to be perfonacd in accordance vith Ivg-5222 at or near the end of the fnspectlon Interval. 406 0 Rl Ill
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Table 1 H INSERVICE INSPECTION PROGRAN 0 CLASS,I CONPONENTS (Cont'd) Item Examination Cocpcnents and Parts Examination Examination Requirements for Examination Technique/Examination No. Category To be Examined Nethods Third Inspection Interval Area Cccmcnts
>zj HQ 0'gH Q f/) Q STEAN GENERATORS 82.30 82.31 8 8 Clrcuaferential snd Nerldional Maids in the VOIIxactrlc There are no steam generator lover head circuaferentlal or meridional uclds.
SHE 82.32 lover Need I-I WOW 82.(0 8-8 Tubesheet-to-Need Meld Voltxactric The tubesheet.to.head ucid ulll be Examination ulll be performed uith UT Lf) M g IET cxaaincd. The examination vill be techniques. limited to one of the tuo stcam generators. (() X >Cf H a (C) O 0 b(l 83.130 8 D Nozzle.to Vessel Maids Voluactrlc All nozzle fnside radius sections ulll be Examinations ulll be performed ulth UT 83.1(0 .Snd Nozzle Inside Radius exmaincd. At least 25X but not more than techniques. There sre no stems generator M X ()5 Sectlcns 50X of the nozzles shall be examined by nozzle-to-vessel ucids. HO% the end of the first inspection period snd the remainder by the end of the 0) inspection Interval. ta ET% 85.70 8 F Nozzle to Safe End Surface snd All nozzle safe-end dissimilar metal Examinations ulll be performed uith PT and 406
~QH 85.80 Dissimilar Natal Maids VOIIxactrlc uclds shall be examined. UT techniques at R E. GIIVIS.
85.90 86.90 8.0.1 Pressure.Retaining N/A No bolting on stcccl gcncrators >2 Inches ln 86.100 Bolting >2 Inches in diameter at R. E. GIrna. 86.110 Diameter 87.30 8.0.2 Bolts, Studs, snd Nuts Visual (VT. I ) All bolts, studs, and nuts ulll be Examinations may be performed in place S2 Inches In Diameter examined. under tension or uhcn removed. 88.30 8 8 Integrally Meldcd N/A There are no stcam generator Integrally At tschmcnts ueldcd attachments. IN-2500-13. 815.30 .8 P Pressure Retaining Visual (VT.2) All stcam generator cocponents to be VT examlnatle/Is ulll be performed In O goundsrles ~ xamincd during system leakage test. accordance ulth IMA-52(0. Examinations to be performed In accordance uith IM8-522'I prior to plant startup after each refueling outage. gl m O
O Table I H INSERVI CE INSPECTION PROGRA)l 0 CLASS, I CONPONENTS ICont'd) I t ea Excel net I on Coeponen'ts and Pal'ts Exanl net I cn Exeaination Requireeents for Exaaination Technique/Exasinatfon No Category To be Exaained Nethods Third Inspection Interval Area Coeraents MHQ 0RH Q U) C SIEAN GENERATORS Cont'd 815.31 B.P Pressure.Retaining Visual IVT-2) All steaa generator cocponents to be VT exaainatfons ulll be perforeed In Boundaries exaained during systea hydrostatic test. accordance ulth INA-5260. gH$ Exaainatlons to be per fonoed In accordance ulth IN8-5222 at or near the end of the Inspection Interval. ran> LE) H Ix5 ltj 816.20 8.4 Stean Generator Tubing Volueetrlc The tubing In the hot leg side, U.bend portion, and optionally cold leg side Exaainatlon requlreeents, exaalnatlon OX) X eethod, and the extent and frequency of U VIII be exaained. exaainstion shall be In accordance ulth II) W M H plant Technical Specificatlcns. II)OOR HX [XI HO+ X4 0) t?S MR 406 Rl O m
Table 1 H INSERVI CE INSPECTION PROGRAN 0 CLASSY] CONPONENTS (Cont'd) I tea Ex¹sinatlcn Coeponents and Parts Ex¹sinat ion Ex¹ainat ion Requlreeents for Ex¹ainat ion Technique/Ex¹sinat ion No. Category To be Ex¹slned Nethods Third Inspection Interval Ares Comaents
+HQ 0CHC g T/3 N AT EXCMANGERS 82.50 82.51 $ .8 Bead Voids Voiusetrlc One veld per head vill be ex¹ained. Ex¹sination techniques.
vill be perforeed vith UT gHg 82.52 &ROW 82.60 $ .$ vill be vill be AI3 Hg Q Tubesheet-to-Read Molds Volusetric Each tubesheet-to.head ex¹slned. veld Ex¹slnatlon techniques. perforecd vith UT oXghf 82.70 $ .$ l.ongltudinal Velds NIA There are no RNE longitudinal voids at R. 5 E. glrive. FLOOR 82.80 8.$ Tubesheet-to-Shell Velds Voitzactrfc Each .tubesheet to.shell veld vill be Ex¹sinatlon vill be perfor¹ed vlth UT HX i33 ex¹sined. techniques. HO+ 83.150 8 D Nozzle.to.Vessel Voids Voitzset r I c All nozzle-to-shell and nozzle Inside Ex¹slnatlon <<III be perforeed vlth UT M 83.160 B.D and Nozzle Inside Radius radius sections vill be exaalned. At techniques. Section least 25$ but not vore than 50X of the nozzles shall be ex¹sined by the ond of <OR WQH the first inspection period and the r¹salnder by the end of the Interval. 85.100 8 F Preasure-Retaining NIA No heat exchanger dissisliar velds st 85.110 Dissi¹llar Natal Velds R. E. Cirna. 85.120 86.120 8 0 1 Pressure-Retaining N/A No heat exchanger bolting at R. E. Cinna. 86.130 Bolting x2 Inches In
86. IAO Dl¹seter 87.40 8-0-2 Bolts, Studs, and Nuts N/A No heat exchanger bolting at R. E. Glnna.
<2 Inches In DI¹aeter BB.AO B.N Integrally voided Voluaetrlc or Integrally voided attachments In one RNE Ex¹sinatlon v(II be perfonacd vlth PT or UT Attachaents Surface support shall be ex¹ained. techniques.
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O td Table 1 H INSERVI CE INSPEC'I ION PROGRAN Q CLASSY) CONPONEN'IS (COnt'd) I ten No. Exaelnat lan Category
~ts and Parts To be Exaofncd Extsalnatfon Nethods Exaainat lan Requlrenents for Third Inspection Interval Exanlnatlon Technique/Exaalnatlon Area Cceuents QHQ QgH NEAT EXCNANCERS Cont'd + MQ WR 815.(0 8 P Pressure-Retaining Visual (VT-2) All RNE cceponents ul i( be exajsined VT exaainatlons ulll be perfonaed In BoLndar les during systaa leakage test. Exajslnations accordance uith IMA-52(0. WH$
to be perfonaed In accordance uith INS-5221 prior to plant startup after each refueling outage. r Prov LO H g t(f 815.AI 8 P Pressure-Retaining Vlsual (VT.2) All RNE coeponents ulII be exaained ulll be VT exon!nations perforised ln goundarles during systea hydrostatic test. accordance ulth INA 5240 Exaainations to be perforned in accordance ulth INS-5222 at or near the end of the Inspection interval. t()OQR HOW HQg
'R 4 R
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Table I H INSERVICE INSPECTION PROGRAH 0 ClASS>) COHPONENIS (Cont'd) I tea Exaainat Ion Cccponents and Parts Exaainat lan Exaainat lan Requl resents for Exaaination Technique/Exaainstlon No. Category To be Exasined Hethods 'Ihlrd Inspection Interval Area Conaents Ixj HQ 0QH
/Mg PIPING
$ 5.130 8 F Olsslallar Hetal Holds tC Inches NPS Voluaetric Surface and All butt Neids to be exaalned. The uefds Hill be exaained Nlth UT and PT. jTjHg I WOW $ 5.1CO 8-F Oissiailsr Hetal Maids Surface All butt to be exeslned. ulll be
<C Inches NPS Nelds The uelds exaafned ulth PT. 'LO H g IT5 85.150 8~F Oissiailar Natal Holds Socket . N/A No dissiailar acta( socket Neids at R. E.
ogpua Ginna. I() hf IEj H 86.150 8-G I .Pressure-Retaining N/A No pressure-retaining bolting >2 Inches In I()
'L()
008 Q g
86. 160 Bolting e2 Inches In dianeter et R. E. Ginns. HX 86.170 Oiaseter H05 13) 87.50 8.0.2 Pressure. Retaining Visual (VT-I) All boitsg student and nuts to be The bolting shay be exasfned in place under M Bolting S2 Inches ln exaained. ~ tension or uhen dlsassesbted or reooved.
Oiaaeter 89.10 B.J Circusferentlel Pipe Volusetric and 258 of the required circuaferent la( butt The piping ueids ulll be examined Nith UT 89.1'I Voids tC Inches NPS Surface ueids to be exaained. See Note 1 at end and PT. of Table 1 for selection criteria. 89.12 B.J l'angl tudinal Pipe llelds Votuaetric and longitudinal uelds that adjoin scheduled The piping uelds Hill be exasined uith UT tC Inches NPS Surface circusferential Neids are to be exaained. and PT. Cne pipe disaster not to exceed 12 inches of each longitudinal ueld length required. 89.20 B.J Clrcuaferent lal Molds Surface 25K of the required circusferential butt The piping Ne(ds Hill be exaralned uith PT. 89.21 <<C inches NPS uelds to be exeained. See Note 1 at end of Table I for selection criteria. C) 89.22 8 J longitudinal Pipe Ueids Surface longitudinal ueids that adjoin scheduled The piping Nelds Hill be exanlned Nlth PT.
<4 Inches NPS clrcusferentisl Nelds are to be exaained.
One pipe diameter of each longitudinal Neld length required.
tt i
O td Table I H INSERVI CE INSPECTION PROGRAN 0 CLASS I, CONPONENTS (Cont'd) I tea No. Exsalnatlon Category
~ts end Parts To be Exsaincd Exsainatlon Nethods Exsalnation Requlrsaents for Third Inspection Interval Exsainatlon Technique/Exsaination Area Coeraents ariH Q OQH
~PIPNG C i'd g f/3 'g 89.30 B.J Branch Pipe Connection Voluaetrlc and 25X of the required branch connection The branch connection Molds sill be 89.31 Maids 24 Inches NPS Surface Joints to be exsained. See Note I at end ~ xsalned uith UT snd PT. WHY 89.32 B.J Branch P lpe Connection of Table I for selection criteria. vwo> of the required branch canectlon Maids <C Inches NPS Surface 25X joints to be exsained. See Note I at end The branch connection Molds exsained ul th PT. NIII be L() H g4 of Table I for selection criteria. Ogpua 89.(0 B.J Socket,Maids Surface 25X of the required socket voids to be The socket uelds NIII be exsained ulth PT. (() X 4 H exsalned. See Note 1 at end of Table 1 L()OOR for selectlcn criteria. HX (33 810.10 B.K I Integrally Attschsents Melded Voluaetric or Surface All required supports to be exsalned. See Note 2 at end of Table I for The integrally uelded attachaents sill be HQg
.exsalned ulth PT or UT as applicable.
selection criteria. f/) 815.50 8 P All Pressure-Retaining Visual (VT-2) All coaponents to be exsained during VT exsaination NIII be perforsed In Bounds.ies for Piping Cosponents systea leakage test. Exsalnation to be perforsed in accordance ulth IM8.5221 accordance uith IMA-5240. ~QH prior to plant stsrtup after each refueling outage. 815.51 B.P All Pressure. Retaining Visual (VT-2) All cccponents to be exsained during VT exsaination VIII be perforsed in Boundaries for Piping systsa hydrostatic test. Exsainat ion to accordance uith IMA-52(0. Cccponents be perforscd in accordarce uith IMB-5222 et or near the end of the inspection interval. O gl m O
O Table 1 INSERVICE INSPECTION PROGRAll 0 CLASS.,l, CONPONENTS (Cont 'd) I tea Exsainst I on Cocponents snd Parts Exsalnat lan Exsainat Ion Rcquireeents for Exsainatlon Technique/Exsainatlon No. Category To be Exsained Nethods Third Inspect Ion Interval Area Cssaents lTI HQ gMC m PWPS BS.IBD 8 G I Bolts snd Studs,
>2 Inches in Disaster Voluaetrlc All bolts and studs to be exsained. The bolting Case N-307.1 ulll be exsained ulth UT.
shall apply. The bolting aey Code Ex) H$ be exsained In place under tension or shen ) WOW dlsasscehled or rsaoved. Se.lgo S-G-I Flange Surface for Bolting >2 Inches In Visual (VT-1) Exsainatlon includes 'I Inch srau(ar OQ)X Dfsaeter Vhen Connection surface of flange around each stud hole surface shen disassechled. 'LO E>3 >(5 5 H Is D lsssseehled k() AOX Se.200 B.r,-l Nuts, Bushings, and Visual (VT.I) All nuts, bushings, snd uashers to be HXQ Vashers >2 Inches In Diameter exsained shen disassechled. HOW M 87.60 8.0.2 Pressure-Retaining Visual (VT I) All bolts,.studs, and nuts to be The bolting say be cxsalned in place under Boltlny <2 Inches In examined tension or shen disassechlcd or recevcd. Disaster 4 O )-3 810.20 K-I All required attachaents to ulll be 8 Integrally Velded Attsdxaents Voluaetrlc or Surface Sce Note 2 selection at end of Table criteria. 1 be exsained. for Velded at tscheents or UT as applicable. cxsained ulth PT IR 812.10 8 L 1 Puq> Casing Velds Voluaetric Reactor coolant pump casing acids on one I tea except frsa exsainatlon per puep to be exsained. Rcllcf 84.. 812.20 B.L 2 Internal Surfaces of Pump Visual (VT.3) One reactor coolant Ixmp to be exsained Puap casing Internal surface ui(I be Casings shen di sasseehled. cxsained ulth visual techniques uhen dlsasscehled. 815.60 S.P Pressure-Retaining Visual (VT-2) All components to bc cxsalncd during VT exsalnations ulll be performed ln Soutafarles for hap systsa leakage test. Exsainatlon to be accordance ulth IVA-5240. C) Components perforsed In accordance ulth IVS-5221 n prior to plant starttp after each I'cfucllng outage ~ m O
tM lg, Table 1 H INSERVICE INSPECTION PROGRAN 0 CLASSY) CONPONENTS (Cont d) Iten Exaainatlcn Cccponcnts and Parts Exaalnatlcn Exaainatlon Rcquirceents for Exaainat i on Technique/Exaal net ion No. Category To be Exaaincd Nethods Third Inspecticn interval Area Coaaents
~ MQ QQM
~PINPS C t'd Q T/l 8 eIS.61 e-P Pressure-Retaining Visual (VT-2) All cocponents to be exaained during VT exaainations ulll be perforned in goundarlcs for Puap systcfa hydrostatic test. Exiaination to accordance ulth IMA-52LO. ITI H Coeponents be perforocd in accordance uith ILN~ 5222 $ PJOP at or near the end of the Inspection I intewal. 40 H g Q N/A N/A .Puap fly@eels Surface and reactor coolant pLap flyuhcet to be DQ ITI Voluactrlc Each cxsaincd per Reg. Guide I.IL. Nigh-Exenlnations uiLL be perforied uith UT techniques. NT and gU stress areas to ba exaalned each period LO hj + H ulth full exaainatlon at the end of LII O O R Interval. LD Q Q HWW HOg f/I
ÃX> 0 I3 ~QH O
m O m
O Table 1 H INSERVICE INSPECTION PROGRAN 0 CLASSiL CCNPONENTS (Cont'd) Itea Exaainat Ion Coaponents and Parts Exsalnation Exsainati on Requlrceents for Exa4Inat I on Technique/Exealnat Ion NO. Category To be Exaalned Nethoch Third Inspection Interval Area Comacnts
<HQ OgH VALVES g(/) Q
86. 210 SG I Bolting >2 Inches in N/A No valve bolting >2 Inches in disaster at 86.220 86.230 Oieaeter R. E G Irate. WH$
&WOW 87.70 BG2 Bolting Inches In All bolts, studs, E2 VlsuaL (VT-1) and nuts to be The bolting 4ay be exaained ln place under k() HRQ 810.30 K-I Ol aaetcr Integrally Velded cxsained. tension or shen dlsassecbied or reaoved.
oCgX 8 . VOLLaaetrlc or All required attachacnta tO be exaalncd. Velded attschuents ulll be exealncd uith P'I a Attachaents Surface See Note 2 at end of Table 1 for or UT as applicable. L() Eri + H selection criteria. L() OOX 812.30 B.N 1 PresEurc.Retaining Veids Surface One valve In each group of valves that ls Valve ucids VILL be exa4lned ulth PT. H td L)3 in Valve Bodies <4 Inches NPS of thc saoe construction and sI41(ar flection to be exaaincd. HOg (/) 812.(0 B.N.1 Prcssure-Retaining Velds N/A No prcssure-retaining uclds In valve bodies h3 >ET R In Valve Bodies 24 Inches NPS tC Inches NPS at R. E. Glnna. COG
~QH 812.50 B.N.2 Internal Surfaces of Visual (VT-3)'ne valve In each group of valves that ls Valve Bodies on Valves of the sacs construction and slallar >4 Inches NPS fMctlcn to be exa4ined.
815.70 8 P All Pressure.Retaining Visual (VT.2) All cocponents to be exaaincd during VT exealnatlons VILL be perforecd ln
'oundaries for Valve systc4 Leakage test. Exaalnatlon to be accordance uith IVS ~ 52(0.
Cocponcnts perforaed in accordance ulth IVS-5221 prior to plant startup after each l'cfucling ou'lagc 815.71 8 P All Pressure. Retaining Visual (VT 2) All corponents to be exsalncd during VT cxaalnatlons ulLL be perforeed in Boundaries for Valve syste4 hydrostatic test. Exaainatlon to accordance ulth IVA-52CO. Ccepoqents be perforeed In accordance ulth IVS-5222 C) at or near the erd of the Inspection interval. N) lll
lp O Table I NOIES H 0 (I) Exaainstions shall be distributed throughout the piping systea te<fatlsfy the extent required by AS% Section XI 1974 Edition uith Addenda through Suaaer 1975 as peraitted by TOCFR50.55a(b)(2)(II). Exealnations selected shall be distributed in such a aanner to Include: (a) Terainal ends ln each pipe or branch nn cornected to vessels. (b) Terainal ends and Joints In each pipe or branch ran corvv.cted to other coaponents.
~MQ QQH (c) All dlssfailar. octal voids.
5(f) R (d) Additional piping uelds so that the total rxmber of circusferentlal butt voids (or branch canection or socket ue(ds) selected for exaaination equals 25X of the clrcusferentlal butt uelds (or branch connection or socket ueids) ln the reactor coolant piping system. This total does not include uelds excluded by lug ~ 1220. These additional uelds Nay be located In one loop. WHY (2) ExaaLInation is liaited to those Integrally uelded attaclxaents that Neet the fo(loving condltlonst rP300 (a) the attacivaent is on the outside surface of the pressure-retaining coeponent; 'LO 0 H
'X g FTI X
(b) the attacivnent provides coeponent support as defined in NF-ITIOT ga (c) the attachaent base aaterfal design thickness ls 5/8 inch or greater; (() X )T5 H and (() OOX (d) the attachaent veld loins the attachsent either directly to the surface of the coeponent or to sn Integrally cast or forged attachaent to the cceponent Hh5W HOW Exealnatlons Include the uelded attacheents of piping required to be examined by Exaoinaticn Category 8-J and the uelded attac)scents to associated lxmps and M valves integral to such piping.
<OR ~QH
Table 2 H SCNEKE 0
"~
e CCOE CLASS Iten Exaainatfo Cosponents and Parts Exaainatlon Exaninatfcn Requiroaents for Exaaination Technique/Exaninatlon No. n To Be Exanined Kethod Third Inspection Interval Area Coaeents Category QHQ QRH QQ)gP The ASKE Section XI Each type of exaainatlon The NDE aethod This cotmn provides infornatfon This cotton provides Information specific Itoa No. and area ls listed in this required to regarding the rabber and/or percent of to exaninatfon techniques and exaainatlon Category of the cohnn. satisfy Code exaninatfons required to be perfonaed for areas, ccoponent are listed is in these cotuuLs. requireeents listed in this the inspection Interval. WHY coimn. KWAP LO H g4 oCgX LO hj ~H v LIT O 0R HO g HXW Ol 406 WQH
O Table 2 H INSERVICE INSPECTION PROGRAH 0 C)ASS 2 COHPONENTS I tee No. Exacsinatio nCategory
~ts and Parts To Be Exsaincd Exacafnation Ncthod Exacsinatlon Rcquirccaents Third Inspection Interval for Exacainat lan Technique/Exaainat Area Ccccaents lan PRESSURE VESSELS cd H Q OMH gf/) R O'1.10 C-A Shell Circusfercntlsl Voluaetric 100X of each ueld to be excxaincd (applies The Molds uill be exaalned uith UT.
Me(ds only to uelds at gross structural discontinuities). For sultiple vessels of slcaflar design size and service, exacsinatfons Nay be liaited to one tdH$ vessel. ) PfOW C1.20 CA Head Clrcuafercntial Voluaetric 100X of each head-to-shell ucld to be The voids ulll be exacaincd ulth UT. I() HRQ Maids exccalned. for accltfpie vessels of D X Eri siallar design size and service, I 'Tf gU exaalnatlons csay be Ifcalted to one I() X 'Tf H vessel. I() OOX C1.30 C-A Tubesheet-to Shell Meld Vol use tri c IOOX of each ueld to be exaaincd. For The uelds uill be exacalncd ulth UT. H Izf (33 aultlple vessels of siscllar design size and service, exeainations scay be llaitcd HQQ to one vessel. f/) C2.10 C-8 Nozzles In Vessels sl/2- Surface All nozzles at tercainaI ends of pipicX) Thc ueids ulll be exaalned ulth or as C2.'ll Inch Tccxaina( Thickness Nozzle-to-Shell (or Heal) rum cchlch are selected for exaaination I sppl cable. HT PT
<OR ~QH under Categories C-F-I and C.F.2. 100X Me(d of each veld to be exacsined. Hacacays snd hand holes excluded. for sxcitlpte vessels of sfscllar design, size, and service, exacainatfcns easy be llaited to one vessel.
C2.20 C.B Nozzlcs Mlthout Surface and All nozzles to be selected at tercsinaI The voids ull1 be exacslned ulth UT and HT C2.21 Reinforcing Plate In Voluaetrlc ends of piping recce selected for or PT as applicable. Vessels <<I/2- Inch Noes Inc I cxaainatlon under Categories C.F-I and C-
'fhickness Nozzle-to.Shell F.2. 100X of each ueid to be exacsincd.
(or Head) Meld Hacacays and hend holes excluded. for aultiple vessels of sfcal(ar design, size, and service, exaalnations easy bc ll~ I ted O to one vessel. Rl m O
0 t3 Table 2 H INSERVI CE INSPECTION PROGRAN 0 CLASS,2 COHPONENTS (Cont'd) Iten Exaafnatlo Coaponents and Parts Exanlnation Exaeinat Ion Requireeents for Extxainat ion Technique/Exaaination No. nCategory To Se Exaalned Nethcd Third Inspection Interval Area Ccctaents PRESSURE VESSElS Con 'd <HQ OCH C2.22 C-g Nozzle Inside Radius Voluaetrlc 100X of each ares to be exeained. The nozzle inside radius section ulll be gMg Section Nanuays and hand holes are excluded. for exsained ulth UT. eultiple vessels of sfuilar design, size, snd service, exauinatlcns nay be linited to one vessel. AH) ROW C2.30 C-8 Nozzles ulth Reinforcing N/A There are no nozzles ulth reinforcing plate C2.3I Plate In Vessels >I/2. In vessels >I/2.inch noainai thickness at tie H g >T3 C2.32 C2.33 inch Noadnat Thickness R. E. Gl~. Ogpua
'ST W >CI H NOON zf) Q g H tzi I33 HOg t9 VI <OR WQH
O Table 2 H I NSERVICE INSPECTION PROGRAM 0 CLASS,2 CONPONENTS (Cont'd) It<<a Ex<<ainstlo Coepcnents and Parts Ex<<ainatlon Examination Requireaents for Ex<<alnation Technique/Ex<<ainatfcn No. nCategory To Be Ex<<alned Nethod Third Inspection Interval Ares Ceaments tTj MQ PRESSURE VESSElS Con Id 0@M gf/) C3.10 C-C Integrally Veided At- Surface IODX of each Ne(d to be ex<<ained. The ue(ded attachments Vill be ex<<alned g tachments Attachments <<hose base claterls( Is Nith NT or PT as applicable. 3/C Inch or greater to be selected. Vherc saltlple vessels are provided ulth WH$ a number of similar attachaents, the sttachaents <<ay be distributed <<song the KQOP vessels. For sultlple vessels of similar I() M Is) Q desfgn and service, ex<<ainatlons <<ay be c)QgW Limited to one vessel. g 4 aH I C() (() O08 CC.10 CD Pressure.Rctalning B- N/A No pressure-retaining vessel bolting oltfng <<2 Inches in D- >>2 inches ln df<<aeter at R. E. Oirns. l<<eater HWW C7.10 Pressure-Retaining Cccpo- Visual (VT-2) All pressure-retaining boundaries for Yf cx<<afnations VIII be performed in H05 nents vessels to be ex<<ained during systea accordance ulth IVA-52CO. t/) pressure tpst. Ex<<ainations to be pe-rformed In accordance ufth IVC-5221~for each inspection period. <OR QQH C7.20 C N Prcssure. Retaining Cocpo- Visual (VT-2) All pressure.retaining boundaries for VT cx<<atnatlons ul(I be performed In nents vessels to be ex<<ained during systea R, hydrostatfc test. Ex<<alnations to be accordance ulth IVA-52CO. performed in accordance ulth IVC-5222 a! or near the end of each inspectlcn Interval or during same inspection periods of each Interval. C)
)4 ia l>>o r m
O
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Table 2 H 0 INSERVICE INSPECTION PROGRAH CLASS,) CCHPONENTS ICont'd)
+RAN I ceca Exsllnstfo Cosponents snd Parts Excxslnatlcn Excxalnat ion Requlrenents for Exacs inst Ion Technique/Exscal net I on No ~ n To Be Exact!nod Hethod Third Inspection Interval Area Ccacsents, Category ITi HQ 0 Q I-I PIPING &ITIOUS C3. 20 C-0 Integrally gelded Swfsce 100X of each ueld to be exisined. The ccelds cciLL be excxslned uith HT or PT as Attachsents Attachscnts uhose base csaterfal is 3/C I appl cable. td H inch or greater to be selected.
Selecticn Iicclted to those cocponents selected under Exsslnatlon Categoc'Ies Ef C-F-I and C-F-2. tO H Erl >ET CC.20 CO Pressure-Retaining N/A C)XgW pressure-retaining bolting >2 inches In Bolting >2 Inches In Ko diiseter at R. E. Glnna. a LI3 W 'TT H Bisector LIS O 0 R C5.10 CF1 Piping lee lds ln Surface and 100X of each clrcuaferential and 2.5t of The uelds ullL exislned cclth ID Q Q H0M Erl5 be UT and PT. I35 C5.11 Austenitlc Stainless Volusetric each longitudinal ueid requiring C5.12 Steel or High-Alloy exaalnatlon. See Note 1 st end of Piping k3/8-Inch Noalnal Table 2 for selection criteria. OT Wall Thickness for Piping
>>C NPS, Clrcccsferentlal and I.ongltudinal (l 0 R CF1 'Piping Nelds In ~QH CS. 20 Surface and 100X of each circusferential and 2.5t of The uelds cclII be exaalned ulth UT and PT.
C5.21 Austenltlc Stainless Volusetrlc each longitudinal ueld requiring C5.22 Steel or High. Alloy exaaination. See Note 1 at end of Piping tI/5-Inch Noalnal Table 2 for selection criteria. Hall thickness for Piping k2 NPS and <C NPS, Circusferential and Long i tud ina l C5.30 CF I Socket llelds In Surface 100X of each veld requiring excxsinatlon. The ueids IIIIL be exaccined uith PT. Austenl tie Stainless See Note 1 at end of Table 2 for Steel or High-Alloy selection criteria. Piping CS.CO CF1 Pipe Branch Cocvtections Surface IOOX of each circuaferential snd 2.5t of The ueids cclIL be excxsined ulth PT. CS.C I In Austenltic Stainless each longitudinal veld requiring CS.C2 Steel or High-Alloy exasination. See Note 1 at end of m>>Q Piping k2 NPS, Circusferential and Table 2 for selection criteria. O (
~ >>
cc Longitudinal
44)<
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5 I rt I Table 2 H INSERVI CE INSPECTION PROGRAM 0 CLA~g COMPONENTS <Cont'd) Iten Exaninatio Coepcnents and Parts Exaaination Exaainatlon Requirenents for Exanlnetion TechnlqueIExaalnatlon No. n To Be Exanlned Method Third Inspection Interval Area Coasents Category QHQ OgH ~PIPIPP I I'd g Tfi R C5.50 C F.2 Piping Voids in Carbon or Surface and IOOX of each clrcusferentlal ard 2.5t of The Maids VIII be exanfned ulth UT and NT. C5.51 Lou-Alloy Steel 23/8-Inch Voimetrlc longitudinal ueld requiring C5.52 Noainai Vali Thickness each exanlnatlon. See Note 2 at end of WH$ for Piping >A NPS, Clrcuaferentlal and Table 2 for selection criteria. In addi-tlcn, 100M of the sain stean and nafn
&QOP Longitudinal feechtater uelds located outside tO H g ITT contalnaent and traversing safety areas shall'e exanined per Technical Speci-oXgX f l cat lone. U LO N ICf M %OOX H hf i33 HOW M
0 I-3
~QH
A Table 2 H INSERVICE INSPECTION PROGRAN 0 CLASS, 2 COHPONENTS ICont'd) Itoa Exaainatio Coaponents and Parts Exasination Exaalnat ion Requireaents for Examination Technique/Exaainat ion No. n To ge Exasined Nethod Third Inspection Interval Area Cosnents Category
<HQ OZH
~PIPIIIP P 'd g T/) R C5.60 C.F.2 Piping Maids fn Carbon or N/A No carbon or Iou.alloy steel nonexespt C5.61 Lou-Alloy Steel <<I/5-Inch ueids In this category at R. E. Girns. fTiHg C5.62 Ncoinal Mall Thickness for Piping-t2 NPS and SG & IT) O P NPS, Clrcuaferentiai and Longltudlnal to H g FE) C5.70 C F 2 Socket Maids In Carbon or N/A No carbon or Iou alloy s'teel nonexeslpt oCgX Lou-Alloy Steel in this category at U Maids R. E. Glnna. 10 fTI <H C5.80 C.F.2 Pipe granch Connections Surface 100X of each clrcusferentlal and 2.5t of The voids Mill ba exaained ulth NT. tf) OOR C5.81 In Carbon or Lou-Alloy each longitudinal ueld requiring HX f)5 C5.82 Steel 22 NPS, Clrcusferentlal and exatsfnatfon. See Note 2 at end of Table 2 for selection criteria. HO 5 Long I tudlnal f/) C7.30 C N Pressure. Retaining Cocpo- Visual IVT-2) All pressure.retaining boundaries for VT exaafnations uIII be perforaed In nents piping to be exaained during systea accordance ufth IMA-5240. NOR
~QH pressure test. Exaainatlon to be per-foreed ln accordance ulth IMC-5221 for each Inspection period.
CT.SO Pressure-Retaining Cospo- Visual IVT.2) All pressure-retaining boundaries for VT exaalnatfons ulII be perfortsed fn nents piping to be exisined during systea accordance ulth IMA-52CO. Reference Relief hydrostatic test.'xislnatfon to be Request No. 4. perforaed In accordance ulth IIC-5222 at or near the end of each inspection Interval or during saic Inspection periods of each Interval. C) gl Ilt
J4 O Tabte 2 H INSERVICE INSPECTION PROGRAN 0 CLASSY) CONPONENTS (Cont'd) Itea Exaafnatfo Cosponents and Parts Exaafnatfcn Exacfnatfon Requf resents for Exaafnatfon Technique/Exaafnatfon No. n To Be Exaalned Ncthod Third Inspect Ion Interval Area Coctsents Category
~ xf H Q OgH X T/) a C3.30 C-C, integral ty Iletded At- N/A IOOX of each ueld to be exaafncd.
t schaent s Attschsents uhosc base s>>ttcrlal 'Is 3/4 'Inch Ff H ortrna. greater to be selected. Selection rQnv $ tlafted to those cocponents selected under Exasfnat Ion Category C-G. No fxrps eeet this criteria at tt) H Irf >>(5 C4.30 C 0 Pressure-Retaining 8- K/A R. E. Glnna. pressure-retaining puq>> bolting Ogpu oltlng>>2 Inches ln 0-No
>>2 inches fn dfaoeter at R. E. Ginna. L() 59>>T) aM feaster 4() AO 'Pq C6. 10 Pressure.Retaining ln Ptlp Casings Netds N/A No pressure-retaining fxlp uelds at R. E. HX t3)
G HOW C7.50 C N Pressure-Retaining Cospo- Visual (VT-2) All prcssure.retaining baxxfarfes for VT exaafnatlons Kilt be pcrfors>>cd In (/) ncn'ts fxgps to be exaafncd during pressure accordance Kith INA-5240. test. Exsslnat ion to be pcrfors>>ed in accordance uith IKC-5221 for each OR inspect ion period. QQH C7.60 C N Pressure-Rctafning Cocpo- VISUaL (VT.2) Alt pressure-retafning boundaries for VT exaafnatfons ultl be perforled In Q]Q ncnts pimps to be exaafncd during systca accordance Kith IVA-5240. hydrostatic test. Exasfnatfcn to be perforled In accordance Kith IKC-5222 at or near the end of each inspection Intewal or during saoc Inspection periods of each interval. O m
1 0 $/ <<T
,Il
A Table 2 H INSERVICE INSPECTION PROGRAH 0 CLASSc2 COMPONENTS (Cont'd) I tea No. Exesinatto n
~ts and Parts To Be Exeatned Exesinatlon Method Exesinatlon Requlreaents for Third Inspection Interval Exeaination Technique/Exaainat ton Area Ccocsents Category ITt HQ OC VALVES g (/) m C3.40 C C Integrally Molded At- Surface IOOX of each uetd to be exeslned. The uetds util be exeained ulth IIT or PT as Iachaecl'I s Attachaents cchose base aaterlal ls spplIcable. g H 3/4 Inch or greater to be selected. 0 & ts3 OP Selection tialted to those coeponents selected under Exeaination Category C-O.
(() H R4 C4.40 C.D Pressure.Retaining B- N/A No presswe-retaininy bolting <<2 Inches In O I g
0) gX citing >>2 Inches In D-Ieaeter dleaeter at R. E. Oicaa.
9H5 C6.20 Pressure.Retatnlng Maids 100X of uetds In coeponents In each acids Mitt be exeslned uith or L() O OR ln Valve Bodies The MT PT ss (() Q piping rcxc exealned under Exaalnat Ion applicable. H Categories C-F-I and C-f-2. In case of
~ xcttlpte valves of stallar H 0 design, size, fmction, snd service In a systea, thP exaainatlon of only one valve hS 'T5 C7.70 Pressure-Retaining I s required.
All pressure-retaining 40 PA H C M Coepo- Visual (VT-2) boundaries for VT exaalnatlons util be perforaed In nents valves to be exeained during systea accordance ul th IMA-5240. pressure test. Exealnation to be per-foraed In accordance ulth IMC-522I for each tnspectlcn period. C7a80 C M Pressure-Retaining Cccpo- Visual (VT-2) All pressure-retainlny boundaries for VT exealnations uttt be perforaed In nents valves to be exesined during systea accordance uith IMA-5240. hydrostatic test. Exaalnation to be perforaed In accordance uith IMC.5222 at or near the erd of each Inspection Interval or during saae Inspection periods of each tnterval. a Ill cs
n fz3 Table 2 - N01ES H 0 (I) Thc ueids selected for exaainatfon shall include 7.5X, but not less, than 20 uelds, of all austenltic stainless steel or high-alloy uelds not excepted by INC-1220. (Scoe uelds not excepted by thfs Case are not required to be nondestructively exaaincd per Exauinatlon Category C F-1. shall be included In thc total ueld ccxat to uhlch the 7.5X sacpilng rate is applied.) The exaulnations shall be distributed as follousz ueids, houever, These (a) the exaalnations shall be distributed acong the Class 2 systoas prorated, to the degree practicable, on the rxzzber of nonexccpt austenltlc stainless steel or high.alloy uelds In each cystos (I.e., lf a systes contains 30X of the nonexeept ueids, then 30X of the nondestructive exauinations required by Exasination Category C-F-1 should be pcrforecd on that systos)T tzf M Q OCM m (b) ulthin a systcu, the exauinatlons shall be distributed acong tenslnai ends lace Note (3)) and structural discontinuities (see Note (4)) prorated, to the degree practicable, cn the rxuber of nonexeept teralnai ends and structural discontinuities in that systeuf and RXP (c) uithln each systcu, exaulnations shall be distributed betueen line sizes prorated to thc degree practicable. gH$ (2) Ihe uelds selected for cxauinstfon shall include 7.5X, but not less than 28 uelds, of all carbon or Iou-alloy uelds not excepted by INC-1220. (Soue & Iz) 0 P voids not excepted by this Csee are not required to be nondestructively exauined per Exauinatlon Category C-F12. These voids, houever, shall be Included l() in the total veld caat to uhich the 7.5X saapllng rate ls applied.) The exauinations shall be distributed ak foiloust (() M'lz3 C) 'g < lz3 (a) the exaainations shall be distributed among the Class 2 systocs prorated, to the degree practicable, on the rxuber of nonexespt carbon or Iou-alloy ga ueidh In each systeu (i.e., If e systoa contains 30X of the nonexecpt ucids, then 30X of the nondestructive extxslnatfons required by Exauination Category C-F-2 should be perfonscd on that systcu)T t() W 'T5 H (C) OOR (b) ulthin a systeu, the exaulnstions shell be distributed acong teruinai ends (see Note (3)) and structural discontinuities (see Note (()) prorated, to H X (3) the degree practicable, on thc neer of nonexcspt terulnsi ends snd structural discontinuities In that systce; snd MOg (c) ulthln each systee, exaalnations shall be distributed betuccn line sizes prorated to the degree practicable (I) (d) Only those uelds shoving reportable prcservlce transverse Indications need to be exauined for transverse reflectors. COB QQH (3) Teruinai ends are the extrcuitles of piping re that connect to structures, coeponents (such as vessels', Imps, valves), or pipe anchors, each of uhfch acts as a rigid restraint or provides at least tuo degrees of transitional restraint to piping therasI expansion. (Z) Structural discontinuities Include pipe ueid Joints to vessel nozzles, valve bodies, puep casings, pipe fittings (such as cibous, tees, rcduccrs, flanges, ctc., ccnforuing to ANSI 016.9), snd pipe branch connections and fittings. O
O Table 3 H SCHEHE 0 CCBE CLASS Iten Exasinat lo Cceponents and Parts Exaninat Ion Exaalnat lan Requireeents for Exaaination Technique/Exeainat ion xo. ncategory To Be Exanined iiethod Third Inspection Interval Area Coaeents rxi HQ The ABYE'ection XI Each type of exaninaticn aethod This colum provides Infonaatlon m Itea Ko. and area ls listed in this The NDE required to regarding the rxnber and/or percent of This colum provides Infonaatlon specific to exanination techniques and exaninatfon gEI3Z P Category of the col tarn. satisfy Code exasinatlons required to be perfonaed for orcase coeponent are listed requl recants Is the Inspection interval. 'in these coitxms. listed in this cot ttm. WH$
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O Table 3 H INSERVICE INSPECTION PROGRAH 0 CIASS 3 CONPONENTS I tea Exauinat io Coaponents and Parts Exasinst ion Exeslnat ion Requireeents for Exajsinatfon Technique/Exaaination No. nCategory To Be Exaained Method Third Inspect ion Interval Ares Ccements MHQ OCH I 01.10 D2.10 D A D.B Pressure-Retaining nents Coapo- Visual (VT-2) All cccponents to be exaained during systecl pressure ol systecl hydrostatic VT exaainations accordance uith ulll be performed In IMA-5260.
+MR D3.10 D C test. Exaainaticn to be perforsed In accordance uith IIR).5221 for each fnspec.
tlon period and performed once each Interval In accordance uith IIO-5223. XH$
) PJOV DI. 20 D.A Integral At tee)xaents of Visual (VT.3) All required at tscivaents to be exaained Integral attachaents NII I throu- Supports and Restraints, during each Inspection Interval. for The be exauined.
(() H g Q gh Dl- .60 Hydraulic Scxkbers, Spring, Constant load, auttlpte coeponents In a systee of siailar design, fustian, and service, oNgW D2.20 D B and Shock Absorbers the Integral attachment of cnly one of Lo W M a H throu. gh D2- 0 C the su(tip(a ccaponents shat( be exauined. The fntegral attachaents (() OOX .60 selected shall correspond to those sup- M X Qj D3.20 port cccponents selected for exaainatlon I-l 0 g throu. in accordance ulth IVF-2510(b). gh D3- M .60
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O Table 4 H SCHEHE 0 CCOE CLASS iten ExaslnatIo Ccoponents snd parts Exiainatlon Exaninat ion Requirenents for Exaalnat lan Technique/Exanlnat I on No nCategory To Be Exanined Hethod Third Inspection Interval Ares CoaIaents
~ xl H Q The ASHE Section Xl Each type of exasinatlon The NBE oethod This coIIsvI provides Inforsat len This coIIIm provides Infonaat ion specific OXH go)X Itoa No. and area is listed in this required to regarding the Ixgber and/or percent of to exaninatlcn techniques and exasinaticn Category of the coIMm. satisly Code exasinatfons required to be perforaed for sI'ess td X cceponent are listed requiresents Is the Inspection Interval.
in these coIIxms. listed in this colum. WH$ tOOW LO C) 'C H g rtf ITI g5 LD W ~ H LET 00X HWN HQQ th
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RIIU O Table 4 H INSERVICE INSPECTION PROGRAH 0 x~ CLASS 1 ~ CLASS 2, AND CLASS 3 CCHPONENT SUPPORTS Item Examinatio Cocponents snd Parts Examination Examination Requirements for Exaslnat ion Technique/Exmsinat lan No, n0atcgory Kethod, To Se Examined Third Inspection Interval Arcs Consents MHQ m PLATE AND SHELl TYPE SUP TS llNEAR TYPE SUPPORTS AND CCHPOHENT STANDARD SUPPORTS g M 'g F1.10 F A Hechani col Cornect Iona to Visual (VT-3) Cosponent supports to be selected for ftnctfcnai testing of snubber type stpport throu-fi-Pressure-Retaining nants and Building Compo exasinatlon are the sorts of the coeponents shall be performed ln accordance gh nonexcept Class I, 2, and 3 coeponents ulth Technical Specifications axl In .40 F2.10 F 0 Structure; Iield Connec-tions to Building scheduled to be examined. Examination accordance ulth requirements of this &QOP boundaries established In accordance ulth throu- Structure; Iield and INF-1300. Exaslnatlons may be performed program, LO cl m H g t4FCI gh f2. F C Hcchanlcal Connections at during normal system operation or plant .40 Intermediate Joints In outagcs ~ g F3.10 Hulticcxnected Integral U LO X W H throu. gh f3-snd Nonintegral Supports; and Component Dis-LIT O 0 N .50 placement Settings of H ITI I33 Guides snd Stops, Hlsallgnment of Supports, H05 Assesbly of Support M Items; Spring Type Supports; Ccnstant load Type Supports; Shock 0Q Absorbers; Nydraul ic Type Snubbers IR O IYI m m N Cl
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TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION 0. MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 72 " 111 TABLE 5 Safet Related H draulic Snubber Accessible or System Snubber Installed on Inaccessible Snubber No. and Anal sis Line Number A or I AFU-205 Standby Auxiliary Feedwater A AFU-208 Standby Auxiliary Feedwater A AFU-209 'Standby Auxiliary Feedwater A AFU-224 Standby Auxiliary Feedwater A AFU-225 Standby Auxiliary Feedwater A AFU-226 Standby Auxiliary Feedwater A AFU-229 Standby Auxiliary Feedwater A AFU-109 Auxiliary Feedwater 500 FWU-3 Feedwater 100 A FWU-5 Feedwater 100 A FWU-2 1 Feedwater 301 A FWU-44 Feedwater 300 A N-601 Pressurizer Relief Discharge A N-602 Pressurizer Relief Discharge A N-604 Pressurizer Relief Discharge A N-605 : Pressurizer Relief Discharge A N-607 Pressurizer Relief Discharge A N-608 Pressurizer Relief Discharge A N-615 Pressurizer Relief Discharge A N-616 Pressurizer Relief Discharge A MSU-8 Main Steam 200 PS-2 Pressurizer PORV Discharge A PS-4 Pressurizer PORC Discharge A PS-5 Pressurizer PORV Discharge A PS-6 Pressurizer PORC Discharge A PS-8 Pressurizer PORV Discharge A PS-9 Pressurizer PORC Discharge A PS-10 Pressurizer PORV Discharge A PS-11 Pressurizer PORC Discharge A
TITLEi RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL TABLE 5 Const Safet Related Mechanical Snubbers Accessible or System Snubber Installed on Inaccessible Snubber No. and Anal sis Line Number A or I AFU-3 Auxiliary Feedwater A AFU-31 Auxiliary Feedwater A AFU-34 Auxiliary Feedwater A AFU-52 Auxiliary Feedwater A AFU-75 Auxiliary Feedwater A AFU-98 Auxiliary Feedwater A AFU-101 Auxiliary Feedwater A AFU-103 (East) Auxiliary Feedwater A AFU-103 (West) Auxiliary Feedwater A AFW-ill Auxiliary Feedwater A AFW-123 Auxiliary Feedwater A AFW-124 Auxiliary Feedwater A AFU-227 Standby Auxiliary Feedwater BDU-16 Steam Generator Blowdown 200 CCU-43 Component Cooling 450 CCU-57 'omponent Cooling 700 CCU-71 Component Cooling 600 CVU-26 Chemical and Volume Control 730 I CVU-46 Chemical and Volume Control 300 I CVU-49 Chemical and Volume Control 700 I CVU-80 Chemical and Volume Control 100 I CVU-103 Chemical and Volume Control 500 I CVU-104 Chemical and Volume Control 500 I CVU-131 Chemical and Volume Control 500 I CVU-186 Chemical and Volume Control 250 I CVU-345 Chemical and Volume Control 900 I CVU-351 Chemical and Volume Control 900 I CVU-372 Chemical and Volume Control 1000 I CVU-550 Chemical and Volume 200 Control 1000 I FWU-8 Feedwater A FWU-12 Feedwater 200 A FWU-15 Feedwater 301 A FWU-17 Feedwater 301 A
~4' TITlE: REY, QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL TABLE 5 Con~t Safet Related Mechanical Snubbers Accessible or System Snubber Installed on Inaccessible Snubber No. and Anal sis Line Number FWU-18 Feedwater 301 A FWU-2 0 Feedwater 301 A FWU-23 Feedwater 301 A FWU-24 Feedwater 301 A FWU-2 6 Feedwater 301 A FWU-32 Feedwater 300 A FWU-38 Feedwater 300 A FWU-39 Feedwater 300 A FWU-40 Feedwater 300 A FWU-42 Feedwater 300 A FWU-47 Feedwater 300 A FWU-48 Feedwater 300 A FWU-51 Feedwater 300 A FWU-52 Feedwater 300 A FWU-54 Feedwater 300 A FWU-57 Feedwater 300 A MSU-2 Main Steam 100 I MSU-3 Main Steam 100 I MSU-7 (Top) Main Steam 200 I MSU-7 (Bottom) Main Steam 200 I MSU-12 Main Steam 300 A MSU-13 (East) Main Steam 300 A MSU-13 (West) Main Steam 300 A MSU-15 (North) Main Steam 300 A MSU-15 (South) Main Steam 300 A MSU-16 (North) Main Steam 300 A MSU-16 (South) Main Steam 300 A MSU-18 (North) Main Steam 300 A MSU-18 (South) Main Steam 300 A MSU-19 (North) Main Steam 300 A MSU-19 (South) Main Steam 300 A MSU-22 Main Steam 300 A MSU-25 Main Steam 300 A MSU-26 (Top) Main Steam 300 A MSU-26 (Bottom) Main Steam 300 A MSU-27 Main Steam 300 A
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TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION 0. MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 75 TABLE 5 Con~t Safet Related Mechanical Snubbers Accessible or System Snubber Installed on Inaccessible Snubber No. and Anal sis Line Number MSU-29 Main Steam 300 A MSU-31 Main Steam 300 A MSU-32 Main Steam 300 A MSU-38 Main Steam 300 A MSU-39 Main Steam 300 A MSU-40 Main Steam 300 A MSU-44 Main Steam 300 A MSU-55 Main Steam 300 A MSU-57 Main Steam 300 A MSU-58 Main Steam 300 A MSU-60 Main Steam 300 A MSU-72 Main Steam 120 A MSU-74 Main Steam 120 A MSU-75 Main Steam 120 A MSU-78 Main Steam 120 A MSU-80 Main Steam 120 A MSU-82 Main Steam 120 A MSU-84 (East) Main Steam 120 A MSU-84 (West): Main Steam 120 A MSU-85 Main Steam 120 A RHU-8 Residual Heat Removal 100 A RHU-30 Residual Heat Removal 2500 RHU-3 3 Residual Heat Removal 2500 A RHU-3 6 Residual Heat Removal 350 A RHU-51 Residual Heat Removal 400 A RHU-53 Residual Heat Removal 400 A RHU-61 Residual Heat Removal 400 A RHU-63 (North) Residual Heat Removal 300 A RHU-63 (South) Residual Heat Removal 300 A RHU-69 Residual Heat Removal 300 A RHU-71 (North) Residual Heat Removal 300 A RHU-71 (South) Residual Heat Removal 300 A RHU-72 Residual Heat Removal 300 A RHU-75 Residual Heat Removal 300 A RHU-92 Residual Heat Removal 300 A RHU-109 Residual Heat Removal , 450 A
TITLE: REV, QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 76 111 TABTE 5 Con~t Safet Related Mechanical Snubbers Accessible or System Snubber Installed on Inaccessible Snubber No. and Anal sis Line Number RHU-110 Residual Heat Removal 450 A RHU-119 Residual Heat Removal 450 A RHU-123 Residual Heat Removal 450 A SIU-3 Safety Injection - 100 A SIU-47 Safety Injection 200 A SIU-52 Safety Injection 200 A SWU-254 Service Water 1850 A SWU-308 Service Water 1400 A SWU-309 Service Water- 1400 A SWU-,370 Service Water- 1500 A SGA-7 Steam Generator "A" A SGA-8 Steam Generator "A" A SGB-3 Steam Generator "B" A SGB-4 ." Steam Generator "B" A
TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 77 111 TABLE 6 HIGH ENERGY WELD OUTSIDE CONTAINMENT
1) MAIN STEAM LOOP A OUTSIDE CV Desi n Basis Break Conse ential Break 30A-MS-600-1A D 30A-MS-600-1A D2 30A-MS-600-1A Dl 30A-MS-600-1A D3 30A-MS-600-1A Fl 30A-MS-600-1A E 36-MS-600-1 Ll 30A-MS-600-1A El 30A-MS-600-1A E2 30A-MS-600-1A F 30A-MS-600-1A G 30A-MS-600-1A Gl 30A-MS-600-1A G2 30A-MS-600-1A H 30A-MS-600-1A J 30A-MS-600.-1A K 30A-MS-.600-1A L

2) MAIN STEAM LOOP B OUTSIDE CV Desi n Basis Break Conse ential Break 30B-MS-600-1B D 30B-MS-600-1B Dl 30B-MS-600-1B Hl 30B-MS-600-1B D2 30B-MS-600-1B Jl 30B-MS-600-1B E MS-600-1 Pl 30B-MS-600-1B J 30B-MS-600-1B K 30B-MS-600-1B L 30B-MS-600-1B Ll 30B-MS-600-1B L2 30B-MS-600-1B M 30B-MS-600-1B N 30B-MS-600-1B 0 30B-MS-600-1B P
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TITLE: REV. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 78 111 TABLE 6 Con~t
3) MAIN STEAM TURBINE BUILDING Desi n Basis Break Conse ential Break 36-MS-600-1 L2 36-MS-600-1 L4 24A-MS-600-1A A, 24A-MS-600-1A B 24A-MS-600-1A Bl 24A-MS-600-1A Cl 24A-MS-600-1A D 24A-MS-600-1A Dl 24B-MS-600-1B A 24B-MS-600-1B B 24B-MS-600-1B Bl 24B-MS-600-1B C 24B-MS-600-1B Cl 24B-MS-600-1B D

4) FEEDWATER TURBINE BUILDING Desi n Basis Break Conse ential Break 20-FW-900-1 M3 20-FW-900-1 J 20-FW-900-1 Kl 20-FW-900-1 L 20-FW-900-1 Ll 20-FW-900-1 M 20-FW-900-1 Ml 20-FW-900-1 M2 8-FW-900-1 A 8-FW-900-1 B 8-FW-900-1 C 8-FW-900-1 D 8-FW-900-1 E 8-FW-900-1 F 8-FW-900-1 G 8-FW-900-1 H,
TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 79 111 TABLE 6 Const
5) FEEDWATER LOOP A OUTSIDE CV Desi n Basis Break Conse ential Break 20-FW-900-1 M4 14A-FW-900-1A T2 20-FW-900-1 Ul 14A-FW-900-1A T3 20-FW-900-1 U2 14A-FW-900-1A U7 14A-FW-900-1A AA 14A-FW-900-1A U5 14A-FW-900-1A U6 14A-FW-900-1A V 14A-FW-900-1A VA 14A-FW-900-1A VB 14A-FW-900-lA Vl 14A-FW-900-1A V2 14A-FW-900-1A V2A 14A-FW-900-1A V2B 14A-FW-900-1A W 14A-FW-900-1A X 14A-FW-900-1A Y 14A-FW-900-1A Z
.14A-FW-900-1A Zl 14A-FW-900-1A Z2 14A-FW-900-1A Z3 14A-FW-900-1A Z4
I TITLE: REY, QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION 0. MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 80 111 TABLE 6 Con>t
6) FEEDWATER LOOP B OUTSIDE CV Desi n Basis Break Conse ential Break 20-FW-900-1 Al 14B-FW-900-1B F3 20-FW-900-1 F4 14B-FW-900-1B F5 14B-FW-900-1A N 14B-FW-900-1B Fl 14B-FW-900-1A V 14B-FW-900-1B F2 14B-FW-900-1B G 14B-FW-900-1B G2 14B-FW-900-1B Gl 14B-FW-900-1B G3 14B-FW-900-1B G4 14B-FW-900-1B H 14B-FW-900-1B HA 14B-FW-900-1B HB 14B-FW-900-1B Hl 14B-FW-900-1B H2 14B-FW-900-1B H2A 14B-FW-900-1B H2B 14B-FW-900-1B J 14B-FW-900-1B K 14B-FW-900-1B L 14B-FW-900-1B M 14B-FW-900-1B Nl 14B-FW-900-1B 0 14B-FW-900-1B 01 14B-FW-900-1B P
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42 528 TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION 0 MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 81 " 111 TABLE 7 SCARY OF RELIEF REQUESTS Relief ASHE Requirement Reason for Proposed Request Section XI for Mhich Relief Relief Alternate Number Reference C t is R ested R est Examination IMB-2500-1 RPV Shell to Volunetrfc Examina- To perform all exami- Perform all examina-Cat. B-A F lange Meld tion during two nations associated tions associated with different periods. with the Shell-to- the Shell.to-FLange at Flange during the or near the end of the same period. interval. IMB-2500-1 RPV Nozzle-to- Volunetric examina- To perform all exami- Perform all examina-Cat. B-D Vessel Metds tion during two nations associated tions associated with different periods. with the Nozzle-to- the Nozzle-to-Vessel Vessel welds during welds at or neir the the same period. end of the interval. IMA-1400 Authorized Use of "Authorized New York State has Use R.E. Ginna Quality Inspecti on Inspect'ion Agencyw not endorsed ASHE Assurance Program. Agency. Codes and does not have an Authorized Inspection Agency. IMB-2500.1 Reactor Coolant Volunetric exami- Pump material and Hydrostatic test, sur-Cat. B-L.1 Pump Case Maids nation of case welds configuration. face and visual exams B-L-2 and Intervals. and visual of of outside surfaces. internals. IMB-2500-1 Class 1 Valves Visual Examination Excessive radiation Examine valve internals Cat. B-H-2 Greater than of valve internals. exposure and histo- when disassenbled for
'fipS 4. rical reliability of maintenance.
valves. Ill-2500.1 Radfoactive Visual Examination Tank will be rendered Perform visual examina-Cat. DB Maste Holdup at hydrostatic inoperative during tion each period at Tank. pressure. tests. normal operating pressure. IMC25222(a) Charging Punps Visual Examination Pumps have maxinun Perform Hydro Test and at 3420 psig Hydro- pressure limit on visual at 2400 psig. static Pressure. the seaLs. IMC-5222(a) Valves PCV 430 Visual Examination Valve diaphragms can- Hydrostatic Test to and PCV 431C at Hydrostatic not withstand Test Flex Connection Pressure. 'Pressure. operate diaphragm per vale test requirements and perform inservice visual examination once per period.
TITLE1 RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION 0 MANUAL INSERVICE INSPECTION PROGRAM PAGE FOR THE 1990-1999 INTERVAL GINNA STATION 82 ill TABLE 7 (Con't) SIIIIARY OF RELIEF REQUESTS Relief ASHE Requirement Reason for Proposed Request Section XI for Mhich Relief Relief Alternate Rubber Reference C ent is R ested R est Examination IMC-5222(a) Secondary Side Visual Examination RG&E adopted pressure Hydrostatic Test at of steam at Hydrostatic differential limita- 1.10 times instead of generator and Pressure. tion of 800 psig 1.25 Psv setting and associated main to prevent primary perform visual steam piping. side tube sheet examination. cladding separation. 10 IM)-5223(a) Standby Auxiliary Visual Examination Pressure Reduction Perform Inservice Pump Recircul ~ at Hydrostatic Flow Orifice requires Visual Examination Line from AOV Pressure. removal and blank-off. once per period. 9710A, AOV 97108 System piping does and their associ- not provide isolation ated downstream to condensate supply flow orifices. tank. Significant tank reduction would be required for removal and is considered impractical. IMD-5223(a) Boric Acid Visual Examination Test Pressure required Perform Inservice Filter and asso- at Hydrostatic will exceed limits Visual Examination ciated piping Pressure. for safe working pres- once per period. Petween Valves sure on Boric Acid 347, 348A and Filter Housing Flange 349A. Gaskets. 12.1 IN-5223(a) Air Start for Visual Examination Air Start Pressure Test Perform Inservice Diesel Generator at Hydrostatic would require termi- Visual Examination including Pressure. nation prior to reach- once per period and Receiver Tanks ing engine skid to once each quarter a and Piping. preclude air to air pressure decay test start motors, leaving performed on air portion of piping receiver. untestable. 12.2 IN-5223(a) Fuel Oil Transfer Visual Examination Requires isolation of Perform system func-Pumps and asso- at Hydrostatic Diesel Oil Storage tional Testing with ciated piping to Pressure. and Dry Tank where no associated visual terminals at Oil no means of isolation Visual Examination Storage Tank. is provided at Trans- once per period. fer lxnp discharge piping with tanks vented to atmosphere.
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42 aza TITLE) RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION 0 MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 83 111 TABLE 7 (Con't) SQKARY OF RELIEF REQUESTS Relief ASHE Requirement Reason for Proposed Request Section XI for Which Relief Relief Alternate Hueber Ref erence t is R ested R est Examination 12.3 IWO-5223(a) Jacket Cooling Visual Examination Cooling Water Expan- Perform System Water System and at Hydrostatic sion Tank vented to Fax:tional Testing associated piping Pressure. atmosphere requiring with associated to terminals at isolation with vast Visual Examination Water Expansion piping involved will once per period. Tanks. be unable to pressurize. 13 IWC-5222(a) Hon-ISI classi- Visual Examination Requirements should be Test in accordance fied systems at Hydrostatic based on the contain- with 10CFR50 Appendix penetrating Pressure. ment system design not J with the safety primary the associated process fumtion the line containment. system design require- performs in accordance ment. with Technical Speci-fications, surveillance requireaents, in addition, perform Inservice Visual Exami-nation on exposed portions. 14 IM)-5223(a) Class 3 Portion Visual Examination Hydrostatic Testing's Perform Inservice of the service at Hydrostatic iapractical due to Visual Examination water system. Pressure. system design that is once per period. open-ended and employ-ing butterfly valves that were not designed to provide a leaktight boundary. 15 I WC-2500 2 Piping Piping Welds < 3/8" At a mlnlmma terminal Surface and Volunetric Cat. C-F-1 Wetds < 3/8" nominal wall thick- connection wetds of Examinations on 8 C.F-2 nominal wall ness do not require identified exeapted terminal connection resp.'lass Items,C5.10 thickness for surface and volu- welds per Items C5.10 welds of identified and C5.50, piping >> HPS4. metric examinations. and C5.50 of Table exempted welds shall IWC-2500 should be be performed to the examined. requirements of IWC-2500-1. 16 IWB-2500 Class 1 8 2 Voltmetric or surf- Integral Attachments On Class 1 8 2 Integral Cat. B-K-1 Integral Attach. ace examination on on Class 1 8 2 support Attachments, a surface Item B10.10 on piping speci- Class 1 Integral attachments should have examination shall be and IWC- fically support Attachments is re- a surface examination performed on support 2500, Cat. Attachments. quired on Base to insure safety and attachments to IWB and C-C, Item Attachment > 5/8". system integrity. IWC-2500 requirements. C3.20. Class 2 requires a surface examination on Base Attachments 3/4 II
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TITLE: REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 84 111 RELIEF REQUEST NO ~ 1 DEFER RPV EXAMINATIONS TO END OF INTERVAL Components for Which Relief is Requested: The component for which relief is requested is the Reactor Pressure Vessel (RPV) Shell-to-Flange Weld. ASME Requirement from Which Relief is Requested: Table IWB-2500-1, Examination Category B-A, requires that the RPV Shell-to-Flange weld be examined during the first and third periods in conjunction with the nozzle examinations, with at least 50 percent examined during the first period and the remainder by the end of the third period. The required Shell-to-Flange examination is impractical periods specified as it if performed during the can only be accomplished from the flange surface. III. Proposed Alternate Method: During the first two inspection intervals, 100 percent of the accessible length of the RPV welds including the Shell-to-Flange weld were examined at or near the end 'of the interval when the entire examination could be performed from both the flange surface and the vessel wall. This is a more practical approach in that the required examinations from both surfaces can be performed at the same time. During the third interval, 100 percent of the accessible length of all RPV welds including the shell-to-flange weld will be performed at or near the end of the interval when all the required examinations can be performed at the same time.
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TITLE> REY, QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 85 111 RELIEF REQUEST NO ~ 2 I ~ Components for Which Relief is Requested: The components for which relief is requested are the RPV Nozzle-to-Vessel welds and Nozzle Inside Radius Sections. ASME Requirements for Which Relief is Requested: Table IWB-2500-1, Examination Category B-D, Item B3.90, Nozzle-to-Vessel welds allows partial deferral.
"If examinations are conducted from inside the component and the nozzle weld is examined by straight beam ultrasonic method from the nozzle bore, the remaining examinations required to be conducted from the shell inside diameter may be performed at or near the end of each interval."
Examination Category B-D, Item 3.100 Nozzle Inside Radius Sections, does not allow deferral to the end of the interval, and requires (footnote 2) 25 percent to 50 percent of the nozzles to be examined during the first period, with the remainder to be examined at the end of the interval. Examinations from the nozzle bore and nozzle inside radius examinations can only be performed on two (outlets) of the six major nozzles without removal of the core barrel. The mechanized examination of the two accessible nozzle and inside radius sections is quite expensive, and the nozzle-to-vessel examination is only a partial examination from the nozzle bore. From a technical position considering the progress which is being made in ultrasonic examination equipment and techniques and for the correlation of data obtained from the bore with that obtained from the shell, it is highly desireable to perform both examinations at the same time.
TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 86 111 RELIEF REQUEST NO ~ 2 (Con~t) III. Proposed Alternate Method: Rochester Gas & Electric (RG&E) proposes to perform both nozzle-to-vessel examinations (from the nozzle bore and from the shell inside diameter) at or near the end of the interval. The nozzle inside radius examinations will also be performed at this time. This more practical approach will allow all the required examinations to be performed at the same, time on all the nozzles and nozzle inside radii.
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TITI E: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 87 111 RELIEF REQUEST NO. 3 Examination Requirement for Which Relief is Requested: The ASME Boiler and Pressure Vessel Code, Section XI, 1986 Edition, IWA-1400(f), requires an arrangement with an Authorized Inspection Agency to provide inspection services. In addition, the Code requires that certain administrative functions be performed by the "Enforcement Authority" and "Authorized Nuclear Inservice Inspector." Proposed Alternative: Ginna Station is located in the state of New York. This state has not endorsed ASME Codes and therefore does not provide administrative organization and controls such as "Enforcement Authority," "Authorized Nuclear Inservice Inspector" and "Reporting Systems." However, Ginna Station's Quality Assurance Program does provide equivalent administrative control. Therefore, RG&E requests that Ginna's Station Quality Assurance Program be used in lieu of Code administrative functions. Rochester Gas & Electric's program for the inservice inspection, governed by the R.E. Ginna Station Quality Assurance Manual, contains the requirements and responsibilities for implementation of the program and procedures. The procedures have been prepared and approved by the responsible organizations within Rochester Gas & Electric (e.g., Ginna Station, Engineering, Materials Engineering and Inspection Services, Electric Meter and Laboratory and Purchasing) . Approved procedures will be implemented to control the standards for examination evaluation. These procedures include the identifications of the organization performing the inspection, description of the method of inspection to be used, acceptance and rejection criteria, and requirements for providing evidence of completion and certification of the inspection activity.
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TITLE) RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL .INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 88 111 RELIEF REQUEST NO.3 (Con~t) In addition, procedures are developed by Ginna Station to prescribe the disposition of nonconformances. The procedures implemented for the repairs, the retest procedures and the test results will be reviewed by the Plant Operating Review Committee. The members of this committee include technically qualified staff
. personnel.
Examination techniques have been established with written requirements and incorporated in'ccordance into written procedures. Qualifications for nondestructive test personnel are in compliance with Regulatory Guide 1.58, "Qualification of Nuclear Power Plant Inspection, Examination and Testing Personnel." Records and reports of the inservice inspection will be developed and maintained by Rochester Gas and Electric and include such items as examination plans and schedules, examination of results and corrective actions. The functions of the authorized nuclear inservice inspector, namely their review and verification of inservice examinations, personnel qualification and equipment certification during the annual outages at Ginna Station will be performed by personnel of the Hartford Steam Boiler Inspection and Insurance Company. The qualifications of the inspectors, inspections specialists and inspection agency are in compliance with the Code.
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TITLE< REV. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 89 111 RELIEP REQUEST NO ~ 4 Components for Which Relief is Requested: Each of the 27.5 inch diameter recirculation loops at R.E. Ginna has a Class 1 Reactor Coolant Pump. The function of these two pumps is to provide forced circulation through the RPV core during normal reactor operation. Code Requirement for Which Relief is Requested: Table IWB-2500-1, Examination Categories B-L-1 and B-L-2 require volumetric examination of casing welds and visual examination of internal pressure boundary surfaces of one pump case in each of the pump groups performing similar system functions each inspection interval. These examinations are impractical for the reactor coolant pumps at Ginna Station and relief is, therefore, requested. A. Supporting Information The two reactor coolant pumps (RCP) for R.E. Ginna are Westinghouse Model 93 pumps. Each pump casing is fabricated by welding four stainless steel (SA351 CF8) castings together. Thus, there are 3 circumferential pressure-retaining welds that are to be volumetrically inspected in accordance with Category B-L-l. 2 ~ The unsuitability of ultrasonic examination was demonstrated during the "A" reactor coolant pump examination in 1980. An attempt was made to determine the wall thicknesses using ultrasonic examination, the casing welds must be inspected using the miniature linear accelerator (MINAC). 3 ~ Radiographic examination using the MINAC was performed on the R.E. Ginna "A" RCP during the Spring 1981 refueling outage. In addition, the same type of examination has been performed at several other sites.
TITLE: REV. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 90 111 RELIER REQUEST N0.4 (Con~t) This examination was performed by placing the MINAC inside the pump casing and placing the film on the outside of the pump. To perform the examination, the pump was completely disassembled. Disassembly to this extent is far beyond any disassembly expected for this examination. Also, insulation on the casing exterior was removed for film placement. Additionally, the pump bowl must be dry for installation of the MINAC. Therefore, all fuel assemblies were removed from the reactor vessel and the vessel water level lowered to below the nozzles. Complete disassembly of the pump was also required to conduct the VT-1 examination in accordance with Category B-L-2. 4 ~ No problems have been found with the welds at R.E. Ginna or other sites.'dditionally, no problems have been found during the Category B-L-2 visual examination. The visual examination was conducted at R.E. Ginna by using the video camera on the MINAC. The whole body exposure to personnel during the Spring 1981 directly attributable to the RCP "A" examinations 93,067 millirem. This does not include the dose received during the complete core unload to get the plant in condition for the RCP disassembly. V
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TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 91 " 111 RELIEF REQUEST NO.4 (Con~t)
5. The nuclear industry has been successfully applying leak-before-break concepts to primary loop and Class 1 auxiliary piping systems of commercial nuclear power plants.
Currently, the analyses supporting such concepts comes under the review of the Nuclear Regulatory Commission by General Design Criteria-4 (GDC-4). There are eight different models of RCP's in Westinghouse-type PWRs . Model 93 methodology used in the analyses is consistent with that recommended in Vol. 3 and GDC-4. A finite element NUREG'061, stress analysis model for the Model 93 pump was developed. The RCP casings are cast stainless steel. The chemistries of each heat of material used in the pumps were used to determine the fracture toughness. The phenomenon of thermal aging was addressed. The program successfully demonstrates that leak-before-break analyses are applicable to all primary pump casings of all Westinghouse design PWRs for which the screening loads
'are reasonably applicable and the fracture toughness are known.
6. We believe that performing a volumetric examination of the Ginna Station Unit 1 RCP casing welds and a visual examination of the interior pressure retaining surface of one pump during the third 10-year inspection period does not provide an increase in safety and expected radiation exposure. The following items have been considered:
a ~ Visual examination (VT-2) of the exterior of all pumps during the hydrostatic pressure test required by Table IWB 2500-1 Category B-P.
4/ 0 TIT LE i REV. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL OF 92 111 RELIEP REQUEST N0.4 (Con~t)
b. Perform a visual examination (VT-1) of the external surfaces of the welds of one pump casing.
c ~ Perform a visual examination (VT-3) of the internal surfaces each time pump disassembly is required for maintenance. d 0 Perform an evaluation to demonstrate the safety and serviceability of the pump casing. The evaluation will include: Establishing material properties including fracture toughness values. (ii) thePerforming a stress analysis of structure. (iii) Reviewing of the operating history of the structure (iv) Selection of locations for postulating flaws (v) Determination of a flaw size resulting in the detectable leak rate (vi) Establishing the stability of the selected flaw (vii) Demonstration that a postulated through-wall flaw which yields detectable leakage remains stable for all design loadings, with a margin of 2 on flaw size
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42 528 TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 93 111 RELIEF REQUEST NO.i (Con~t) NOTE: In making this assessment, thermal aging embrittlement and any other processes which may degrade the properties of the pump casing during service will be considered.
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TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 94 111 RELIEF REQUEST NO 5 I ~ Components for Which Relief is Requested: Class 1 valves requiring valve body internal VT-3 examination. Size
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10 842A Darling/Check 10-SI2-2501-A 10 842B Darling/Check 10A-SI2-2501-B 10 867A Darling/Check 10-SI2-2501-B 10 867B Velan/Gate 10A-SI2-2501-B 10 700 Velan/Gate 10A-RCO-2501-A 10 701 Velan/Gate 10A-AC7-2501-A 10 720 Velan/Gate 10A-AC7-2501-B 10 721 Velan/Gate 10A-AC7-2501-B 853A Velan/Gate 6A-RC-2501-A 853B Velan/Gate 6A-RC-2501-B 6 852A 6A-RC-2501-A Velan/Check'elan/Check 852B 6A-RC-2501-B ASME Requirement for Which Relief is Requested Table IWB-2500-1, Examination Category B-M-2, requires an internal VT-3 examination on at least one valve within each group of valves that are of the same size, constructional design (such as globe, gate or check valves) and manufacturing method, that perform similar functions in the system. This relief request is based on the following points: 1~ to complete the subject examination, unnecessary expenditures of man-hours and manrem are required with essentially no compensating increase in plant safety, and
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TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 95 111 RELIEF REQUEST NO.5 (Con~ t) 2 ~ the structural integrity afforded by valve casing material utilized will not significantly degrade over the lifetime of the valve. Based on data compiled from a plant similar in age and design to Ginna Station, it is expected that approximately 100 manhours and 5 manrem exposure would be required to disassemble, inspect, and reassemble these vales. Performing this visual examination under such adverse conditions, high doses rate (30-40 R/hr), and poor as-cast surface conditions, realistically provides little additional information as to the valve's casing integrity. The valves material, a high-strength cast stainless steel (ASTM A351-CFS), is widely used in the nuclear industry and has performed extremely well. The presence of some delta ferrite (typically 54 or more) substantially increases resistance to intergranular stress corrosion cracking. The delta ferrite also helps the material to resist pitting corrosion in chloride containing environments. A RG&E feels that adequate safety margins are inherent in the basic valve design and that the public's health and safety will not be adversely affected by not performing a visual examination of the valve internal pressure boundary surfaces. Additionally, this visual examination adds little or no value to the overall safety of the plant and subjects plant personnel to unnecessary radiation exposure. Therefore, a request for relief from this requirement is sought.
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TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 96 111 RELZEP REQUE8T NO.5 (Con~ t) III. Proposed Alternative Method: As stated above, RG&E does not believe that the visual examination required each ten-year interval is warranted. However, as standard maintenance practice dictates, when these valves are disassembled for maintenance purposes, a visual examination of the internals and internal pressure boundary surfaces will be performed, to the extent practical.
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TITLE) REV. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 97 111 RELIER REQUEST NO ~ 6 Component for Which Relief is Requested: The radioactive waste hold-up tank in the waste disposal system provides a means of storing contami-nated water that has been used in the operation of the nuclear power plant. The waste disposal system and waste hold-up tank may be required to function in all modes of reactor operation including cold shutdown and refueling. ASME Requirement for Which Relief is Requested: Table IWD 2500-1, Examination Category D-B, Item No; D2.10, requires VT-2 examination of the waste hold-up tank at hydrostatic. testing levels (at least 1.10 system pressure) during each interval as well as VT-2 examinations at nominal operating pressure during each period. The design of the waste disposal system is such that contaminated water is stored in the waste holdup tank until such time as the level of contamination is below the limits for discharge. At this time the holdup tanks may be reavailable for use by emptying the stored liquid. Several important systems within the chemical volume and control system drain into the waste disposal system hold-up tanks. These are the volume and control tank drains, reactor coolant letdown system, reactor coolant drain tank discharge, and the demineralizer system drains. If the tank was to be hydrostatically tested filling with water and pressurizing to 1.10by system it pressure, the hold-up tank would be rendered useless. The plant would then be potentially put into an unsafe condition for any abnormal plant function and startup occurred without a holdup tank being if available.
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42 529 TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 98 111 RELIEF REQUEST HO. 6 (Con~ t) Since this hold-up tank constantly stores liquid, any degradation of the tank material would show up prior to it becoming a problem. RG&E believes that hydro-statically testing the rad-waste hold-up tank puts Ginna's plant in an unsafe condition and therefore a request for relief from this requirement is sought. III. Proposed Alternative Method: A Visual VT-2 examination shall be performed once every period with the system at normal operating pressure to verify continue structural integrity.
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T IT I.E: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE FOR THE 1990-1999 INTERVAL GINNA STATION 99 ill RELIEF REQUEST NO ~ 7 Components for which Relief is Requested: CVCS, Three Charging Pumps and Discharge Piping to Discharge Isolation Valves. ASME Requirements for which Relief is Requested: IWC-5222(a) System Hydrostatic Test; The system hydrostatic test pressure shall be at least 1.10 times the system pressure Psv for systems with Design Temperature of 200'F (93C) or less, and at least 1.25 times the system pressure Psv for systems with Design Temperature above 200'F (93C). The system pressure Psv shall be the lowest pressure setting among the number of safety or relief valves provided for overpressure protection within the boundary of the system to be tested. This corresponds to a test pressure of 3420 psig. The charging pumps have a minimum hydrostatic test pressure limitation on the seals of 2400 psig, as specrified by the pump manufacturer. As a result, the pumps and associated discharge piping to the first isolation'valves cannot be tested to the required Code Test Pressure. III. Proposed Alternate Method: During the hydrostatic test and associated VT-2 examination, the charging pumps and associated discharge piping to the first isolation valves will be tested at a pressure of 2400 psig.
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TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 100 111 RELIEF REQUEST NO ~ 8 Components for Which Relief is Requested: RCS Overpressure Protection Nitrogen Accumulator System Valves PCV 430 and PCV 431C ASME Requirements for Which Relief is Requested: IWC-5222(a) System Hydrostatic Test; The system hydrostatic test pressure shall be at least 1.10 times the system pressure Psv for systems with Design Temperature of 200'F (93C) or less, and at least 1.25 times the system pressure Psv for systems with Design Temperature above 200'F (93C). The system pressure Psv shall be the lowest pressure setting among the number of safety or relief valves provided for overpressure protection within the boundary of the system to be tested. This corresponds to a test pressure of 137.5 psig. The diaphragms in the operators of the subject valves are only designed to withstand a maximum pressure of 105 .j)sig, and therefore cannot be tested to the required Code test pressure. III. Proposed Alternate Method: The RCS overpressure nitrogen accumulator system will be tested to the Code requirements up to the flex connection to the valve operator. Operability of the diaphragm and operator is verified by valve testing requirements. In addition, an inservice pressure test at operating pressure will be performed once each inspection period on the piping, including the diaphragm.
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42 528 TITLE: REV. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 101 111 RELIEP REQUEST NO ~ 9 Components for Which Relief is Requested: Main Steam Secondary Side of Steam Generator and Downstream Piping to Class Boundary. ASME Requirement from Which Relief is Requested: IWC-5222(a) System Hydrostatic Test; The system hydrostatic test pressure shall be at least 1.10 times the system pressure Psv for systems with Design Temperature of 200'F (93C) or less, and at least 1.25 times the system pressure Psv for systems with Design Temperature above 200'F (93C). The system pressure Psv shall be the lowest pressure setting among the number of safety or relief valves provided for overpressure protection within the boundary of the system to be tested. Since the design temperature of the Main Steam system is greater than 200'F, the test pressure is required to be 1.25 times Psv, or 1356 pslgi A pressure differential limitation of 800 psig between the primary and secondary side of the Steam Generator has keen adopted. This was established early in plant life due to the experiences of some plants with primary side tube sheet cladding separation. To maintain this 800 psig differential, and the required pressure on the secondary side, the primary system must be heated up to a minimum of 160'F which would result in a problem with heat balance and a potential operational problem during implementation of the test procedure. The administrative controls necessary to assure a proper and safe test and the complexity required for the test procedure result in a situation that should be minimized. In addition to the Section XI volumetric and surfaces examination requirements, the piping is part of the augmented inspection program since high energy break criteria. it falls within the
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TITLE: REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 102 111 RELIEF REQUEST N0.9 (Con~t) A letter was submitted to Dennis L. Ziemann Chief Operating Reactor Branch N2, USNRC, Dated: November 8, 1979, requesting relief.
Subject:
System Pressure Test Restriction for Steam Generator and associated Feedwater and Main Steam piping, R.E. Ginna Nuclear Power Plant N1, Docket No. 50-244. III. Proposed Alternate Method: Test. the secondary side of the Steam Generator and associated Main Steam piping at a pressure of 1194 psig, which corresponds to 1.10 times the Psv setting. These components are inside containment and any significant leakage would be detected by various leakage monitoring systems during plant operation.
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~2 528 TITLE: REY.
QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE FOR THE 1990-1999 INTERVAL GINNA STATION
,h 103 ill RELIEF REQUEST NO ~ 10 Component for Which Relief is Requested:
Feedwater, Standby Auxiliary Pump recirculation line between AOV 9710A, AOV 9710B and their associated downstream flow orifices. ASME Requirement from Which Relief is Requested: IWD-5223(a) System Hydrostatic Test; The system hydrostatic test pressure shall be at least 1.10 times the system pressure Psv for systems with Design Temperature of 200'F (93C) or less, and at least 1.25 times the system pressure Psv for systems with Design Temperature above 200'F (93C). The system pressure Psv shall be the lowest pressure setting among the number of safety or relief valves provided for overpressure protection within the boundary of the system to be tested. For systems (or portions of systems) not provided with safety or relief valves, the system design pressure Pd shall be substituted for Psv. In order to hydrotest this piping to Section XI requirements, the pressure reducing flow orifices downstream of AOV 9710A & B would require removal and blank flanges installed. System piping does not provide an isolation valve between the orifices and the Condensate Supply Tank. A significant reduction in tank level would be .required to facilitate orifice removal, which is considered to be impractical. III. Proposed Alternate Method: The Class 3 portion of this piping shall be VT-2 examined at operational discharge pressure during functional testing which is performed once each period.
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TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 104 111 RELIEF REQUEST NO ~ 11 Component for Which Relief is Requested: CVCS, Boric Acid Filter (CSFLBA) and all piping between valves 347, 348A and 349A. ASME Requirement from Which Relief is Requested: IWD-5223(a) System Hydrostatic Test: The system hydrostatic test pressure shall be at least 1.10 times the system pressure Psv for systems with Design Temperature of 200'F (93C) or less, and at least 1.25 times the system pressure Psv for systems with Design Temperature above 200'F (93C). The system pressure Psv shall be the lowest pressure setting among the number of safety or relief valves provided for overpressure protection within the boundary of the system to be tested. For systems (or portions of systems) not provided with safety or relief valves, the system design pressure Pd shall be substituted for Psv. The hydrostatic test pressure necessary to satisfy Sec5ion XI requirements will exceed the limits for the safe working pressure on the Boric Acid Filter housing flange gaskets. III. Proposed Alternate Method: The Boric Acid Filter and associated piping shall be VT-2 examined, at full operational pressure during inservice testing which shall be performed once each period.
am TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 105 111 RELIEF REQUEST NO ~ 12 Component for Which Relief is Requested: Emergency Diesel Generation: Starting Air including receiver tanks and associated piping. 2 ~ Fuel Oil Transfer pumps, suction and discharge lines including miscellaneous lines terminating at oil storage tanks. 3 ~ Jacket Cooling Water system including miscellaneous line terminating at cooling water expansion tanks. ASME Requirement from Which Relief is Requested: IWD-5223(a) System Hydrostatic Test; The system hydrostatic test pressure shall be at least 1.10 times the system pressure Psv for systems with Design Temperature of 200'F (93C) or less, and at least 1.25 times the system pressure Psv for systems with Design Temperature above 200'F (93C). The system pressure Psv shall be the lowest pressure setting among the number of safety or relief valves provided for overpressure protection within the boundary of the system to.be tested. For systems (or portions of systems) not provided with safety or relief valves, the system design pressure Pd shall be substituted for Psv. Only portions of the piping associated with the components identified above are capable of being pressure tested. The Air Start System pressure test would require termination prior to reaching the engine skid to preclude administrating air to the Air Start Motors. This would leave that portion of piping between the Air Start Motors to the first isolation, prior to reaching the engine skid, untestable.
TITLE: REY. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 106 ill RELIEF REQUEST NO ~ 12 (Con~t) The Diesel Fuel Oil Transfer system would require flange connection disassembly and the installation of blind flanges to isolate the Diesel Oil Storage Tank, which is vented to.atmosphere, and the Day Tank where no means is provided to isolate the transfer pump discharge piping at a point close to the day tank. Additionally, the overflow piping form the day tank to the storage tank, which is identified as Class 3, has not isolation valves installed and is vented to the atmosphere. The Jacket Cooling Water System would require isolating the Cooling Water Expansion Tank, due to vents to the atmosphere, which would include most of the piping subject to pressure testing. Due to the amount of piping within the class boundary which is unable to be pressurized, testing in accordance with Section XI requirements would not prove system integrity over and above the existing Surveillance Inservice and Functional Testing. III. Proposed Alternate Method: Inservice Testing shall be performed on the Air Start System at least once each period in accordance with the requirements of Section XI. Additionally, once each quarter a pressure decay test shall be performed on the air receiver to verify check valve operability in the reverse direction for the air receiver inlet check. System Functional Testing shall be performed at least once each period on the Diesel Fuel Oil Transfer and Jacket Cooling Water Systems in accordance with the requirements of Section XI. In addition to the testing discussed above, Technical Specifications 6.4.1 requires surveillance testing to be performed on a monthly basis. Such as, verifying operability of the fuel oil transfer pumps and verifying that the diesel starts from normal standby conditions.
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TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 107 111 RELIEF REQUEST NO ~ 13 Components for Which Relief is Requested: Non-ISI classified systems, which do not carry radioactive gases or fluids, that contain line penetrating primary containment. ASME Requirement 'from Which Relief is Requested: IWC-5222(a) System Hydrostatic Test; The system hydrostatic test pressure shall be at least 1.10 times the system pressure Psv for systems with Design Temperature of 200'F (93C) or less, and at least 1.25 times the system pressure Psv for systems with Design Temperature above 200'F (93C). The system pressure Psv shall be the lowest pressure setting among the number of safety or relief valves provided for overpressure protection within the boundary of the system to be tested. The safety function of these lines is to become part of the containment isolation system during periods when containment isolation is required. Therefore, the pressure testing requirements should be based on the vontainment system design not the associated process system design requirements. III. Proposed Alternate Method: Test these lines in accordance with 10CFR50 Appendix Z, Reactor Containment Leakage Testing for Water Cooled Power Reactor commensurate with the safety function the line performs in accordance with Technical Specification, Surveillance requirements. Additionally, at least once each period exposed portions of the lines penetrating primary containment will be examined during normal system operation.
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TITlE) REV. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 108 111 RELIEF REQUEST NO 14 Component for Which Relief is Requested: Service Water, All pressure retaining components within the Class 3 portion of the Service Water System. ASME Requirement for Which Relief is Requested: IWD-5223(a) System Hydrostatic Test; The system hydrostatic test pressure shall be at least 1.10 times the system pressure Psv for systems with Design Temperature of 200'F (93C) or less, and at least 1.25 times the system pressure Psv for systems with Design Temperature above 200'F (93C). The system pressure Psv shall be the lowest pressure setting among the number of safety or relief valves provided for overpressure protection within the boundary of the system to be tested. For systems (or portions of systems) not provided with safety or relief valves, the system design pressure Pd shall be substituted for Psv. Rochester Gas and Electric believes that the hydro-stat'ic test requirement for the service water system is impractical due to system design which dictates the use of an'open-ended test. The portion of the system downstream of the heat exchanger is also open-ended and cannot be hydrostatically tested. The remaining section of the system is only isolatable by means of butterfly valves which were not designed to provide a leak-tight boundary. With the system as such it would be impractical to expect the leakages other than at the valves could be detected. The ample margin in cooling capacity inherently provided by system design does not dictate the need for an essentially leak-tight boundary. Since the system is in constant operation, its integrity is continually monitored. Thorough inspection of the system each period at the full operating pressure is adequate to detect any gross failures in the system without degrading system safety or availability.
TITLE: RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION 0 MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 109 111 RELIEF REQUEST NO. 14 (Con~ t) III. Proposed Alternate Method: Pressure retaining components within the operational boundary will receive an inservice test at operating pressure and an associated VT-2 examination each period during the interval.
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TITLEi RE Y. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 110 111 RELIEF REQUEST NO ~ 15 Component for Which Relief is Requested: Class 2, IWC 2500-1 Table Examination Category C-F-1 and C-F-2, Items C5.10 and C5.50. ASME Requirements for Which Relief is Requested: Category C-F-1 and C-F-2 (Items C5.10 and C5.50, respectively) for piping welds > 3/8 inches nominal wall thickness for piping > NPS4, a surface and volumetric examination is required on 1004 of each weld requiring examination at each inspection interval. III. Proposed Alternate Method: Rochester Gas and Electric believes as a, minimum that the terminal connection welds of identified exempted welds (< 3/8" nominal wall) should be examined to the requirements of IWC 2500-1 Table, Category C-F-1 and C-F-2, Xtems c5.10 and c5.50 respectively. These exaqinations are identified in the Class 2 Allocation Tables as Augmented Examinations and also are included under the, category C-F-1 and C-F-2. Xn the Program Plan Tables (Supplement 1 to Appendix B). These are identified as C-F-1 or C-F-2 followed by " ". These components are also noted in the instruction field.
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TITLE: RE V. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL 111 111 RELIEF REQUEST NO 16 Components for Which Relief is Requested: Class 1 and Class 2 Integral Attachments on Piping specifically to Support Attachments. ASME Requirements for Which Relief is Requested: For Class 1, Integral Attachments on piping as indicated in IWB-2500-1, Category B-K-1, Item B10.10, requires volumetric or surface examination be performed on Base Attachment Thickness ) 5/8". For Class 2, Integral Attachments on piping as indicated in IWC-2500-1, Category C-C, Item C3.20, requires a surface examination be performed on Base Attachments
) 3/4 II It has been felt that support attachments to the pressure boundary such as gussets and stanchions should have a surface examination performed to insure the safety and integrity of the Class 1 and Class 2 Systems.
III. Proposed Alternate Method: Surface examinations shall be performed on Integral Attachments on piping specifically support attachments once per interval in accordance with IWB-2500-1 and IWC-2500, B-K-1 and C-C, respectively.
REV. PAGE QUALITY ASSURANCE MANUAL 1 OF93A GINNA STATION EFFKTIVE DATE: January 1, 1990 ROCHESTER GAS & ELECTRIC CORPORATION SIGNATURE DATE TITLE: ATTACHMENT A PREPARED BY: p-ao- FP APPENDIX B GINNA NUCLEAR POWER STATION QUALITY ASSURANCE INSERVICE INSPECTION PROGRAM REVIEW FOR THE 1990-1999 INTERVAL APPROVED BY: 7A ATTACHMENT A Line List Introduction In the following Section; Class 1, 2 and 3 Line Lists have been identified and grouped into their associated section. P&ID drawings were reviewed in respect to their class and systematically identified with unique line numbers. Line numbers were then identified with required ASME Section XI Code Information and reviewed according to their exemption status. Lines that were exempted have their corresponding code exemption stated. Lines not possessing code exemption have been identified with the type of examination required by the code. In all cases, the system and associated P&ID drawing number can be located in the upper left when viewing the Line List Tables. The following line lists have been grouped by class for convenience. P&ID Drawings to support these line lists are located in Attachment B.
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R. E. GINNA NUCLEAR PDUER PLANT Inscrvice Ease<nation Boundary Line List Ihtrd Inspection Interval Class: . Sy'stcnt REACTOR COOIAMI-PRESSURIZER PCID Mot 33013 1250 RGLE GILBERI SllR I ISI Site Ihkns Eaeept ion NDE Linc Mo. Line No. Linc No. f IS. Natrl. (In.) (in.) S@s I s Method I'o 1ccp lnl Line Description/Rcoarks lb.lCb.2S0l RC 200 10 PRZ QtlGE A.3s are lb.0D 1.000 SUR/VOL Y PRZ SURGE LINE 44-BCS 2501 A 4 'C 273 A-13 A3rb 4.DO 0.53 I SUR/VOL T PRZ RELIEF PRZ 10 PCV 434 ~ 4A.BCS.'2501 ~ 4 RC.273 A-15 A376 ,. 4.00 0.5'Sl SURI VOL Plt RELIEF PRt 10 PCV 43S 's3 H Q. 4C.RCS 2SDI 4-RC-1005 A. 12 A3rb 4.00 0.531 CUR/VOL T PRZ RELIEf PRZ.TO RELIEF IIANIFOLD 0 4H 34-RCS-2501 3 ARCS 1005 A- lt A3rb 3.00 0.430 SUR T PRZ RELIEF IIANIfOLD 10 VALVES 515 C 431C gmg 34.lCB-2501.A RC 300 3 'C-1000 A 9 A370 3.00 0.430 SUR Y PRZ SPRAY FRCti LOOPS 10 43IA C 0 344RCS.ZSDI.B RC ~ 300 3 RC.IOOI A-9 'brb 3.00 0.430 SUR T PRZ SPRAY FRCtI LOOPS 10 431A C S 3B.RCB.2SD I 3 RC.1006 A 12 Abrb 3.00 0.430 SU'R T ~ PR't RELIEF MANIFOLD '10 VALVES S1b C 430 3C RCB-2501 lC-300 3 RC 1000 A.9 ASrb 3.00 0.430 SUR PRZ SPRAT fRIRI 431A C 0 10 PRZ MEAD ) Qo
7SA.lCS 2501
.754 ARCS 2S01 ~ 4 N/A M/A A3 74',
A3rb'3'rb 0.75 0.75 0.219 0.219 IN 1220lb) IIIS )220Ib) T Y PRZ RELIEF 10 VALVE 950 PRZ SPRAT ST PASS AT Slb ~HA~
.75a.ltb.tSD'l.l N/A 0.75 0. 219 IN. 1220 lb) T PRZ SPRAT ST PASS AT 5'lr ~.'OON% .7SS RCS-2501 M/A A376 0.75 0. 219 IN-1220 Ib) Y QSGE SANPLF. AT VALVE 952 I4) K ITS H gja
R. E. GINNA NUCLEAR POQER PLANt 85 la 8 Inservice Exseinat ion Boundary Linc List lhlr4 Inspection Interval Class: I Systcnt RESIDOAL NEAt RENOVAL PSID No: 33013 1247 0 RGtE GILSERI QJR I ~ I SI Slee lhkns Except Ion NDE Line No. Line No. Line No. f I G. Net r I. ( In.) {In.) Sasls Method Po leap In7 .Line Descrlptlon/Rcearks 10A-AC7.2501.A AN-2500 'ID.AC-1004 A.15 A376 'l0.00 1. 000 SUR/VOL 7 Rll IRISI VALVE 700 70 VALVE 701 IGA-iC7.250) ~ 0 SI.200 IO.AC. 1001 '.14 A376 10.00 1. 000 SUR/VOL Sl fRCSI VALVE 720 10 COLD LEG 0 , AH Q oNH P g my I Ping& AE) H O 4 to Wg MNMHQ AORS gm~ XAp Pja O n m
~ c R. E. GINNA NDclEAR PlxIER PLANI Inscrvicc Exaeination Boundary Line List
'Ihird )nspcction Interval Class:
Systnal SafETZ INJECTION Pl ID No: 33013.1262 RGLE 0llSERI SINAI I Sl S Itc Thkns Exception NDE Linc No. Linc No. Line No. f ID. Hatr i. IIn.) I in. I Seals Hcthod Po Tcep. In7 Line Description/Rcoerks Z, Sl fRIN ACCIN IDA.512 ~ 2501 A
,'SA. $ 12 ~ '2501-$ $ 1-200 $ 1-100 ID.SI IOOC
10. $ 1-1005 A 16 A 17 A376 A376 10.00 10.00 1.000 1.000 SUR/VOL SUR/VOL T'l TO COLD LEG B fROH ACClN 10 COLD LEG A 2.$ 1.1001 A.19 2. 00 0.3tt 070$ B 10 10" Sl ACCIN DINP 2A-$ 12-2501 $ 1 11D A376 SUR 1 cx3HQ I 2$ - $ 12-2501 S I ~ 210 2-$ 1-1002 A zl A376 2.00 0.3tt SUR T Sl PtNP A 10 NOT LEG B ONH ZC ~ SIZ-ZSOI $ 1.110, 111 2- $ 1.1001 A 20 A376 2.00 0.3$ $ SUR T $ 1 PINP B 10 NOT LEG A g rn g 2D.SI2 F 2501 SI-2IO 2.SI-IOOZ A. 16 A376 2.00 0.3tt SUR T, Sl PINP A 10 1D" Sl ACCIN DINP
.Tsa slz 2501 A N/A A376 0.75 0. 113 IMS 1220ibl T ACCUH A 10 VALVE 0390 .TSa.SIZ-2SDI AS N/A A376 0.75 0.113 IVS-I220IbI T . ACCUH S 10 VALVE BLOB & X A >~
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lf R. E. GINNA NUCLEAR POtrER PLANI Jnservice Eaaolnatlon Boundary Line List
'Ihlrd Inspect ton Interval Closet 2 Systeot AUXILIARY COOLING SPENT fUEL PAID Not 33013 1240 RCtE CILRFRT SIIR I IS) Site 'lhkns Reception NOE Line wo. Line No. Line No. flG. Hatrl. I In.) I ln.) Assis Hethod Po Tests Inl Line Oescrlption/Ressorks 0.35 A312 2.00 0. ISA INC-1222IA) 250 350 Z THIS LINE ACCOUNTEO fOR OH 3301'3.12dd ~
21 ~ CN. dGI CVC 900 2J.CM.ADI CVC.900 8-35 A312 2.00 0.)5t INC-'1222IA) 250 350 Z THIS LINE ACCOUNTEO fOR ON 33013 12dC ~
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R. E. GIRNA NUCLEAR PouER PLANT Inservlce Exanination Sounsary Line List Third Inspect)on Interval Ciasst 2 Systea: AUXILIARY COOLANT PLID Not 33013.1246
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RCIE Line ko. GILSFRT Line No. suR I Line uo. ISI 'lee I IS. Natrl. (In.) Thkns ( In.) Eacept Ion Seals NDE iiethod Po leep lnT Line Descript 1onlaecvsrks ba.ac-)52 CC.200 A53 6.00 0.280 IUC-)222(C) 90 70 N vaLvE b13 To pEN 131. . bs.ac-)52 Cc-220 A53 ". 6.DO 0.280 Iuc 1222(C) 90 70 N PEN 130 'IO VALVE blC ~ ca.ac.152 CC-C SO 8-29 ASS C.OO 0.237 I uc. 1222(A) 9O TO N VALVE 7508 IN cout TO RocR PEN 128. 4s.ac- Is2 CC.625 8-30 A53 4.00 0.237 luc-1222(A) 90 70 N VALVE 750A To RDCR SEFORE PEN 127 IN CON 3a.ac 152 CC-220 ASS 3.00 0.216 IIC.1222(A) 90 70 N PEN 125 TO VALVE 759S. 3s ac.152 CC.22D A58 3.00 0.216 luc. 1222(A) 90 70 8 PEN 126 '10 VALVE 759A.
)c ac.1$ 2 CC ~ 3)o 6 CC.CSO 8.29 ASS 3.00 0.216 luc-1222(a) Pa To RDCR SEFORE PEN 128 IN CONT TO VAL 7C9S. )D.ac ~ 152 CC.625 6 CC-330 ~ .30'53 3.00 0.216 ItC 1222(a) 9D 70 N RDCR SEFORE PEN 127 IN CONT TO VAL"749A.
2a ac-152 A53 2.00 0.'ISC luC-1222(A) 9a Ta PEN 12C TO VALVE 7C3A. 2s ac-IS2 CC-220 A53 2.00 0.154 luc-1222(a) 90 70 N PEN 124 10 VALVE 745 ~
.7$ a-ac-IS\ CC-300 A53, D.75 0.113 IUC-1222(a) 90 70 N 3C AC-152 10 PIPE CAPo (VALVE 2741)e .75s-ac-152 CC.300 A53 0.75 0.113 ItC 1222(a) 90 70 N 3D.AC-152 10 Pl)'E CAP ~ (VALVE 262'I). .7Sc-ac-152 CC.200 A53 0.75 0.113 Iuc.1222(A) 90 70 N 6A AC-152 To PIPE CAP (VALVE 272C) .T5D-ac-152 CC.220 A53 O.TS 0.113 luc-1222(A) 70 N 68 AC '152 To PIPE CAPo (VALVE 2726) ~
R. E. Gluua NUCLEAR POMER PLANT Inscrvice Exaainatlon Beanery Line List Thtrd Inspection Interval Classt 2 Systcet AUXILIARY IEEDVATER PAID Not 33013-1237 0 RGIE 0 IL 4ER'I SMR I ISI S I tc Ihkns NDE Linc No. Line No. Line No. fl$. Natrl. (in.) (In.) Hcthod Po )cela In) Linc Descrlptlon/Rccacrks 3A-fM 900-IA AIM 500 fM.100'I 4 ll A106 3.00 0.300 IMC-)222(A) 715 505 Y 'IRIS LINE ACCOUNTED FOR OH 3'3013 1236. 3a ~ fM 900.14 AfM (00 fM-1005 4-13 A106 3.00 0.300 INC F 1222(A) 715 505 Y THIS LINE ACCOUNTED fOR ON 33013-1236. M'HQ 34 ~ IM.90D.IA AfM 500 fM 100\ $ -11 A)06 3.00 0.300 IMC-1222(A) 715 505 THIS LINE ACC(XJNIED fOR 33013.1236. QQM gag Z ON 34 'M"900-1$ AfM-(00 fM.1005 $ -13 A106 3.00 0.300 IMC-1222(A) 715 5D5 Y THIS LINE ACCOUNTED fOR OH 330'l3 1236. 5~4<~ oalgte +g, L()XWH ~ t()OOR ~ HSING >
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a 1 ~ ~ R. E. GINNA NUCLFAR PDMER PLANT lnservlce sean(nation Boundary Line List Ihird Inspection Interval Cl ~ tst 2 Systcot CDNTAINNEMT SPRAY PllD Not 3)D13 ~ 1261 RGIE GILS'ER I SMRI Isl Slee lhkns Exec(tt lon MDE Line No. Line No. Line No. f ID. >>ctrl. (In.) (In.) Basis ltethod I'o Tacit lnl Line Description/Renorks CC.SI-301 CS.150 A312 C.oo 0.2)l IMC.1221(F) 20% 70 N 3A Sl 301 TO 61-$ 1-301. to'Sl 301 'CS-SOa 8 C7 C.oo O.ooa Iuc.)RRI(A) 205 ra cs Pt>>tP To 6)-SI ~ 301 CE $ 1.301 Cs F 250 A312 C.OO 0.2)l luC-1221(f) 205 70 MD 6XC RDCR OM 38 Sl )ola ~HQ O@H Cf.si.301 0. 217 Iuc.1221(f ) 10 6XC RDCR ON 6P Sl 301. 3 ~ $ 1-151 CS-250 A312 C.oo 3.00 0.000 IMC-)221(E) 205 30 70
'70 N CX) RDCR RMSI TO FIRsf fLANGE.
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)A.SI-)al CS 'I50 A312 3.00 O.R16 luC- 1221(f) 205 70 N CS-SI-)01 TO CC-S!-301.
, )s Sl'301 CS 2$ 0 A) IR 3.00 0.216 luc.1221(f) Ros ro CX) RDCR ON CE-Sl 301 10 CX3 RDCR ~
)c.sl.)al 3.00 0.000 luC ~ 1221(A) VALVE 66)S 10 SPRAY ADDITIVE 'TAML';
2 $ 1.151 2i-Sl ~ 151 R.oa 2.00 0.15C 0.15C IMC 1221(E) 30 70 RMST 10 VALVE 69)A. RUST '10 VALVE 6938. I Plop~ IMC ~ 1221(E) 30 70 I() H 2s-S I- IS I 2.00 0.15C IMC IR21(E) 30 'la RMSI 10 VALVE 69CS. o4 10 VALVE 606. i tn 2C.SI ~ 151 2D.SI '151 CS 520 A312 2.00 2.00 0.'ISC 0.15C Iuc 1221(E) ItlC ~ )221(A) 30 30 70
'70, RUST 10 Sl 151 TO VALVE 673C L()
ag KIT) Hg 2(-SI 301 cs 100 A31R 2.00 0.15( Iuc- 1221(F) 205 70 II eo-sl-301 To 6N-sl-3ol. I() OOMPH Rf.sl ~ 301 Cs. 100 A31R R.oa 0.15c luc.1221(A) 205 . 70 . N 2E-Sl-301 TO VALVE 675A. 2G ~ Sl ~ 301 . C5 ~ 100 A31R R.oo 0.15C IMC 12RI(A) 205 70 N 2E-SI.301 TO VALVE 6758 ~ 2N ASIA 301 CS. I GO A312 2.00 0.15C INC 1221(A) 205 70 N 2E.sl-)ol To vikvk brea.
,2l.sl.)ol CS 100 A312 2.00 0.15C IMC 1221(A) 205 70 N 2E.SI 301 TO VALVE blbA: M RJ ~ SI ~ 151 CS 510 8 19 A)12 2.00 0.15C IMC-1221(A) Ro) ro bS.SI 151 TO CS EDUCTOR RK.SI ~ 301 cs. 510 A312 2.00 0.15C ltC.IRRI(A) 205 70 ~ 6C-$ 1-301 '10 VALVE b59A. <OR 2(K.SI )Ol 0.1st luc. 122 I (A)
CS.5 10 A)12 2.00 Ros 70 ~ Cs EDUCTORA TO RK-Sl 301 go H 2L-SI.151 2>> sl-301 C$ .510 CS.510 8.19 A312 A)12 R.oa 2.00 0.15C 0.15C luC.1221(A) IMC-IRRI(A) 205 205
'la 70 CS EDUC'IOR 1 TO CS EDUCTOR BA-$ 1-151 TO CS EDUCTOR.
2 IR RN Sl.)al Cs 510 ~ A)12 2.00 0.15C IIC-1221(A) 205 70 CS EOUCTOR 2 TO 2N-SI-)O1. 2P.SI 15'I CS 510,CS F 520 A)12 2.00 0.15C IMC ~ 1221(A) 2L-$ 1-15'I 10 VALVE S738. 24 ~ SI )OI CS.510- A)12 2.oa 0. 1st luc. IRRI(A) bs-Sl-)0) '10 VALVE 659S. 24A.SI 1$ 1 CS.520 A312 2.OO D. ISC INC 1221(A) 2P.SI-ISI SY VALVE 673S 10 VALVE bl)D. Ri.si 151 Cs 520 A)12 2.00 0.15c Iuc.1221(A) 2" TEE DN P-$ 1-151 PAST VALVE RS.SI 151 cs.SRa A3) 2 2.00 0.1st Iuc ~ 12RI(A) 2P-SI.151 PAST VALVE S368'TO 'IST 2" TEE. N Eh N ts
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R. E. GINNA NCLEAR PO$ IER PLANT Inservice Exaaination Boundary Line List
'Ihird Inspection Interval CI asst 2 Syste$ $ : CONTAINMENT SPRAY PSID uo: 33013-12dl H
RCCE GILBERT stIR I ISI site Ihkns Except ion ND( 0 Line No. Line uo. Lln>> No. f IS. Hatrl. (In.) (in.) Basis Method Po leep ln1. Line Description/Retaarks 10.$ 1 151 RXR.(50 lb.SI -200( S-19 ~ A312 lb.00 0.165 IIC-1221(E) 30 70 RIIST TO lsl IDXB B 10XS RDCR. 108-AC.SOI lb.00 0. 000 Tuls LluE Acccuxldo foR N 330)3-12(7. 8 ~ S I.151 RXR-CSO 8-19 A312 B.OO D. I(6 IIIC.1221(E) 30 70 IN 10 Sl 151I ACTUALLY A TEE. BA-sl -151 8-19 ACCCUMTED s)HQ
68. $ 1-151 Rue CSO RRR C50 10 SI 151R 8.19 A312
'A312 8.00 8.00 D. ICB IIC-1221(E)
IlC-1221(E) 30 70 . 6A-S!-151 10 Cs PUHP. OWH m D. IC8 30 70 SB.SI.151 To CS PIAIP XI bc-SI ~ 151 8.00 0.000 IBIS LINE ACCCUMTED FOR N 33013.1247. g ba Sl ISI RRR.CSO 6 ~ $ 1.151R 8.19 A312 6.00 0.1(6 IIC.1221(E) 30 70 - lb.SI-151 TO RDCR PAST VALVE 858$ ~ 68 Sl-'l51 RKR (50 lb.Sl.'ISIR 8-19 A312 6.00 O. I Cd IIC-1221(E) i. 30 70 10 SI '151 To VALVE 85bA SC.SI.301 500 - PCS 8-Cb AC03 6.00 0.280 SUR/VOL 205 To cA-sl-151 To lsl exexe TEE SD-$ 1-30) C$ 500 8-ce Aco) 6.00 0.280 - sUR/voL 205 70 .SC.SI.301 'lo VALVE 860A. SDD $ 1-301 CS.SDO 8-ce 6.00 - Aco3 0.26D IMC 122I(F) 205 70 YALYE 860A To 1sT 6" TEE BEfoRE v.ds2Aa SE.SI 301 Cs 500 8-ce Aco) 6.00 0.280 SUR/VDL 205 70 . 1$ 1 TEE N LINE SC SI-301 TO VALVE 8608.
'EE Sl 301 Cs 500 8 C6 'C03 d.oo 0.280 IIC-)22)(f) 205 70 VALVE 8608 lo VALVE 862A 6F $ 1.301 500 8.(6 - I() bf < HQ ~no8~
F CS A(03 e.oo 0.280 IlC 1221(f) 205 70 TEE BEFORE VALVE 862A To PEN lbs. SG. $ 1-301 CS ~ IOO,CS '150 S.CB A312 6.00 0.281 IUC-122'llF) 205 70 N PEN 105 TO CS SPRAY RING, du.sl 301 CS. 150 A312 6.00 0.2dl IlC-1221(f) 205 70 SG Sl-301 To CB-SI-301. N ~ 61.$ 1.301 cs 150 . A312 6.00 0.281 INC-1221(f) 205 70 N CC-SI.301 To 60 $ 1-301. SJ.SI-30'I CS.BOO 8-C'7 e.oo 0.280 - ACO) SUR/VOL 205 To cD-sl-3ol To 1sT exdxe TEE SX-$ 1-301 C$ .600 S.C7 A(03 e.oo 0.280 SUR/VOL 205 70 ~ dXSX6 TEE ON dJ.S1-301 To VALVE 8600.
~ SXX-S)-30) CS 500 8 C7 6.00 0.280 IlC-1221(f) -.
AC03 205 70 VALVE 860D To 6" TEE BEFORE VALVE 8628. SL-SI.301 CS-8OO 8 ~ C7 A(03 e.oo 0.260 'lo SUR/VOL 205 70 SX6X6 TEE OM SJ ~ Sl 301 VALVE 860C SIL.S 1.301 CS ~ BOO B.c7 Aco) 6.00 0.2do IIC 1221(F) . 205 70 VALVE 860C TO d" TEE BEfORE VALVE 8628. SH.SI 301 Cs.boo B.C7 AC03 e.oo 0.280 llC-1221(f) - 205 70 SXSXS TEE BEFDRC VALVE 8628 TO PEN 109. SN ~ SI.301 CS.200,$ $ -250 A312 e.oo 0.280 llC-1221(f) 205 70
' PEN 109 To 6 TEE N LOIIER CS RING.
6P-$ 1-301 Cs ~ 250 A312 d.oo 0.2dl IIC.)22)(f) 205 70 N Cf-Sl-301 TO dM-SI-301. bo sl-301
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Cs 250 A)12 6.00 0.2dl IlC-1221(f ) 205 To N eu-sl-3ol To ck-si-3ol. C CM 15'I CVC-1200 'A312 - CA-SI.301 C.oo O.120 30 70 luis LluE AccOUMTED FOR N 33013-12e5. C$ 500 8 CS A312 C.oo 0.000 IIC-1221(A) 205 70 cs PUHP To SC Sl 301 CS-$ 1-301 C$ -150 A312 C.oo 0.237 IUC-1221(f ) 205 70 M 68 Sl 301 To 3A Sl-301 o m C
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I R. E. GINNA WCLEAR POVER PLANT lnservice Exaainet ion Stxncery Line List third Inspection Interval Clsssi 2 O Systea: CVCS IETD(MI PAID No: 33013 126(
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ISI Site Thkns Exception MDE Descript(on/Reeorks RGLE GllSERI SVR I Line No, Line No. Line No. f 18. Metr 1. (In.) (in.) 8osls Method Po leep In) Line 8-36 0.75 0.113 IMC-1222(h) 250 100 .75f CN.&01 '10 V 2233 COMPLETES DTPASS.
.TSG.CN 601 CVC-1000 A312 CVC-1000 8-36 A312 0. 75 0. 113 Itic-1222(A) 250 100 2K CH 601 TO VALVE 207A. .75H.CH 601 A312 0.75 0. 113 I tC-1222(A) 250 100 2K.CH-&01 TO VALVE 2234. .751-CHt&OI CVC.1000 8 36 ttj H Q 2" TEE OM 2N-CH.15'I TO VALVE 2237I .75>.CH. ISI CVC-1000 A312 0. 75 0.083 IlC- 1222(A) 70 100 0@H .75K-CN 151 CVC-1110 A312 0.75 0.083 IlC-1222(A) AO 100 2R CH.IS'I TO VALVE 268A.
flLTER 251.
+0)g .TSL.CN.1$ 1 CVC 1110 '312 0.75 0.083 IlC. 1222(A) AO 100 REACTOR COOLANT TO VALVE
0. 083 llC-1222(A) AO 100 REACIOR COOLANT FILTER TO VALVE 389.
.7SN CN 151 CVC 1110 A312 0.75 .7$ i'CN.1$ 1 A312 0.7$ 0. 053 llC lm(A) 20 100 21 CH 151 TO VALVE 2655 Ts$ H CVC.1110
0. 219 IlC-1222(A) 35 VALVE NCV123 TO VALVE 312. $
.75a.CN-2501 A312 0.75 0.75 0. 000 INC.)222(h) 35 VALVE 312 TO 1EE OM 2V.CN.150.
I-s NO
.75R ~ CH-2501
..7$ S-CN 601 CVC.1000 8.36 0.75 0.113 IlC-'l222(A) 250 100 2K CH 601 STPASS OM VALVES 207C 5 2078. t0HR
.TSI.CH.&01 0.75 0.113 llC- 1222(A) 250 100 2f CH 601 PAST VALVES 703 1 702 0.37 0. 000 INC 1222(h) AO 100 2R.CH-151 TO VAI.VE 989, .37SD.SL 2505 .3756-SL-2505 A312 0.37 0. 083 INC.1222(A) 250 100 2K ~ CH-&01 TO VALVE 985.
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R. E. CIMXA NUCLEAR POQER PLANT Inservice Exon(nation Soundsry Line List Third Inspection Interval CI ~ 55 2 Systexa: NUCLEAR SAHPLIMO PAID Mot 33013-1278 RCIE GILBERT SIDER I ISI Site Ihkns Exception MDE Line Mo. Line Mo. Line Mo. fig. Hatrt. (In.) (in.) Sasis Method Po Tecp Inf Line Description/Re5ssrks .SA.SL-151 0.50 0.000 llC.1222(A) 30 80 ~ VALVE 9998 TO IST .SX.SX.5 TEE. .SS-SL.151 0.50 0.000 llC.1222(A) 30 80 VALVE 969 IO IST .SX.SX.S TEE ~ M 'H,Q .37$ A-CM 1S'I .375A.SL-2505 0.37 0.37 0.000 0.000 llC-1222(A) 30 2235 80 602 THIS LIME IS ACCCUMTED fOR ON 33013.1265 VALVE 966C OUT CONT TO PEH 205 ' OXH go)Z .3758-SL-2505 0.37 0.000 IIC 1222(A) 2235 650 9668 OUT CONT PAST PEN 206 TO V 953. .375C.SL.250$ 0.37 0.000 llC- 1222(A) 2235 650 V 966A OUI COMT PAST PEN 207 IO V 951.
.3750-SL-2SOS .375E SL 2SOS 0.37 0.37 0.000 0.000 AO 250 110 110 IHIS LIME IS ACCOUNIED fOR 'IHIS LIME IS ACCOUNTED IOR OH.33013.1264 ON 33013-126(
QN~
.37$ f SL 250S 0.37 0.000 30 100 IRIS LIME IS ACCOUNTED fOR OH 33013 1265 .37SO SL-2SOS 0.37 0.000 INC.1222(A) 2235 602'02 VALVE 959 TO VALVE 958. .2$ A.SL.'2505 0.2$ 0.000 INC. 1222(A) 2235 ~ PEN 205 PAST DEI.AT COIL IO VALVE 955. .25S-SL.2505 0.25 0.000 IlC.1222(A) 2235 602 ,25A SI. 2505 TO VALVE 998 I() X ITS H g I() 0 0 N +~
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R. E. GINNA NVCLEAR POMER PLANI Inservice Exsaination Sandary Line List Ihlrd Inspection Interval Class: 2 Systen:, POST ACCIDENI SANPLIKQ PAID No: 330I3-1279 RGLE GILSERI SVR I ISI Slee 'Ihkns Exception NDE Line No. Line No, Line No. F ID. Natri. {In.) {in.) Basis method po Veep In) Line Description/Reaarxs 30 60 - 1EE ON .5A-SL-151 8 .58 10 VALVE 4268. .5A-PAS.153 .58 PA$ .2505 0,50 0.50 0.000 0.000 INC-1222{A) INC 1222{A) 30 80,5A PAS-153 10 VALVE A26,
I ~ I I I I I ~ ~ I I I I
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R. E. GINMA Mt)CLEAR PQJER PLANI Inservlco Exaoinat ion Sosndary Line List third Inspection Interval Class: 2 Systoat PNIPS S.VALVES PAID Not 33013-12bl H 0 RGSE GILBERf SVR I ISI Site thkns Exeep! Ion NOE Line No. Line No. Line Mo. fip. Hatrl. (in.) (in.) Basis Hethod Po leep Inf Line Description/Reessrks cs Ptsip 'I 1261 0.00 0.000 Vl 205 20, - Hfp. INGERSOL RAND CS PIMP 2 1261 0.00 0.000 VI 205 70 HfG IMGERSOL RAND axe HQ OCH Vmg Ilg t()KWHR HQQ R 03 R f(3 P3
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Q R. E. GINNA NUCLEAR POVER PLANT Inservicc Exaeination Boundary Line List Third Inspection Interval Class) 2 Systcat PIAIPS S VAIVES PS ID Not 33013 ~ 1262 RGAE GILSERT SVR I ISI s I!e Ihkns 'Except ion NDE Line No. Line No. Line No. FIR. Hatrl. (In.) (In.) Basis Itethod po Tccp In2 Line Description/Rctsarks Sl PtatP A 1262 0.00 0.000 VT 1550 200 HFG. IJORTHINGTOH SI PUHP R 1262 0.00 0.000 VT 1550 200 HfG. VORTHINGTOH 0.00 0.000 1550 200 HfG. WORTHINGTON MMQ si ptsIp c 1262 VT 0CH g rn g o.5 U t()XMH NOON ~ t() Hg H 0 re 3R
R. E. CINNA NUCLEAR POMER PLANT lnservice Exaoinatlon Boundary Line List Third Inspection Interval Closet 2 O'd Systaa: P(NPS 6 VALVES PAID Not 33013-1265 RQIE CILBERT SURI ISI S I ze lhkns Exception NDE No.
'ine Line No. Line No. FIB. Hatrl. (In.) (in.) Basis Hethod Po Tccp ln1 'Line Description/Remarks 0.00 0.000 INC 1222(A) 2(50 100 - HFC. AJAX CNARQINQ Pta(P 1 1265 O.DO 0.000 INC 1222(A) 2650 100 HfG AJAX CNARGINQ Pta(P 2 1265 CNARC INC P(NP 3 1265 0.00 0.000 INC*)222(A) 2450 100 HfG. AJAX 83g I tdn>+
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4 ~ 44 R. E ~ OIMNA NOCLEAR PIXIER PLANT Inservice Exaelnati on eouxtary Line List Third Inspection Interval Classs 2 Systeo: RCS OVERPRESS. PROT. N2 ACCIRI. PAID No: 33013 '263 " ROSE GILBERT 'MRI ISI Site Thkns Exception ROE Line No.,'ine f la. Hatrl. (In.) (In.) Rasls Hethod po Teep In) Line Descript lcq/Reserks Line No. No.
'I PCV (30 TO VALVE 8606A.
1.00 0.000 Iuc-1222(A) IA RCSOP A PCV 431C TO VAI.VE 06068m 1.00 0.000 IlC- 1222(A) 10 RCSOP $ Itl C
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R. E. GINNA NUCLEAR P(XJER PLAN Inservice Exaalnetlon Boundery Line List lhird Inspection Intcrvel Clesst 2 n kd Systeat ~ REACTOR COOLANT PLID Not 33013-1260 0 RGtE GILBERT SNR I ISI Site Thkns Except Ion NDE'ethod Line No ~ Line No. Line No. f IG. Hetrl. (in.) (in.) Besis Po TceTI In) Line Description/Resserks 8.17 A312 6.00 0.280 IHIS LINE ACCCIJMTED FOR OH 33013 1247. 6-AC-601 RHR. IDD 6.RH.201S 8-18 6.00 0.280 IHIS LINE ACCOUNTED fOR OH 33013-1247. 6 RH.2016 A312 6A-AC-60) .RHR 100 0.75 0.000 IIC-1222(A) 2235 80 VALVE 597 TO 1ST 7SX.375 RDCR. IxiH Q .TSA.RC 2501 0.75 0.000 INC. 1222(A) 223 S 80 FLANGE BEfORE VALVE 500A TO.TSX.375 RDCR
.TSR.RC 2501 .75C-RC.2501 0.75 0.000 IIC-1222(A) 0 0 SEAL CHAMBER VENT PAS'I VALVES 598 S 599, .TSD-RC.2501 0.75 0.000 INC-1222(A) 0 100 fLANGE PAST VALVE SV592 TO VALVE SV590o .TSE RC 2501 0.7S 0.37 0.000 0.000 IIC-1222(A)
IIC 1222(A) 0 2235 100 80 FLANGE PAST VALVE SV593 TO VALVE SV591 ~
.7SX.375 RDCR PAST VALVE 595 50~
PlAP
=
37SA.RC 2SOI 3 INC.1222(A) 2235 80 .75X.375 RDCR '10 VALVE 594. )
.3758 RC 2501 0.37 O.DDD L() N < ~H I() OOg~
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R. E. SINNA NUCLEAR POUER PLANT Inservice Exsoinetion Soundsry Line LISt Third Inspection Intervsi Closet 2 Systeat REACTOR CQOLAMT PRESSURIZER PAID Not 33013-1250 0ILSERT SNR I ISI - Site 1hkns Except I on NDE RSSE In') Line Description/Reearks Line Mo. Line Mo. Line Mo. fis. Nstrl. (in.) (in.) Sesis Method Po Tecp INC-1222(A) 40 70 - VALVE 529 SI PEN '121 TO VALVE 2.00 0.000 500'25 2A-RC.151 VALVE 52d ST PEM 121 TO VALVE 441 ~ INC 1222(A) 70
.?5A-RC 'l51 0.?5 0.000 - 33013.1272. es3 H Q 0.75 0.000 INC. 1222(A) 1.5 70 TRIS LINE ACCOUNTED FOR ON OCH .75E.RC l51 .3)5A-RC-2505 0.3? 0.000 INC.IZ22(A) 5 90 - PEM 120 IN CONT IO VALVE 492 OUT COIIT ~
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Q Io )O I R. E. OIMNA NUCLEAR P(XJER PLANT lnservice Exaoinat ion BounCary Line List third Inspection Interval Clessl 2 Systcn: RESIDUAL MEAT REMOVAL PAID Hol 33013 '2C7 H 0 RCLE 0 ILSE RT SVRI IS) Slee Thkns Exception MOE Line Mo. Line No. Line No. FIS. Matrl. (In.) (in.) Basis Method Po T esp In? Line Description/Renarks r IO.AC.bol RHR 100 lb.RH 2013 $ 17 A312 10.00 0.365 SUN/VOL 350 350 Y V 720 TO REDUCER 10X6 BEfORE VALVE 717, 104 AC.601 RHJI.300 lb.RN 2001 $ .22 Q12 10.00 0.365 SUR/VOL C10 350 T VAL 701 TO 1ST 'lfE BEfORE VAL 70CA 8 8 lbs.AC 601 RHR 300 lb.RM.2001 8 20 A312 10.00 0.365 10" TEE axj H Q IDC.AC-601 RKR 300 10-RN-200C $ -20 A312 10.00 0.365 SUR/VOL SUR/VOL C1 0 350 350 350 T
.T TEE OM BT PEM ICO TO REFUEL MATER S TK IOOrAC.60'I To RNR PISIP A.
OQH 100 AC.601 RNR 300 lb.RH ~ 200C 8.20 A312 'Io.oo 0.365 SUR/VOL 350 350 Y TEE OM IOC AC 60'I To RHR PUMP 8, IOE.AC 601 RHR'300 lb.RH ~ 2003 8 ~ 20 A312 lb.00 0.365 SUR/VOL 3SO 350 T TEE ON 100 AC 601 10 VALVE 850$ ~ 10(f. AC 601 RMR'300 IO.RH.2003 S.20 Q12 lb.00 0.365 IIJC.)221(f) 350 350 Y VALVE 850$ TO 1ST REDUCINO ELBCMr 1DS AC bol 300 10 SI-2010 $ .20 lb.00 IDGG AC 601 RHR RHR.300 10 SI-2010 8.20 A312 Q12 10.00 0.365 0.365 IIJC 1221(f) SUN/VUL 350 350 350 350 Y Y VALVE 550A PAST TEE TO 10C AC 601 ~ VALVE BSOA 10 1ST REDUCING ELB(XI ) xn 10N AC 601 B.AC-601 RNR 3SO,RNR Coo RNR.CDO I O.RH-2007 8 RH 2010 8.2C 8 26 Q12 A312 lb.O0 8.00 0.365 0.322 SUR/VOL SUR/VOL Clo 350 350 350 N T CONT. OF BS AC 601 RED ELB(XJ TO 10.AC 601 TEE.RED TO TEE PAST MVC Tff~ 624
~o td 5A-AC-601 bs AC 601 RHR.CDO RHR 350 8 RN.2010 8 26 $ .23 Q12 Q12 8.00 8.00 0.322 0.322 SUR/VOL 350 SUR/VOL C I0 350 350 ~
T N IOXS REDUCER TO RESIDUAL NEAT EXCH A DISCHO RHR PMP A To 1ST REOUCINO ELB(XI~ a-BC AC 601 RNR 350 5 RN.2005 8.23 Q'l2 5.00 0.322 BUR/VOL C 'I 0 350 10" TEE OM IOH.AC.601 To RH EX 8 ~ L() n0 50 AC 601 RHR-350 5 RH.2005 $ .23 Q12 5.00 0.322 SUR/VOL 410 350 N- DISCHO RHR PHP 8 To 1ST TEE AFTER V 7108 bf H l5 bf AC 601 AC 601 RHR RNR 400 300 8 RH.2017 S.SI-2012 8-2C
$ .20 Q12 Q12 5.00 8.00 0.322 0.500 IIJC 1221(f)
SUR/VOL C I0 350 350 350 Y Y REDUCER BEFORE VALVE 71C TO RH HT EX VALVE 851A To REO ELBOU BT VAL'VE bSOA, A. HO+ 5FF AC 601 RHR 300 d Sl-2009 8 20 Q12 8.00 0.500 INC.1221(f ) 350 350 T VALVE 8518 TO RED ELB(XI BY VALVE 8508 bk'-$ 1-151 SI-151 8 19 A312 8.00 0.148 SUR/VOL T REDUCER OH 6C-AC-601 TO IOXd 'X6 REDUCER BX AC 6.AC-601
60) RHR Coo b RN-2018 8.26 Q12 5.00 0.322 BUR/VOL C I0 350 RES MEAT EX 8 TO 5XdXb REDUCER TEE, OR RHR 100 6 RH 2015 $ 17 Q12 6.00 0.280 350 350 VALVE 552A TO lb.AC 601 IN 6A.AC.60) RHR.)00 6.RN 2016 8 15 QI2 6.00 0.280 SUR/VOL SUR/VOL 350 350 Y
Y VALVE 852$ To lb.AC.60'I IN CONT ~ CONT ~ go H 6$ -AC-60) RHR-COO 6-RM-2012 8 2C 'A312 6.00 0.250 SUR/VOL 350 350 Y 10-AC-601 To IOA AC.601. 6C.AC.601 RKR COO,RHR CSO (.RH-2014 $ .27 QDC 6.OO O.25O SUR/VOL I0 350 BA-AC.60'I To 8X6 C Y REDUCER AFTER VAL 557C. 6O.AC.601 RHR CSO 6 RH 20)1 $ -26 Q12 6.00 0.280, SUR/VOI. C10 350 TEE AFTER V 857A To 8" Y TEE SY RES 8 EX 8 6E.AC 151 RHR 300 6.SI.2011 $ .20 Q12 6.00 0.13C IIJC.)221(F) 350 350 N 10" TEE OM loEE.AC-601 TO VALVE 1813S. bf AC ISI RHR-300 6.SI.201C 8.20 Q12 6.00 0.13C INC 1221(F) 350 350 N 10" 1EE BETIJEEN V 550A 8 PEH 141. 4 C SI 151 4.00 0.000 410 350 THIS LIME AC(XXJMTED fOR OM 33013 1262. 2.CN-IS I A312 2.00 0.109 410 350 THIS LINE ACCOUNTED FOR ON 33013 1264. O
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R. E. GINNA NUClEAR POWER PLAN'I Inservice Exeninet lan Boundary Line List Third Inspection Interval Closet 2 &jan Systen: RESIDUAL NEAT REHOVAL PC ID Mot 33013-1247 RC(E 0 ILBERT suR I IS I Site 'Ihkns Except Ion MD 8 Line No. Line No. Line No. FIB. Hetrl. (In.) (ln.) Basis Method Po 'leap In) Line Descript Ion/Reesrks 2A.AC.601 RMR 300,RHR CDD 8.25 A312 2.00 0.154 IWC-'1221(A) 350 350 3 IO.AC.601 TO 10$ .AC.601. 2$ -AC-60I RMR 350 8-2C A312 2.00 0.15C I WC-1221(A) 410 350 'SC AC 601 N TO VALVE IS12A.
. 2C.AC 601 RMR.(00 8.2C A312 2.00 O. I 5C Iuc ~ 1221(h) C IO 350 N SE-AC-601 TO VALVE 1812$ . <MQ 2F.AC.601 RHEA 2A AC.601 CVC.100 8.17 A3'I2 2.00 2.00 0.154 I WC.1221(A) 350 350 Y THIS LIME ACCOUNTED FOR ON 33013.1264. OCH L" RMEA.2$ .AC 601 A312 A312 2.00 O. ISC 0.154 luC-1221(h)
I WC.1221(A) 410 410 350 350 RESIDUAL HEAT EXCH' RESIDUAL HEA'I EXCH. A TO TO VALVE 807C. VALVE 80)De urn 5
~ RKEA 2C AC'60) A312 2.00 0.15C luc-1221(h) 410 350 RESIDUAL HEAT EXCH. A TO VALVE 807E, RK($ 2A AC d01 A)12 2.00 0.154 Iuc.'1221(A). 410 350 RESIDUAL HEAT EXCH. 8 TO VALVE 8078 RHIB 2$ AC 601 A312 2.00 0.154 I WC 1221(A)
.'J 410 350 RESIDUAL HEA'I EXCH 8 TO VALVE 807F ~ h's
~ I RHEB 2C.AC 601 A312 2.00 O. ISC luC-1221(A) '10 350 RESIDUAL HEAT EXCH. 8 TO VALVE 8070e .TS.AC.60I RKR CDD 8.25 A312 0.75 0. 113 llC-1221(h) 350 350 Y VALVE 2780 TO IO.AC-601. .TSA AC 601 8.25 A312 0.75 0.133 IlC-1221(h) 350 350 .T 2h AC 601 TO VALVE 719A .7$ $ .hc.dDI 8 25 A312 0.75 0.133 Iuc-1221(A) 350 350 2A-AC 601 TO VALVE 719$ .
T
.75$ A.AC.601 RMR 100 10 RH 2013 8.17 A312 0.75 0.133 luc-1221(A) .7$ $ $ -AC-601 RMR 100 6-RH ~ 2015 $ -17 A31 2 0.7$ 0.133 IIC.1221(A) 350 350 350 350 . T T
10 AC-60'I TO CAP 6-AC.601 PAST VALVE 284S TO CAPe I() 0'0 Q5
.75$ C-AC-601 RHR 100 6-RN ~ 2015 $ -1'7 A312 0.75 0.133 Iuc-1221(A) 350 350 6.AC 601 PAST VALVE 2847 T TO CAP, - 7$ $ D AC 601 RMR 100 6.RH.2016 $ -18 A312 0.7$ 0.133 I WC-1221(A) 350 350 T 6A AC 601 PAST VALVE 28CO TO CAP, ~ HOQ ..75$ E-AC.d01 RMR 100 6-RN-2016 8.18 A312 0.75 0.133 Iuc.1221(A) 350 350 T bh-hc-601 PAST VALVE 2853 TO CAP . .75$ F-AC-601 RHR C00 8.2C A312 0.75 0.133 IIC.1221(A) 350 350 T 2-AC-601 PAST VALVE 2785 TO CAP.
A>
~ .7$ $ Q.AC-601 RMR C00 8.2C A312 0.75 0.'133 Iuc-1221(A) 350 350 T IOH.AC.601 PAST VAI.VE 807A TO CAPe ~
X 0Q
.75$ N AC 601 RMR 350 8-2C A312 0.7$ 0.133 IIC-'1221(A) 410" 350 T 28 AC.601 PAST VALVE 2784 TO CAPo PQH'. .7581-AC-601 .7$ C.AC.601 .7$ 0 AC.60'I .TSE.AC.601 RMR 350 RHR C00 RHR CDD RHR CDD S.RH-20M 8.23 8-25 8-25 8-25 A312 A312 A312 A312 0.7S 0.75 0.75 0.75 0.133 0.133 0.133 0.133 IIC.1221(A)
Iuc-122)(h) luc.122)(h) luc-'1221(A) 350 350 350 350 350 350 350 350 T T T T BC-AC-601 PAST VALVE 2782 TO CAPo VALVE 2779 TO 10-AC 601. VALVE 95S TO 10.AC-601. VALVE 718$ TO 10.AC 601 II
.7$ F-Ac-601 RHR CDD 8 25 A312 0.75 0.133 Iuc.'1221(A) 350 350 VALVE 71SA TO 10 AC 601 Z
TSG AC 601 RMR.C50 $ -26 A312 0.75 0.133 IWC-122)(h) 410 350 M FLAMCE SY VALVE 278S TO 6D.AC 601 '
.7SH AC.60'I RHR 450 $ -26 A312 0.75 0.133 Iuc 1221(A) CI 0 350 VALVE 1829C TO 60-AC 601 .7$ I.AC.601 ~
RHR CSD 8.26 A312'.75 0.133 Iuc-1221(h) C10 350 Y VALVE 1829D TO 60 AC 601
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Q PIO=- R. E. GIHHA NUCLEAR PDVER PLANT (/) Q Inservice Exarainatlon Boundary Line List g Mg Third Inspection Interval H Closet 2 O Systoal RESIDUAL MEAT REHOVAL PSID Mot 33013.12C7 H RG(E GILRERT SVR I ISI .. Site Thkns Exception MDE 0 Lire No. Line No. Line Ho. Fi8. Hatrl. (in.) (in.) Basis Hethod Po leep Inf Line Description/Rcraarks
.7S J.AC-601 RHR 450 $ -27 A312 0.75 0.113 Iuc-1221(A) C10 350 N flANGE BT VALVE 2788 TO 6C AC 601 ~ ~ .75)A-AC.601 RHR.300 8 20 A312 0.75 0.133 Iuc-)221(A) 410 350 N DRAIN VAL 5508 10 FLANGE AFTER VAL 711E. .TSX.AC.60I 450 $ -27 0.75 0.113 RHR A312 IVC 1221(A) 410 3$ 0 N VALVE 1829A TO 6C AC 601 ~ rs) H Q .7$ XA-AC-601 RHR.300 $ -20 '312 0.75 0.133 IVC-1221(A) 410 350 N 10F.AC-601 BEFORE RHR PNP A TO FLANGE. 0 XH .75L-AC-601 RHR 450 8.27 A312. 0.75 0.113 IVC-1221(A) 410 350 VALVE 1829$ TO 6C AC 601. xr ra ITS(A-AC-601 RHR 300 8 20 A312 0.75 0.133 luC.1221(A) 410 350 N
M DRAIN fRDH VALVE BSDA TO +75K AC 601 ~ g
.7SLR ~ AC-601 RHR.300 8 ~ 26 A312 0.75 0.133 luc.1221(A) 410 350 N RHR PUMP A TO VALVE 706Am .75N.AC.601 RHR.300 8.25 A312 0.75 0.133 IVC.1221(A) 350 350 T 'RAIN fN RHR PtaIP A TO VALVE 705A, . .7$ k AC.601 RHR 350 '-23 A312 0.75 0.113 IVG.1221(A) 410 350 k 88-AC 601 TO VALVE 7'IIC. .750.AC.601 M PI.O RHR-350 5.23 A312 0.75 0.113 IVC-1221(A) 410 350 N ED AC 601 TO VALVE 7118 .7$ P.AC-601 RHR.3$ 0 8.25 0.75 0.113 Iuc-1221(A) I() H .754.AC-60I RHR-350 8.25 A312 0.75 0.113 Iuc.1221(A) 410 350 N RHR PUMP 8 DRAIN TO VALVE 7058 CI g0) gO .75R AC 601 .7SS.AC-601 RHR-2500 RHR.2500 8-22 8-22 A312 A312 A312 0.75 0.7S 0.113 0.113 IVC-122)(A)
IVC-1221(A) 350 CIO 410 3$ 0 350 350 N RHR PIRIP 8 TO VALVE 7068+ IOA AC 601 TO fLAMGE PAST VALVE 2763. 10A-AC 601 TO FLANGE PAST VALVE 2786. a-4R
~g .TST.AC.601 RKR 400 8-2C A312 0.75 0.113 IVC-1221(A) 410 350 ~ 10$ -AC-601 'IO VALVE 7'IIA.
I() OO 7SU AC 601 $ -24 LO+g IRA.AC.60'I RHR CDO RHR.C00 6.RH.2010 8.26 A312 A312 0.75 0.75 0.113 0.133 IVC-1221(A) IVC-1221(A) 410 410 350 350 T IDH AC 601 TO FLANGE PAST VALVE 2781+ B-AC.601 TO VALVE 2775.. Ixl > CDHT SWP 8 RHR.300 0.00 0.000 ATH. <200 CONCRETE SIRIP EXENPT fRDN EXAMINATION+ 'RHR PIRIP A RHR 300,RHR 350 8-25 0.00 0.000 410 350 RHR ptarp 8 RHR.300,RHR.350 8-26 0.00 0.000 CI 0 350 OR o m
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A R. E. GINNA NUCLEAR POMER PLANT Inservice Exaoination Boundary Line List Third Inspection Interval h Class: 2 Systes: SAfETY INJECTION SYSTEH PAID Not 33013-iR62 0 RGIE GILBERT ISI Size Thkns Exeep! Ion NDE Line No. Line No. Line No. fly. Hatrl. (In.) (in.) Basta Hethod Po leep Inl Line Dcscrlptlon/RecLarks IDA Sl 90R SIS.200 ~ A376 10.00 1.000 I MC. 1221 (E ) 740 60 ACCUHULATOR 1 TO VALVE 842A. 10$ S1 "902 S I S-200 Q76 10.00 1.000 IIC-1221(E) 740 80 10A Sl 902 TO CAP ON TEE IDC.SI 90R $ 1$ ~ 200 A376 10.00 1.000 IIC-1221(E) 7CO 60 IOA Sl 90R TO CAP ON TEE. rs5.H A 'l(6.$ 1.902 $ 1-100 A376 10.00 1.000 IIC-1221(E) 740 50 Y ACCUHULATOR 2 TO VALVE 8C28 OMAH 10E.SI.902 Sl-100 A376 lb.00 1.000 IIC.1221(E) 7CO 50 100 Sl 902 To TEE CAP IDF.SI 902 Sl-1(R) are 10. 00 1. 000 IIC.1221(E) 740 50 10D Sl-902 To TEE CAP. 54.$ 1-30) B SI-C00,8.$ 1.301 b. 8 I.2001 6 15 Q12 8.00 0.322 5 210 . Y THIS LINE AC(XXNITED fOR ON 330'13 1266, BS.$ 1.301A SI-COo,b-SI-301 B. S1.2001 8-15'12 5.00 0.322 5 210 Y 1NIS LINE ACCOUNIED fOR ON 33013 BC ~ $ 1.301 ~ S I-C 00, 8-S 1-301 B.SI 2001 8-15 Q12 8.00 0.322 IIC-1221(E) 200 200 bE/EO.SI-30). 1266.'A/58-Sl-301 An 60.$ 1.301 BE.$ 1.301 SI.COO,SI-301 5.$ 1-2003
b. S 1-2002 8.16 8.16 Q IR 5.00 0.322 IMC-1221(E) 200 200 Y
Y 8C Sl 301 'io TO TEE PAST VALVE 8268 ~ k I() H 4~ QIR 6F.SI.301 Sl COO,B.SI-301 SI-CDO,RHR 450 8-$ 1-2003 8-16A A312 8.00 8.00 0.322 0.322 IIC-1221(E) IMC 1221(E) 200 200 200 200 T 5C.SI-301 TEE To 1ST TEE PASl'AI.VE d260 50/BE-$ 1-301 To 1ST 5XC RDCR o4 pal O Y I (/) 60.$ 1.151 RHR-450 8-19 Q12 8.00 0.322 IIC-1221(E) 200 200 Y 6F.SI.30'I TO BH-SI-151. a BH-$ 1 ~ 151 C $ 1 ~ 301 RNR.CSO RKR 450 8.168 8.168 A312 Q12 8.00 c.oo 0.1C8 0.237 IIC.1221(E) IMC-1221(E) 200 200 200 200 Y bf Sl-301 To 10.SI-151 bf.SI.301 To Sl PIIP SUCTION 8I.
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4A $ 1.301 RHR-450 8-168 QlR C.oo 0.237 IIC.1221(A) 200 200 Y BH Sl '151 To Sl PIRIP SUCTION 83 CB SI 301 RHR.CSO 8-16S A312 C.OO 0.237 IMC-1221(E) Roo 200 Y 8G Sl-151 To Sl PUHP SUCTION 82 4C.SI 151 RHR F 450 8-168 A312 C.oo 0.237 IIC-1221(E) 200 200 T 48-Si-3Oi PAST V 1816A 8 8 TO 6C-AC-60). 40 ~ $ 1.1501 $ 1-300,$ I.210 8 37r A312 C.OG 0.337 SUR/VOL 1550 200 N 3A.S!-1501 TO VALVES 8788 8 876A. 4E ~ SI 1501 $ 1-300,$ 1-110" S.C2 Q12 C.oo 0.337 1550 200 3E.SI 1501 TO TEE BEFORE V 878C 8 dl80 3A.SI.150'I SI-300 8-37 Q12 3.00 0.300 SUR/VOL SUR/VOL '1550 200 Sl PIHIP A To RDCR AFTER VALVE 558A, 06 3B.SI.'I 501 $ 1-300 8-Co Q12 3.00 0.300 SUR/VOL '1550 200 'Sl PWP C PAS'I FLANGE To 3" TEE. 3C.SI ~ 1501 $ 1-300 8-Cl A312 3.00 0.300 SUR/VOL '1550 200 38.$ 1-150i PAST V 871A 8 870A CD-SI.150'I 3D.SI.1501 Sl-300 8-Cl QIR 3.00 0.300 SUR/VOL 1550 200 38.$ 1.1501 PAST V 8718 8 8708 3E.SI 1501 35.$ 1.150i $ 1-300- 8-CR Q12 3.00 0.300 SUR/VOL 1550 200 Sl FWP 8 PAST V 5568 To RDCR PEN Tole 2A.SI ~ 'ISDI SI-RIO 8-39 cA31R 2.00 0.215 SUR 1550 200 N CD Sl 1501 PAST VAL 878A TO VAL 878F ~ 2$ -$ 1.150'I $ 1.2iO 8-39 A376 2.00 0.216 SUR 1550 200 N CD SI 1501 PASt VAL 8758 To VAL dido+ 2C A ISOI Sl-110 B.CS A376 2.00 0.343 SUR 1550 200 T C" TEE ON CE-Sl-1SOI TO VALVE d78J. 20.$ 1 1501 Sl 110 S.CC Q12 2.00 0.218 SUR 1550 200 Y C" TEE ON CE-Sl-1501 TO VALVE 8768m O
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xa R. E. CIJJMA JAJCLEAR POJJER PLANT Inservice Examination Bmxxiary Line List Ihird Inspection Interval Classt 2 Systeml SAFETT INJECTION STSTEH PLID No: 330I3-1262 RC(E OILBERT ISI Site
. Ihkns Except i on NDE I.lne No. Line No. l.lna No. FIB. Jlatrl. (in.) (in.) Basis Hethod Po TeaTJ In) Line Description/Remarks 2r.-s1-902 SIS 200 2.00 0.3(3 IIC.1221(E) 7{0 80'.
A312 10A-Sl-902 TO VALVE 8({A. 2N-Si-902 SI.101 A312 2.00 0.15( IlC-1221(E) 7(0 10D.SI-902 80 TO VALVE 84(B.
-SI.902 21 2J Sl 902 A312 A312 2.00 2.00 0.15(
0.15( luC-1221(E) IlC-1221(E) 7(0 7(0 50 80 AccteaJLATDR L'I 939 pAsT I pAsl v N3A v 533$ To To LT 939m Acctae)LATDR 1.
<QQ tc.si ~ 902 A312 2.00 0.15( luc-1221(E) 7(0 80 ACCJARJLATOR 1 PAST V S32A TO LT 938.
2L.SI ~ 902 A312 2.00 0.1st Iuc-1221(E) 7(0 60 LT 938 pAsT v 832$ To Acctae)LATDR I ~ 2H.sl-902 A312 2.00 O. Is{ IiJC. 1221(E) 7(0 50 2'l 902 A312 2.00 0.15( luC-1221(E) 7(0 60 ACCUHULA'IOR 2 PAST V 537A TO LT 936 LT 93( PAST V NTB TO ACCUJRJLATOR 2. .2P-SI-902 A312 2.00 0.15( IIC.1221{E) 7{0 60 Acctae)LATOR 2 PAS'I V S38A TO LT 395m 20-SI-902 A312 2.00 0.15( {E) 7(0 IUC.1221 80 LT 395 pAsT v 8385 To AccwULATDR 2.
'IA.SIPI 1.00 0.133 Ivc-1221(A)
A312 200 200 SIAPSI I TO VALVE 2803 Ie-SIPI A312 1.00 0.133 llC-1221(A) 200 200 SIAPSI.1 10 VALVE 2802. 4C.SIP I A3 lt 1.00 0.133 IlC-1221(B) 200 200 SIAPSI-1 10 VALVE 2801. ID SIPI IE.SIP2 A312 A312
'1.00 1.00 0.133 0.133 llC-1221(8)
IIC-1221(A) 200 200 SIAPSI-1 'TO VALVE 280( ~ t()OOg +~ IF.SIP2 A312 '1.00 0.'l33 luC-1221(A) 200 200 200 200 SIAPSI-2 TO VALVE 2516. SIAPSI-2 TO VALVE 2811 ~ HO+Hibf a. 10 SIP2 IN-SIP2 A312 A312 1.00 1.00 0.133 0.133 llC-1221(B) llC-1221(B) 200 200 200 200 SIAPSI.2 TO VALVE 2812. SIAPSI.2 TO VALVE 2813.
. Q4 11-SIP3 A312 1.00 0.133 luC-1221{A) 200 200 SIAPS1.3 TO VALVE 2808m IJ.SIP3 A312 1.00 0.133 llC-1221(A) 200 200 ~
SIAPSI:3 TO VALVE 2806m IK-SIP3 A312 1.00 0.133 IIC-1221(B) 200 200 SIAPSI.3 TO VALVE 2809. IH Sl-1501 A3'l2 1.00 0.133 Iuc-122) {8) 200 200 RDCR TOMARDS SIAPSI 1 TO VALVE 897 I I'$1-150'I SI.110 A3'l2 1.00 0.133 IIC-1221{5) 1550 200 .'j5J-Sl-1501 TO VALVE. 887. ID-S i. ISO I SI-I'10 A312 1.00 0.133 Iuc-1221(5) 1550 200 (E-SI 150'I PAST V NSB TO ACCWLATOR te IR.SI 1501 SI 110 A312 1.00 0.133 IIC-1221{5) 1550 200 1JJ-Sl-1501 PAST V NSA TO ACCLBRJLATOR 1 ~ le.sl 902 A) lt 1.00 0.133 IVC 1221(E) 7{0 50 ACCIJHULATOR I 10 VALVE NCAa IS.S1.902 A312 1.00 0.133 IIC. 1221{E) 7(0 80 AcctaaJLATOR I TO VALVE NDA
'IT-S!.902 1.00 0.133 IlC.1221(E)
A312 7(0 80 ls Sl-902 TO VALVE 886A. IU.S l.902 Sl-100 A312 1.00 0.133 IVC.1221{E) 7(0 80 AcctaaJLATOR 2 TO VALVE S3(B ~
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R. E. GINNA NUCLEAR POMER PLANT Inservlce Examination Boundary Line List Third Inspection Interval Class: Systcn: SAFETY INJECTION SYSTEH PAID Not 33013.1262 H 0 RGCE GILBERI SMR I ISI Site Ihkns Exception NDE Line No. Line No. Line No. f IB. Hatrl. (in.) (in.) Basis Hcthod Po Tccp Int Line Description/Reeerks IV.SI.902 SI-100 A312 1.00 0.133 IMG. 1221(E) 740 50 ACCLNULATOR 2 TO VALVE 8308 lu-SI-902 Sl-100 A312 1.00 0.13$ IMG 1221(E) 7CO 50 1V Sl 902 TO VALVE 8865. IX. S I-903 1.00 0.000 Iuc 1221(A) 740 50 V BC6 OUT CONT PASt PEN 120 TO V 8623. adi HQ .75A Sl 1501 SI.300 A3'l2 0.75 0.154 IMC.1221(8) 1550 200 1H.S 1-1501 TO 3A-51-1501 0 @H .TSAA-S 1-301
7$ 0.$ 1.1501 Sl-COD S 1-300 8 16 A312 0.75 0.75 0.000 0.154 IIC.1221(A)
IMG. 1221(8) 200 200 1550 200 BE.SI-301 70 fLANGE PAST VALVE 1522. 1H Sl 1501 TO VALVE 55C. gag
.7$ dd Sl 34'I SI 400 5 ~ 16 0.75 0.000 luG.1221(A) 200 200 BD Sl-301 TO FLANGE PAST VALVE 152ls .7$ RG.SI.ISI RNR 450 8 19 ~ 0.75 0.000 IMG. 122 1(A) 200 200 BN Sl.15'I TO FLANGE PAST VALVE 2517e,. .7$ BD-Sl-IS I .7$ BE SI 1SDI RHR 450 Sl-300 5-19 5.37 0.75 0.75 0.000 0.000 IlC 1221(A)
IMG 1221(B) 200 200 1550 200 BG Sl 151 BYPASS. CD.SI-1501 PASt VALVE 855Am RXnW +
.7$ df.sl-1501 Sl-300 5-37 0.75 0.000 IMG. 1221(B) 1550 200 CD SI-1501 PAST VALVE 525A I() H .TSBG-S I- ISOT Sl 300 8.37 0.75 0.000 IMG 1221(B) 1550 200 4D Sl 1501 PAST VALVE 8258 ~ BIBLE .TSBN-S 1-1501 51.210 8 39 0.7S 0.000 luc-1221 (8) 1550 200 28 Sl-1501 TO FLANGE PAST VALVE 25C2.
75 5 I. S 1.1501 SI.210 8-39 ~ 0.75 0.000 IIC-1221(B) 1550 200 2A-SI.1501 TO fLANGE PAST VALVE 28C1
~now .TSC Sl 1501 S 1.300 A312 0.7S 0.154 IMG. 1221(B) 1550 200 38-51-1501 10 1H.SI.1501. <
HRb) HOW ~
.FSD*SI 1501 51-300 A312 0.75 O. ISC llC 1221(B) 1550 200 3E SI 1501 TO 1N 51-1501.
TSE SI-1541 Sl-300 A312 0.75 0.154 IMG.1221(8) 1550 200 3E-51-1501 10 VALVE 2510.
.7$ f. SI-1501 Sl-300 A312 0.75 0.154 IMG.1221(B) 1550 200 3E-Sl-1501 'TO VALVE 5558. Ul .75G SI.1501 51-300 A312 0.7S 0.154 IMG.1221(8) 1550 200 ~ CD.SI.1501 PAST I( 872A PEN 110 TO V 879. .7$ N-SI.1501 SI-I'IO . A312 0.7S 0.15C IMG.1221(B) 1550 200 CE.SI-1501 TO TEE PAST VALVE SI-I'10 OR .751.$ 1-1501 .TSJ.SI-1501 51-110 A312 A312 0.75 0.7$
0.154 0.154 IMG-1221(B) IMG-1221(B)
'1550 1SSO 200 200 .75G $ 1.1501 70 75! Sl 1501 .758.51-1501; TO VALVE 2554 ~
gQH IR
~ .TSH Sl 150'I SI.110 A312 0.75 0.154 IMG.1221(B) 1550 200 14 Sl 1501 TO VALVE 3536. ~ .7SN-Sl-150i SI.110 A312 0.75 0.154 IMG-1221(B) 1550 200 CE Sl.'1501 TO VALVE 529A. .7$ P.SI-1501 SI 110 A312 0.75 0.154 luG.1221(8) 1550 200 CE.SI.1501 TO VALVE 8298. .7$ 4 SI 1501 SI. 1 10 A376 O.TS 0.215 IMG-1221(B) 1550 200 4E-Sl-1501 'IO FLANGE PAST VALVE 2533. .7$ R Sl.lS01 S1-110 O.TS 0.000 IMG 1221(8) 1550 200 2D.SI-1501 PASt VALVE 2832 TO FLANGE'R .7$ S.SI.1501 S1-110 A312 0.75 0.154 IMG-1221(8) 1550 200 Sl-150'I TO fLANGE PAST VALVE 2846. .7$ 1 Sl 902 0. 7$ 0.000 IIC 1221(E) 7CO 80 ACCUMULATOR 1 TO VALVE BCSA.
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Aj W R. E, CINNA NUCLEAR PDNER PLANT H Inservice Exaalnatlon Boundary Line List Third Inspection Interval Classl 2 Systen: SAFETT INJECTION STSIEM 33013- 1262 PSID Not H . 0 ROSE 0 ILSERI SNR I ISI = Size Thkns Except ion MDE Line No. Line Mo. Line Mo. f lg: Metr t. (In.) (ln.) Basis Method Po Teep Inl Line DescrlptlonfRemarks .750 $ 1 002 Sl-100 0.75 0.000 INC-122) IE) 7$ 0 80 ACCUMULATOR 2 TD VALVE 8$ 3S .75V $ 1-2501 A376 0.75 0.218 IlC-1221IE) 7CO 80 - 100 Sl 902 TO .75N.SI 1501. A376 0.75 0.21S llC.1221IE) 7tO 80 100.$ 1.902 TO VALVE SCOS ~ es3H Q
.75M.$ 1-2501 0gH p
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R. f. GINMA NUCLEAR POVER PLANT lnservice Exaoination Boundary Line List Third Inspection Interval Class: 2 Systen: SERVICE MATER Filo Nol 33013.'1250 RGIE CllBERT SVR I ISI Site Thkns Exception NDE line No. line No. Line No. fib. Hatrl. (In.) (In.) Basis Hethod Po Teep Inl Line DescrIPtlon/Remarks 6 QI 125 Su-1400 A53 S.oo 0.322 IlC-1222(C) 60 60 Y .VALVE 4644 lo 8" TEE SY PEN 323 CUT CONT SA- SM. LZS Su-1400 A53 8.00 0.322 IIC-122t(C) 60 bo T PEM 323 10 COOLING COILS I fAM HO10RS. SS-SV-I25 QI 700 A53 6.00 0.322 IlC-1222(C) bo So T CVCC 6 FAN HOIOR AAGRO2D TO PEN 312. <HQ O.g H 6C QI.125 QI-1500 A53 d.oo 0.322 IVC-1222(C) 60 80 T RED ELSOM AFTER PEM 312 TO VALVE 4642. SD SV.125 Su-1400 A53 &.00 0.322 IIC-1222(C) 60 bo T VALVE 4643 To 8" TEE BEFORE PEN 315. XMAS sf.su.I25 QI 'loo A53 6.00 0.322 IVC-1222(C) 60 bo Y RED ELBOI PAST PEN 315 10 AAGRO2C 6I SV.125 QI-200 A53 5.00 0.322 IlC.1222(C) 60 80 Y RED ELBOV PAST PEN 320 10 AAGRO2C i SG SV 12$ QI ~ 1500 A53 8.00 0.322 llC-1222(C) 60 bo Y 'ALVE 4641 TO RED ELBOM PAST PEN 3207 VALVE 4630 To 1ST 8" TEE BY PEN 311 ' ) A HA5 Sx Su 125 SV-1400 A53 8.00 0.322 llC-1222(C) bo dO T Sl QI 125 QI.'ISO A53 8.00 0.322 Iuc.122z(c) 60 50 Y RED ELBOM BY PEN 311 To AAGR026. SI.QI. I25 Su-600 A53 8.00 0.322 llC-1222(C) 60 80 Y COOLING COILS 5 fAll HOTORS TO PEM 316 o'g g~o SX-su-IZS QI-1500 A53 d.oo 0.322 IIC-1222(C) 60 50 T RED ElBOM AfTER PEN 316 TO VALVE 4628. SL-QI 125 SM.1400 A53 ~ 8.00 0.322 llC-1222(C) 60 80 T VALVE 4629 TO 8< TEE ST PEN 308. ag X IT5 H@ SN.sv-125 Sus200 A53 . 8.00 0.322 Iuc-1222(c) 60 80 T RED ELBOM BY PEN 308 TO AAGRO2A. L() 0 0 8Z SN SV.125 QI.500 A53 8.00 0.322 llC-1222(C) 60 80 T AAGR02A To RED ELBCM BEFORE PEN 319. LO+g SO. Su-125 QI 1500 d.oo 0.322 IVC-1222(C) RED ELBOI BY PfN 319 TO VAI.VE 4627 6.QI ~ 125 SM-1400 A53 A53 6.00 0.280 IlC-1222(C) 60 60 80 80 T Y 8" TEE BY PEll 323 To 1ST RED ELBOM. H 0 x(5 6A QI 125 su-1500
'u.700, A53 6.00 0.280 llC-1222(C) 60 T RED ELBOM BEFORE 5 AFTER PEN 312, 6S SM.I25 SM-1400 A53 6.00 0.280 llC-1222(C) 60 80 ' 8" TEE ON 80-SM-125 To PEN 315 ~
6C. S'V. 125 QI-ZOO,SM-1500 ~ A53 (.Oo O.28O IVC-1222(C) 60 bO Y RED ELBCM IM COlT 8 CUT CONT AT PEM 320m bo SM.125 QI-1400 QI-150 A53 6.00 0.260 luC-1222(C) 60 80 Y 8" TEE ST PEN 311 To RED ELBOM PEN 311 ~ 6E SV.125 QI. 600, SM.1500 A53 6.OO O.ZSO IVC.1222(C) 60 80 Y RED ELBOM BEFORE 6 AfIER PEN 316. bf.QI 125 QI-1400 SM.200 A53 6.00 0.260 IIC-1222(C) 60 60 Y 8" TEE BT PEN 30S T0.1SI RED ELSOI 308.
60. Su-125 QI-500 QI-1500 A53 6.00 0.260 llC l222(C) 60 50 T RED ELSOM PEN 3'l9 IM CONT To 319 ON COM 3G. SV-125 3.00 0.000 luc-1222(A) 60 80 STPASS CONNECT AAGRO2A 6 AAGR025 To RDCR Z.SA.SM.125 su-1410 A53 2.50 0.203 luc-1222(A) 60 80 T VALVE 4636 TO 2.5X2.5X2 'IEE PAST PEN 201 2.5s.su.125 SM.SOO A53 2.50 0.205 IVC.1222(A) 60 bo T IST ELBOM PAST PEN 20'I TO AAGROIS Z.Sc.su-125 QI.450 A53 2.50 0.203 IIC. 1222(A) 60 80 Y REACTOR COOLER AAGROIB TO PEN 209m 2.5o-su-125 QI 1550 A53 2.50 0.203 luc lt22(A) 60 50 Y 2.5X2.5X2 TEE SY PEM 209 TO VALVE 4635 O
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R. E. GIHMA HVCLEAR POVER PLAHT Inservice Exaainat ion Sotxtdary Line List lhird Inspection Interval Classt 2 Systen: SERVICE MATER PAID Not 33013-1250 RGCE GILSERT QIR I ISI Site thkns Except ion Line Ho. Line No. Line No. floe Hatrl. (In.) (in.) Basis Hcthod 1ecp Int Line Po Descript Ion/Rectarks 2.5E-SV 125 QI ICID A53 2.50 0.203 IIC-1222(A) 60 b0 Z VALVE C758 TO 2.5X2.5X2 TEE SY.PEH 209. 2.5F-QI.12$ SM 300 .A53 2.50 0.203 IVC-1222(A) 60 80 1 IST RED ELBGV SY PEN IN CONT 10 AAGROIAo 2.5G-SM-125 Su-800 A53 2.50 0.203 IIC-1222(A) Y'. 60 b0 REACTOR COOLER AAGROIA TO PEN 201 2.SH. QI-'I25 Su. 1550 '. 2.50 0.203 IIC 1222(A)
'0 A53 80 T ~ 2.5X2.5X2 TEE BY PEH 201 10 VALVE 4757.
51-SM.125 2.50 0.000 IIC-1222(A) 60 80 BYPASS CV AAGR02A. 2.5 J-QI.125 2.50 0.000 IIC-1222(A) 60 80 BYPASS DH MGR025 2.5r-su.12$ 2.50 0.000 IVC ~ 1222(A) 60 50 BYPASS OH MGR02Ce 2.$ L-QI-125 2.50 0.000 I VC-1222 (A) 60 80 ~ BYPASS OH AAGR02D 2A-SM.I25 QI.ICID,QI 800 2.00 A53 0.15C IVC-1222(A) 60 80 T '2.5X2.5X2 TEE AT PEN 201 1ST RED ELSOV, 2S-QI.125 SM C50,SV 1550 2.00 A53 0.15C I VC-1222(A) 60 80 T RED ELBDV SY PEN 209 10 1ST 2" 1EE ~ 2C.SV.125 QI. I C 10, QI-300 A53 2.00 0.15C IIC-1222(A) 60 80 .2.5X2.5X2 Y TEE BY PEN 209 1ST RED ELSDM. 2D.SV.125 QI.SDD,SM.1550 A53 2.00 0.15C I IC- 1222 (A ) 60 80 Y 1ST RED ELSOV SY PEN 201 TO 2>> TEE, 2E-Ql-125 2.00 0.000 IIC-1222(A) - 60 80 . 2.5I-SM 125 PASt VALVE 479CF. 2F.SV-I25 2.00 0.000 IIC-1222(A) .- 60 80 2.5J-QI.125 PAst VALVE 479CX. 25-QI-125 2.00 0.000 IIJC- '1222(A) - 60 80 3X2 RDCR OH 3A-QI 125 TO AAGR02C 2H QI125 2.00 0.000 Iuc-1222(A) - 60 80 BYPASS FH AAGRDIS 10 AAGR02D.
.75A-QI.'125 0.75 0.000 IIC. 1222(A) 60 b0 AAGROEA 10 VALVE 479CD .7$ S-QI.125 0.75 0.000 IIC-'1222(A) 60 80 - AAGR02A 10 VALVE 479CC. .755-su-125 0.75 0.000 IMC-1222(A) 60 - . 80 AAGR02A 10 VALVE C79CE ~ .7$ D.SM-I2$ 0.75 0.000 IIC-1222(A') 60 80 AAGR02A 10 VALVE .75 5. QI.125 47948'0 0.75 0.000 luc-1222(A) 80 AAGR02B 10 VALVE 479CNo ' .75f -QI.125 0.75 0.000 IMC- 1222(A) 60 80 'AGR02B 10 VALVE 4794J ~ .7$ G-QI.125 0.75 0.000 Iuc-'1222(A) 60 80 AAGR028 10 VALVE 47940m ~ .75 H. QI.125 0.75 0.000 IMC.1222(A) - - AAGR025 60 80 10 VALVE 479CVo ~ .7$ 1 QI.125 0.75 0.000 IIC-1222(A) 60 80 =
AAGR02C 10 VALVE 479CH.
.7$ J. QI-125 0.75 0.000 IIC 1222(A) 60 80 AAGR02C 10 VALVE 479(No .7$ r-su-125 0.7$ 0.000 IIC-1222(A) 60 80 - AAGR02C 10 VALVE 4794Le .75I.-QI-125 0.75 0.000 IIC-1222(A) 60 -
80 AAGR02C 10 VALVE 479CM.
.7$ H-su.125 0.75 0.000 IIC-1222(A) 60 80 - MGR020 TO VALVE C79CR O
II
R. E. GINNA NUCLEAR PCMER PLANT Inservice Exaoinat ion Boundary Line List
'third Inspection Interval Cl asst 2 Systeos SERVICE MATER I'LID Nos 33013.1250 H 0
RGLE GILBERT SMR I IS I S I ze Thkns Except Ion NDE Line No. Line No. Line No. fly. Natrl. (In.) (in.) Basis Method po Teals In7 Line Description/Rcearki
.75N ~ SM-125 0.75 0.000 IMG. 1222(A) 60 BD AAGR02D TO VALVE 4794$ . ~ 75P. SM-125 0.75 0.000 IMG.1222(A) 60 BO AAGR02D TO VALVE 47944. .75O. SM-125 0.75 0.000 IMG 1222(A) 60 BD ~ AAGR020 10 VALVE 47941 M&Q QCH g M A 5 M Xn og' t() H. ~
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R. E. GINNA NUCLEAR POVER PLANT Inservice Exaelnat ion Scxadary Line List Third Inspection Interval Ciassl Systast 2 STANDST AUXILIART fEEDVATER n PS ID Not 33013.123S H 0 RCLE Line 0 ILBER'I QJR I ISI Site Thkns Except Ion NDE 4 No Line No. Line No. fig. Natri. (in.) (in.) Sasis Nethod Po Tarp In2 Line Description/Rasarks 3C.FV-900.1A AFM.SDD FM 1001 S.12 AIDS . 3.00 0.300 llC. 1222(A) 715 505 T Tltls LINE IS ACCOUNTED fOR ON 33013 1236 3C fM 900.1S Aflt.(00 FM.IDDS S-13 AIOS 3.00 0.300 IVC.1222(A) 715 505 T Tltls LINE IS ACCOUNTED FOR ON 30013 1236 .75D.fV.900 IA AfM SDD fM.1001 .75D.f M-900.1S AfV.(00 Fll.1005 0.75 0.75 0.000 0.000 IVC-1222(A) llC-1222(A) 715 505 T. 3C-FM.900.'IA 3C-FV-900-IB TO VALVE 9719Am tx3.H 9 715 505 T TO VALVE 9719$ . .75f.- fM-900.1A AfM 500 FM 100'I 0.75 0.000 IVC-1222(A) 7 IS 505 T 3C FV 900 IA PAST VAt.VE 9727 TO FLANCE. .TSE-fV-900 ~ IS AFV (00 Fll~ 1005 0.7S 0.000 IlC-1222(A) 3C.FM 900 1$ PAST VALVE 9725 TO CAP ~ 715 SDS T .TSF-IV.900 IA AfM SDD fM. 1001 0.75 0.000 IVC- 1222(A) 715 SDS T 3C.FM 900.1A PAST VALVE 972d TO FLANDERS .TSf.f M.900.IB AfM.(00 FM.1005 0. 75 0.000 IlC-1222(A) 715 SDS 3C-f M.900-1S PAST VALVE 972A TO CAP, T .f50.FM 900.1A AfM.500 Ill-1001 0.75 0.000 llC-1222(A) 715 T
'05 3C-f M.900.1A PAST VALVE 9723 TO CAP ~
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Q 0IO R. E. GIMMA MUCLEAR POuER PLAMT Inservlce Exeeinet i on Socsdsry Line List H Closet 2 Third Inspection Intcrvel Xh g I Systeat STEAN CEMERATOR BL(XQ(AAI IA PZID Mo: 33013-1277 RGZE 0 I I SIR'I SMR I ISI Site Thkns Exception MDE Line Mo. Line Mo. Line Mo. F lg. Hatrl. (in.) (in.) Basis Hethod Po Tecp InT Line Description/Renarks 2.00 0.210 luc-1222(A) 1005 SC7 T M. NOZZLE TO FIRST TEE GIRTII QELOh 2l NS.600.1A RGB.100 A106 2S HS.600 ll SCS.100 A106 2.00 0.2ID IMC-1222(A) 1005 SC7 T S. NOZZLE 10 FIRS'T TEE GIRTII MELD t QHQ 2G HS 600 ll SCS.100 A106 2.00 0. 210 IMC- ')222(A) 1005 SC7 T ISI 2C-NS GIRTH OUT FR(SI TEE 2A HS 600 600.'lA TO 1ST 2X2X2 TEE. IA 2S 0'gH 2D.NS-600.1A SGB 100 A106 2.DD 0.2 lb INC-1222(A) ID05 517 T 2E NS.600 IA SGS-IDO,SCS-300 A106 2.00 0.21b IMC-1222(l) ID05 1005 5(7 T T 2" TEE OM 20.NS.600-1A TO VALVE 573b. TEE OM 2C HS 600 IA TO VALVE 5705 ~ g my IA-HS.600-1A SGS 100 A106 1.00 0.179 IMC-1222(A) SC7 S/C.'lA M022LE 10 TEE BEFORE V 57CbA,57Cb IS NS.600 'll IE HS 600 'll SGS SGB 100 100 A106 A106 1.00 1.00 0.'l79 0.179 INC-1222(A) IMC.1222(A) 1005 1005 SC7 SC7 T T IB HS'600 IA 10 TEE PAST VALVE 57Cblh R3~
. 75A-NS.600-1A SGS.100 A106 0.75 0,15C INC 1222(A) 1005 5C7 T IA HS 600 ll TO VALVE 5705Ah IMC.)222(A) 1005 IEE BEfORE VALVE 5731 10 VALVE 5735 .375A.HS 600.1A SGB 100 0.37 0.000 SC7 T h375S-NS.600.1A SGS.100 0.37 0.000 INC-)222(A) 1005 5C7 T O'll'ASS .375A-NS 600-lA TO 2E-NS-600.1Ah .375C H$ .6M IA SGS.100 0.37 0.000 IMC-1222(A) 1005 5C7 T 375B HS 600 IA TO VALVE 5157A L()AOQ ~
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0 1
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R. E. CINMA MUCI.EAR POMER PLAMI Inservice Exatainat ion Stxaxiary Line List Third Inspection Interval H Class 2 Systeat STEAN GENERATOR SLQDOMM 18 F LID Not 33013-1277 0 RGIE 0 I L8 E R I ~ SMR I ISI Site Thkns Except Ion MDE Line No. Line Mo. Line Mo. FIS. ~ Hatri. ' In.) ( In.) Basis Method Po leap Inl Line Descript Ion/Retaarks
$ -3'I A106 2.00 0.21$ luC-1222(A) 1005 SC7 Y N ~ NOZZLE TO FIRST YEE GIRTH MELOs 2A HS-600 18 SCS 200 8-31 A106 2.00 0.218 Iuc 1222(A) 1005 5C7 T S. NOZZLE 10 FIRST TEE GIRTH MELD 28.HS 600 18 SG8.200.
600.1$ ZDO,SCS.CDO $ .31 AIDS 2.00 0.218 Iuc-1222(A) 1005 5C7 Y 2A HS 600 18 S 2$ TO VALVE 5737. QHQ 2C HS IA-HS.600-1$ SCS SCS 200 8-31 AIDS 1.00 0.179 Iuc.1222(A) .1005 57C Y NOZZLE ON S/8-IB TO TEE BEFORE V 570CAh QgH IS-HS.SOO-IS SGS.200 8-31 AIDS 1.00 0.179 Iuc-1222(A) 1005 5(7 T 2C HS 600 'IB TO VALVE 5706 200 A106 1.00 0.179 IMC-122\(A) 1005 5CT Y IA.HS.SOO.IB TO 2C HS-600-1$ . IC NS 600 1$ SGS '.375A HS 600 18 SCS ZDO,SCS-CIMC 0.37 0.000 Iuc. 1222(A) 1005 5(7 Y IA HS 600 1$ TEE TO VALVE 5736, h3758 HS.600 18 SGS CDO 0.37 0.000 Iuc. 1 222(A) 1005 5C7 T ~ .375A HS 600.'IS TO 2C.HS SDO 1$
'.'375$
0.00 0.000 luc-1222(A) 1005 5C'7 .HS.600-18 TO VALVE 5753. I X HS 600 18 SCS.CDO 0.00 0.000 Iuc-1222(A) 1005 5(7 3758-HS 600-1$ TO VALVE 5756A, '- Y H$ .600.18 SCS.CDO C() AO O gl m
4 kg Q
R. E. GINMA NIICLEAR PDMER PLAMF Inscrvice Exaoinat Ion Soundary Line List 1hird Inspect Ion Interval Class: 2 Systeat VESSELS Pf lo Not 33013-1231 RGLE GILSER1 SMR I IS I Site thkns Exception MOE Flo. Matrl. lln.) (In.) Basis Method Po 1ccp ln1 Line Description/Reaarks Line No. Line Mo. Line No. I 0.00 0.000 VGL 715 505 SIEAM GEN IA S 0.1 o.oo o.ooo 215 505 MEAN GEM 1$ arjH Q 0WH
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at a<< R. E. GINNA NUCLEAR PRIER PLAMI Inservlce Examination Boundary Line List third Inspection Interval Cl asst 2 Syst eat VESSElS PE ID No: 33013-12t7 RGtE GILBERI SQRI ISI Site Ihkns Exeeptlon NQE Line No. Line No. Line No. FIG. Hatrl. Fin.) I in.) Basis Method Po teep In) Line Description/Remarks RNEXA )247 B IDP 0.00 0.000 AID 350 RMEXB 1247 B-IDV 0.00 0.000 AIO 350 wive O'@ H grnl s'3~
~ ~
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R. E. GINNA NUCLEAR POVER PLAMT Inservlca Exaeinat Ion Roundary Line List Third Inspection Interval Ciassl 2 Systcnl VESSELS PLID Mot 33013.12d'I SVR I ISI S I so Thkns Except ion NDE ROSE GILRERT po Tecis In) Line Description/Rcearks Line No. Line No. Line No. fly. Hatrl. (In.) (In.) Reals Hethod 0.00 0.000 INC.'1221(A) ~ CS EDUCTOR 'I 12dl 0.00 0.000 IVC 1221(A) CS EDUCTOR R V STOR 2 TANL'2dl 12dl 0.00 0.000 IVC 1221(E) 30 70 <HQ 0.00 0.000 INC.1221(E) SPRAT ADD TANK 12dl Bg
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R. f. CINNA NUCLEAR PDNER PLANT Inscrvice Exaeination Boundary Line L 1st Third Inspection Interval Class: 2 Systcnt VESSELS H PAID Not 33013.1262 0 RGtf DILBERT SNR I ISI Site Thkns Exception NDE In'I Line Description/Rcncrks Line No. 'inc No. Line No. f ID. Natrl. (In.) I in.) Basis Iicthod Po Tccp 0.00 0.000 INC 1221LE) 7A0 BD ACCtssILATDR I '1262
~
0.00 0.000 INC. I221IE) 7AD BD Acctat)LATDR 2 1262 04 1-l' MAO tO H c) Q ifi) Cg a
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R. E GINMA WCLEAR POMER PLANt Inscrvlce Exaoination Secondary Line List Ihird Inspection Interval jb Class: 2 n Systcxa: VESSELS PAID Not 33013-12bb H 0 RGIE GILSERI SNR I ISI Site Ihkns Exception NDE Line No. Line No. Line No. flS. Natrl. (ln.) lin.) Sasis Nethod Po leep In) Line Description/Raasrks NON REG N EX 12bt $ -2 0.00 0.000 VOLISuR 250 350 R C fILIER 12bC $ .3 0.00 0.000 VOLjsuR AO 100 MMQ OgH g rn g oC tan LE) N ~HX aR AE) 0 0 N~ H5 133~ M 0R p j~g
R. E. GINNA NUCLEAR POMER PLAMT Inscrvlce Exaoinstlon Soundsry Line List third Inspection interval Class: 2 Systcot VESSELS PAID Not 33013.1265 RCLE GILSERI SMR I ISI Site Thkns Exception NDE Line No. Line No. Line No. Fly. Hatrl. (In.) (In.) Basis Hcthod Po Tecp Inl L(ne Descript(on/Remarks 2(" CNC PHP P f 1265 $ .6 0.00 0.000 VOL/SUR 2(50 100 PULSE DAHPEMER REC SEAt EX 1265 A.b 0.00 0.000 2300 525 CLASS I C(alPLETE ST DEFINITION fILIER I 1265 B.T 0.00 0.000 VOL/SUR 2(50 100 MHQ S M I I00? OWH S M I FILTER 2 'SEAL MATER N EX 1265 I265 8-7 8.4 0.00 0.00 0.000 0.000 VOL/SUR 2650 VOL/SUR 40 ILO grog P SEAL MATER R f 1265 0-3 0.00 0.000 VOI./SUR 60 1(0 VOL CONTROL TK 1265 B 5 0.00 0.000 IMC 1222(C) 30 100 I Pdn g+~ I Ol cd n WWH@ enoNz L() ol Pjo
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R. E. GINNA NtICLEAR PCMER PLANt Inservice Exaoination Roundary Line List third Inspection Interval Closet 2 Systent VESSELS PLID Not 33013.1266 RCLE CILBERt SMR I ISI Sita 1hkns Exception NDE Line No. Line No. LIne No. I lg. Itatrl. Iin.) I ln.) Sos is Itethod Po leep In) Line Descrlptlce/Renarks 0.00 0.000 INC.12211 E) 5 210 e
tANX A 1266
)266 0.00 0.000 IlC-1221IE) 5 210 R A )AW. S
l Q~ 0
R. E. GINNA NMCLEAR P(XJER PLANT H (/) Ce' Inservlce Essa(nation Boundary Line List Third Inspection Interval Closet 2 Systent MASTE DISPOSAL PAID Not 33013.1272 RCIE 0 ILBER'I SMR I ISI Slee Thkns Exception NDE Line No, Line No. Line No. fig. Hatrl. (In.) (in.) Basis Hethod Po Teep In) Line Description/Reoarks CA.l0.151 RNR-300 A312 C.DD 0.120 IMC-1222(A) 80 PEN 1C3 TO 1ST CX3 RDCR VALVE 1721 Ce IO-1$ 1 RNR-300 A312 C.DD 0.120 INC. 1222(A) 80 RDCR N 3A l0-151 TO VALVE 1003A,
'XC CC.l0.151 3A.IO. ISI . RNR 300 RNR-300 A312 A312 C.DO 3.00 0.120 0.120 IMC-1222(A)
IMC-1222(A) 80 80 CXCXC TEE CX3 RDCR N CB.l0.151 TO CX3Q TEE. N CA.l0.151 TO VALVE 1721.
~HA 04H 38 I0.1$ 1 RNR 300 A312 3.00 0.120 IMC.1222(A) 80 CC.IO 151 10 1ST CQX3 TEEo ps rn .
3C.IO. ISI RNR-300 A312 3.00 0.120 luc-1222(A) 80 CX3Q TEE N CC.IO 151 TO VALVE 10035. g 3D.IO- I 5 I A312 3.00 0.120 INC-1222(A) 80 PEN 107 TO VALVE 1723. . ZA.l0 IS2 2.00 0.000 INC. 1222(A) 80 PEN 129 (XIISIDE CONT TO 1ST TEE'M/RDCRtS IA IO.IS2 1.00 O.DM IMC-1222(A) 80 2A-IO-152 10 VALVE 1785.
. 75A-l0 152 0.75 0.000 IMC- l 222(A) 80 2A 10 152 IO VALVE 1878A TC CNN .TSB LO 152 0.7S 0.000 INC-1222(A) 80 TEE M/RDCR'S ON 2A IO 152 TO VALVE 1713 ~ .75C.IO ISZ N .7$ D IO-ISI .75E.RC.15'I RNR.300 A312 0.75 0.75 0.000 0.120 INC-1222(A)
IMC-1222(A) 80 80
.37SX.75 3C-I0-151 RDCR TO VALVE .375A-I0-152 1709G.
TO V 1789. L()XIT$ M a-+
.37SA l0-152 A312 0.7S 0.37 0.120 0.000 IMC-1222(A)
INC- 1222(A) 80 80 . VALVE PEN 527 'IO 2A-I0-152. 123 TO .37SX.75 RDCR BEFORE V 1789. ~noR ~~ I-I C) 5 M OR QQH
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Q >IOC'i 03 R. E, GINNA NUCLEAR PDUER PLANT M Inservlce Exaolnat ion Boundary Line List P
'Ihird Inspection interval H'/3 Classi 3 O Systoa: -AUXILIARYCOOLANT PBID Not 33013-1245 H 0
R elf GILBERT SVR I ISI Site Thkns Exception NDE Line No. line No. Line No. flB. Hatrl. (In.) lin.) Basis Hethod po leep ln2 Line Description/Resaarks 2F.AC5.152 NIA 2. 00 0. 154 I I0. 1220. 'I c150 <200 7 CC SURGE TANL TO 731A ZG-AcS-152 NIA 2.00 0.154 II0 ~ 1220.1 <<ISO <200 2 CC SURGE TAML TD 713 ZN.AC5-152 CC 170 N/A A53 2.00 0.1$ 4 II0.1220. I <150 <200 2 B23 TO 4C ~HQ Owl-I IA-ACS-ISZ cc-230 N/A A53 1.00 0.145 II0.1220. 'I c150 <200 2, 14A 10 CC SURGE TANK g rn I B.AC5-152 lc-ACS-152 CC-340 CC.340 N/A N/A A53 A53 1.00 1.00 0.133 0.133 II0.1220. I II0.1220. I
<<150 c150 <200 <ZDO 2
2 3A TO BLO00UM SAMPLE HE 3A TO BLO04SIM SAMPLE HE g 1D.ACS 1$ 2 CC.340 N/A A53 1.00 0.133 II0-1220.1 c150 c200 2 3A TO SAHPlE HE A H 1E ACS 152 IF -AC5.152 CC.340
. CC.340 N/A N/A 153 A53 I. 00 1.00
0. 13$
0.133 II0.1220.1 Il0 1220.1
<<150 <150 <200 <200 2
2 3A 10 SNIPLE HE B 3A 10 SAHPLE HE C a w.k.Q
$ p+
IG.AC5.152 CC.3$ 0 N/A A53 1.00 0.133 II0-1220.1 c150 <200 SAHPLE HE C TO CC PWPS IH.AC5-152 II-ACS.'152 CC.350 CC-350 N/A N/A A53 A53:=
1. 00 1.00 0.133 0.133 lt0.1220.1 II0.1220. I
<150 <150 <<2DO <200 2 SAHPLE HE B TO CC PUMPS.
SAMPLE HE A TO CC PtNPS og r/T X ITS ag 1 IJ.ACS-ISZ CC-350 N/A A53 1.00 0.133 II0 1220.1 <<150 <200 2 BLOl00UM SAMPLE HE 4 TO CC PUMPS II0 tf3 H~
~ I IK-AC$.152 IL.AC5.152 CC.3$ 0 CC-350 N/A N/A A53 A53 1.00 1.00 0.133 0.133 1220.1 I I0-1220. I <150 <150 <200 <200 2 BLOI0IMI SAHPLE FAIL fUEL XE 5 TO CC PIRIPS RAD HONITOR HE LEI 0 0 g~
,Fi. IH.Ac5-152 CC.340 N/A A53 1.00 0.133 II0-IZZO.I <<150 <200 2 3A TO FAIL FUEL RAD HDN HE H5 I-IO 5 tx . v) IN ACS 152 I N/A 1.00 0.133 II0 1220.1 <150 <200 2 CC SURGE TANL'O RCV017 IP.AC5.152 CC 240 N/A A53 1.00 0.133 I I0. 1220.1 <150 <200 VENT FRCli ZA
'7. .TSA.ACS-ISZ .7SB-ACS-152 CCr 100 CC-200 'N/A N/A A53 A53 0.75 0.7S 0.123 0.113 II0.1220.1 II0.1220.1 <150 <150 <200 <200 '. -
DRAIM FRDH 100 TO 2702 DRAIN FRDH 148 TO VALVE 737A, 2742
.7SC.AC5-152 CC-200 NIA A53 0.75 0.113 II0.1220.1 <150 <200 2 DRAIN FRDH 14$ TO VALVE 735A ;7SD-AcS-IS2 CC.200 N/A A53 0.7$ 0.'113 IIO-IZZD.I <150 <<200 2. DRAIN FRCH 14$ TO VALVE 735B .7$ E ACS-ISZ CC.1BO N/A A53 0.75 '.75 0.113 II0-1220. I <150 <200 2 2D 10 727P 3R .7$ F ACS.TSZ CC 180 N/A A53 0.'113 II0-1220.1 <150 <200 2 2D TO 7274 .TSG.Ac5-152 CC-300 N/A A53 0.7S 0.113 1l0- 'I 220.1 <150 <200 2 140 TO 779A .TSN.AC5-152 CC-300 NIA A53 i0.75 0.113 II0. 1220.1 <'ISO <200 DRAIN fRDH 4C TO VALVE 727A
0 I @jr H Jf j, y
Q R. E. GIN>>A NUCLEAR POMER PLANT H EI) M 4 Inservice Exa>>inaticn Boundary Line List g H Third Inspection Interval Closet 3 O Systeat AUXILIARYCOOLANT td PSID Not 33013-1246 H ' Rot E GILBERT SVRI ISI Site fhkns Exception NDE Line No. Line Mo. Line No. I io. Hatrl. (In.) I ln.) Basis Hethod Po Teep In) Line Description/Roaarks BA AC6 152 CC-200 M/A c-5 A53 8.00 0.322 VT 3 <150 <200 2 CDHP. CLG. MEX Yo VALVE 817 88-Acb-152 CC.220 M/A c-5 A53 8.00 0.322 Vf-3 <150 <200 CF TO 816 6A-AC6.152 CC-200 N/A c-5 A53 6.00 0.280 VI-3 <150
'200 BA To 813; PEN 131 W Q.Q 68-ACb-152 CC 310 M/A C-3 A53 6.00 0.280 VT.3 <150 <200. 1 CDHP. CLG NE TO CA; 773 6C-AC6.152 CC<<230 N/A C-7 'A53 6.00 0.280 Vt-3 <150 <<2dO CCHP CLG BE YO 3A 8 760A 8 8 ACID EVAP do-AC6-)52 CC.220 N/A C<<5 A53 6.00 0.280 VY-3 <150 <200 2 PEN 130 TO 88 6E.AC6 152 CC-16O N/A A53 6.00 0.280 VI 3 <150 <<200 7 CA TO CDHP COOL ~ PUHPS OOKED dF-AC6.152 CC $ 00, S2$ M/A c-9 A53 6.00 0.280 VT 3 <150 <200 PEN 131 TO 48 6G-AC6.152 CC 300 N/A c-7 '53 A53 6.0O 0.280 VT-3 <150 =
2'200 2 BORIC ACID EVAP TO COHP COOLING PIBIPS 4"
) gAW+
68-AC6-152 CC-$ 75 N/A c-9 6.00 0.280 Vt 3 <150 <200 7 COOLERS To PEN 130 CA-AC6-152 CC.330 4.00 0.237 IN-1220. I <150 <200 749A LO H CB.AC6-152 CC.625, CC.600 K/A M/A A53 ASS 4.00 0.237 IN.1220.1 <150 <200 7 1 BA To REDUCER BEFORE 750A TO RCP gn ag 1 CC-Acd-152 cc-ibo M/A ~ A53 4.00 0.237 IN.1220.1 <150 <<200 7 68 YO 773/ To MON REG. NE TO 778 dF Yo REACTOR SUPPORT COOLER >>8>> LE)cW rd H g CO.AC6-152 CC.525 N/A << A53 4.00 0.237 1lO-1220. I <150 <200 2
~ Lf)
CE.ACb 152 CC-700 NIA A53 4.00 0.237 IN. 1220. I <150 <<200 3E Yo 3F t<< 4 F.AC6-152 cc-7oo,- NIA A53 4.00 0.237 IN-)220.1 <150 <200 1 3F To PEN 126 loge HQQ CG.AC6-152 CC-450 N/A A53 C.oo 0.237 IN.1220.1 <150 <200 2 7508 AT PEM 128 TO RCP 2 CN-Ac6-152 CC.525 N/A A53 4.00 0.237 IN- 1220.1 <150 <200 7 dF TO REACfOR SUPPORt COOLER "A>> M 4)-AC6.152 CC.525 N/A A53 C.oo 0.237 lto. 1220.1 <150 <<200 2 CN TO REACTOR QlPPORY COOLER >>A>> 4 J. Acb-152 CC 525 M/A A53 4.00 0.237 I'IO-1220.1 <150 <20D 48 YO REACTOR SUPPORT COOLER >>A>> CC-AC6-152 CC.525 M/A A53 4.00 0.237 IlO-1220.1 <150 <200 7 REACTOR SUPPORT COOLER "A>> To 4L 4L-AC6-152 4H-AC6-152 CC.525 CC-525 MIA N/A A53 A53 4.00 C.OO 0.237 0.237 IN-1220. I IIO-1220.1
<150 <150 <<200 <200 1 REACfoR SUPPORt COOLER >>A>> YO dN CD To REACTOR SUPPORT COOLER >>8>> &la 4N.AC6.152 CC 525 NIA A53 C.oo 0.237 IN.1220.1 <150 <200 2 REACTOR SUPPORT COOLER 8 Yo 40 Co-Acd-152 CC 525 N/A A53 C.OO O.237 llO-1220. I <150 <200 1 REACTOR SUPPORT COOLER 8 TO 68 4P-AC6.152 CC 400 M/A ASS C.oo 0.237 IIO-1220.1 <150 <200 2 7578 TO P125 CO-AC6-152 CC.220 M/A A53 C.OO 0.237 IIO-f220.1 <150 <<200 CONNECTS 88 8 28 3A-AC6.152 CC.330 NIA A53 3.00 0.216 IN-1220.1 <150 <200 CA To 749A 38-A cd-152 CC.330 N/A A53 3.00 0.216 I lO. 1220. 'I <150 <200 1 DRAIN FRCH 4A TO 7498
g% A tt r. AO C h~) Y 4 IlT
R. E. GINHA NUCLEAR POWER PLANT Inservice Exaolnatlcn Boundary Line List lhird Inspection Interval H Class) 3 Systea: AUXILIARY CDOLANI 0 td PAID Hol 33013 '2/6 H R elf GIIBERT SWR I IS! Size Thtns Exception NDE 0 Line Ho. Line No. Line No. f IB. Hatrl. (In.) (in.) Basis Method Po leep In2 Line Description/Reaerks 3C-AC6-152 CC.600 N/A A53 3.00 0.216 I $ 0. 1220. I <$ 50 <2DO 2 CB TO 751A S RCP I 30-AC6-152 cc 600 N/A A53 3.00 0.216 1l0-1220. I <<150 <<200 2 3C To 752A To RCP 'I 3E-Ace-152 700 3.00 0. 1220. I 3f.AC6 152 CC CC.700 N/A N/A A53 A53 3.00 0.216 0.216 1$ I )0-1220. I
<150 <150 <200 <200 2
2 RCP CF TO I To REDUCER AT Cf 757A 6 Cf
<<sS &Q r 3G-AC6.152 CC-220 NIA A53 3.00 0.216 II0-1220. 'I <150 <200 1 759A TO SB g rn 3H.AC6.152 CC-220 M/A A53 3.00 0.216 I l0. 1220. I <150 <200 2 759S To 40 g
31. Ale. I S 2 CC C00 N/A A53 3.00 o.RIe IM).1220.1 <150 <200 2 RCP 2 TO CP SJ.AC6.1S2 CC SRS N/A A53 3.00 0.216 Il0-'l220.1 <150 <200 2 CH 10 REACTOR SUPPORT COOLER "A" 3r-Ace-I SR CC-525 N/A 3.00 0.216 1)0. 1220. 'I A apl <
A53 <150 <200 CD '10 REACTOR SUPPOR'I COOLER IIBN 3H.AC6-$ 52 r Pl CC.SZS MIA A53 3.00 0.216 Il0.1220.1 <150 <200 7 2771 TD 4L 3H-AC6-$ 52 0-1220.'I ogM xo CC-525 K/A A53 3.00 0.216 $$ <<150 <200 1 REACTOR SUP. COOLER 8 TO 2752 S CH L() 3o-Acd-152 CC-CSD N/A A53 3.00 0.2i6 Il0-1220.1 <150 <200 2 CG To CSIB S RCP 2 3P-AC6.$ 52 . CC-230 N/A A53 3.00 0.216 1$ 0. 1220. I <150 <200 1 6C TO WASTE EVAPORATOR 0 X a~ ZA-Acb-152 CC.330 M/A A53 R.OO O.ISC ll0-1220. I <150 <200 DRAIN FRCII CA TO 7C2A, 7C2C, ELSE $ M H 2$ .AC6 152 CC-250 N/A A53 2.00 0.154 1$ 0. 1220. I <150 <200 68 TO 777C noxQ ~+ RC-AC6.'152 CC.260 N/A A53 2.00 0.154 0-1220.1 <150 <200 '2 H 5 HOQ bf > 1$ CS PIMPS A S S TO 6E . 2O-AC6-$ 52 CC 300 NIA A53 2.00 0.154 IUD-1220.1 <150 <200 1 DISTILLATE COOLER To 60 2E-AC6-152 CC.230 NIA A53- 2.00 0.154 I )0-$ 220. I <150 <200 '2 6C TO DIS'llLLATE COOLER 2F-AC6.15R CC.525 N/A A53 2.00 0.109 $ $ 0-$ 220. I <'150 <200 1 CH To REACTOR SUPPORT COOLER M 2G-AC6.152 CC-270 NIA A53 2.00 O. ISC 1$ 0-1220. I <150 c200 1 6B To Sl PIHIPS 2H-AC6-152 CC-230 N/A A53 2.00 0.154 l$0. 1220. I <150 <200 1 I ~ 5C TO 6G 21-AC6-ISZ CC.220 NIA A53 2.00 0.154 II0.12ZD.'I <150 c200 2 EXCESS LD HE To PEN 124 6 TO CO ZJ-AC6-$ 52 CC.525 M/A A53 2.00 0.109 I WD-1220. 'I <150 <200 1 CD TO REACTOR SUPPORT COOLER IIBN Zr-AC6.$ 52 CC-320 M/A A53 2.00 O.ISC Il0-1220.1 <<$ 50 <<200 2 Sl PIHIPS To 6E 2L.AC6.'$52 CC.230 N/A A53 2.00 0.154 Il0-1220.1 <150 <200 I.SD TO 2H 2H.AC6.152 Cl 700 NIA A53 2.00 0.154 ll0-1220. 'I <150 <200 4f TO 758A 2H-AC6.1SR CC 310 M/A ASS 2.00 0.154 I l0- 'I 220. I <150 <<200 1 6B TO Td3, SEAL WATER Hf 2O.AC6-152 CC.230 K/A A53 R.oo 0.154 $ $ 0-$ 220.1 <150 <200 1 WASTE EVAP To 7648 To 60 2P-AC6.152 CC Coo MIA A53 2.00 0.$ 54 1)0-$ 220.$ <<150 <200 1 CP To 7SBB O
~ ~
4 Q R. E. CINNA NUCLEAR POllER PLAMT M lnservice Exaoination Boundary Line List g lhird Inspection Interval Closet 3 n Systent AUXILIARY CCOLANT PSID Mot 33013-1246 H 0 RGSE GILBERT 'UR I ISI Size Yhkns Exception NDE Line No. .Line No. Line No. flo. Hatrl. (In.) iin.) Basis Method Po In2 Line Description/Raaarks 24.ACb 152 CC-525 N/A A53 2.00 0.109 IN-$ 220.1 <ISO <200 2" REACTOR SUP. COOLER 8 'IO 2753 6 40 RA.AC6-$ $ 2 CC.160 M/A A$ 3 2.00 0.154 IN. $ 220.1 <150 <200 2 SEAL UAIER HX TO 68 I.SA-AC6-152 CC-700 N/A A53 1.50 D. ICS Il0-1220. I c'ISO <200 2 RCP I IO .TSAE 6 CP I.SS-AC6.152 CC-230 NIA A53 1.50 D. ICS 140-1220.1 <150 c200 3A 10 75H =.S.SC-AC6-152 CC.CDO 'NIA A53 1.5D 0.14$ IN-1220.1 <150 <<200 2 RCP 2 10 7558 I.SD AC6 152 CC.230 NIA A53 'l.50 D. ICS IN- $ 220. I <ISO <200 2 764A 10 CAS COIPRESSOR HEX 1-3 A> '.SE-AC6-15R CC-230 N/A A53 1.50 0.145 Il@-$ 220.$ <ISO <<200 2 CAS CO{PRESSOR HEX TO 2L td H 1.5f-AC6-1$ 2 CC.230 M/A AS'5 'I.SD 0.1CS 110-1220. I <1$ 0 <200 1 3P 10 GAS CCHPRESSOR HEX I Pan g SA-AC6-152 CC.TDD N/A A53 1.00 0.133 $ 4D-1220.1 <150 <200 2 RCP I to 7564 6 40 18.AC6.152 CC-$ 60 K/A A53 1.00 0.133 IM)-1220.$ <150 <200 1 766 TO bE LD'H IC-AC6-1SR CC.230 N/A A53 1.00 0.$ 33 IN-$ 220.$ 0.133 IN.1220.1
<150 <200 2E TO STEAM AIR COOLER ogSOT Cd+
ZQ ID ~ AC6-152 IE AC6 ~ 152 CC-450 CC.310 N/A NIA A53 A53 1.00 1.00 0.133 14D-1220.$
<150 <150 <200 <200 1 30 TO 2528 10 276 10 CA RCP 2 % X IT3 H ag lf AC6-152 ~ CC-300 M/A A$3 1.00 0.133 IN 1220.1 <SSD <200 2 .2748 TO 6C en OX w T~XS IS.AC6.$ 52 CC-400 N/A A53 1.00 0.133 $ 10.1220.1 <150 <200 RCP 2 TO CP LD+g tB . IN.ACb-'l52 230 N/A 1.00 0.133 $ 10-$ 220.$ < ISO <200 1.5D TO 774A TO 2D 11-AC6-152 CC CC.230 M/A A53 A53 1.00 0. D3 II0-1220.1 <ISD <200 '2 ~ 77CD TO I.SC S-S O g I J-AC6-152 CC.300 N/A A53 1.00 0.133 IN.1220. I <'I50 <200 1 STEAM AIR COOLER TO?CBO TO 2D M IX AC6.152 CC-300 N/A A53 1. 00 0.133 IN. $ 220. I c150 <200 77CC TO 60 .TSA.AC6.15'2 .TSM AC6 152 CC-600 CC-270 M/A N/A A53 A53 0.7S 0.75 0.'113 0.113 ILO-1220.1 110-1220.1 <150 <150 <200 <200 2
2 CA TO,TSOC 777L TO Sl PWP 1 g C) $ -3
. TSAR.AC6- I 52 .25AC-AC6- $ 52 CC-230 CC-210 N/A N/A A53 A53 075 0.25 0.113 0.113 IN-$ 220.$
IN.1220.1 c150
<150 <200 <200 'I.SC 10 727H 6 J 77lf '10 Sl PWP I Pma . TSAD.AC6.'l52 CC-230 M/A A53 0.7S 0.113 $ 40.1220.1 <150 <200 '2 1.5C TO 7lCD .75AE-AC6-152 CC C50 NIA A53 0.75 0.113 $ 10-1220.1 <150 <<200 2 4E 10 7500 .TSAT.AC6-$ 52 CC.320 N/A A$3 0.15 0. 113 IN-$220. I <1$ 0 <2DO 1 Sl PUHP 'I 10 777)l '0
~ .TSAS.Ac6-152 CC 230 NIA A53 0.25 0.1$ 3 ll0 1220.1 <'150 <200 2 StENT fROI I SD '10 2712 C)
.TSAR-AC6-$ 52 CC-CSD N/A A53 0.7$ 0.113 IN-$ 220.$ <150 <<200 30 10 2737 m .25ll-Acb-$ 52 CC-320 k/A A53 0.1$ 0.1$ 3 140 1220.1 <150 <200 Sl PIRIP 1 TO lllE 43)
Ql
Q R. E. GIMMA NUCLEAR P04ER PLANI M lnservice Exaaination Boundary Line List g third Inspection Interval Class: 3 n Systeal AUXILIART COOLANT PC ID Not 33013.1246 RGCE. GILBERT 8481 ISI Slee thkns Except Ion MDE Line No. Line Mo. Line No. f 18. Hatrl iin.) (in.) Basis Hethod Po leap Int l.lne Description/Renarks
.TSAJ AC6 152 CC.230 M/A A53 0.75 0.113 II0-1220.1 <150 <<200 I.SE TD 727K 8 L .TSAX-ACS- ISZ CC-CDD M/A ASS 0.75 0.113 140. 1220.1 <150 <200 'I 31 to 274$ .75AL-AC6-152 CC 270 N/A A53 0.75 0.113 I IO. 'I 220. 'I <150 <200 TTTN 10 Sl PIBIP 2 HQ 75AM ACS 152 CC;230 M/A A53 0.75 0.113 I)0. 1 220.1 <'150 <200 1 'lO GAS COHPRESSOR NEX O@H 75AN.AC6-1$ 2 CC-400 N/A A53 0.75 0.113 IIO. 1220.1 <150 <200 2 31 TO 2739 g rn g .TSAO-AC6-152 cc-270 NIA A53 0.75 0.113 ILO. '1 220. I <150 <200 n7H 10 Sl PIBIP 2 .15AP-Ac6-152 CC.CSO M/A AS3 0.75 0.1 I3 I IO- 1220. 'I <150 <200 -
1 30 TO 2736
.75AG-ACS. ISZ CC.320 N/A A53 0.75 0.113 I IO. 1220. I <150 <ZDO 1 51 PNIP 2 TO TVP .75AR-Acb- ISZ - CC-400 N/A A53 0.75 0.113 1l0-1220.1 <150 <200 VENT TRDH 1.58 TO 2744 w Pf n .7SAs-Ac6-152 CC-320 M/A A53 0.75 0.113 IIO 1220.1 <150 <<200 Sl PUMP 2 TO 7778 It) H .7$ AT-Ac6-152 .75AU-AC6.1$ 2 CC:4$ 0 CC-270 NIA M/A A53 A53 0.75 0.75 0.113 0.113 14D-1220.1 IIO. 'I 220. 'I <150 <'150 <<200 <200 1
2. VENT fRDH CE TO TTTS '10 Sl PtaIP 3 2743 ow can
.7$ AV.ACS 152 CC-450 NIA 0.75 0.'113 140.'1220.1 <150 <200 4G TO 2735 A53 2 Lt) 'X IT3 Hg .TSAU-ACS-152 .75AX-AC6.152 CC.270 CC'.400 N/A NIA A53 A53 0.7$
0.7S 0.113 0.113 110.1220.1 14D-1220.1
<150 <150 <<200 <200 1
2 TTTJ '10 Sl PIBIP 3 1.58 TO 765A 8 8
~now< .TSAT-ACS-1$ 2 CC.320 KIA ASS 0.75 0.'113 IIO IZZO.I <150 <200 1 Sl PIMP 3 TO TTTR .7542-AC6.152 CC-330 M/A 1 A53 0.75 0.113 II0.1220.1 <150 <200 1 ZA TO 277S . 7$ 8.ACS.'I 52 CC-250 N/A i A53 0.75 0.113 140.1220. 'I <'150 <200 28 10 CS PIBIP 1 .TSBA.AC6-152 CC-320 M/A A53 O.TS 0.113 II0-1220.1 <150 <200 . 1 Sl PQIP 3 TO TTTK .1588-AC6.152 CC-220 N/A A53 0.75 0.113 IIO 1220.1 <150 <200 2 21 TO 74C 7$ 8C AC6 152 CC-320 NIA A53 0.75 0.1'13 140-1220. 1 <150 <200 2L 10 727f 2 0 ~ 7SBD-ACS-152 CC.SDD N/A A53 0.75 0.113 IIO 1220.1 <150 <200 VENt fROH SA TO 2733 gjo .758E-AC6.152 .75$ f-AC6.152 .7588-AC6.152 CC-310 CC.52$
CC.310 M/A N/A NIA A53 A53 A53 0.7$ 0.75 0.75 0.113 0.113 0.113 I IO. 1220. I IIO-1220. I 14D-1220.1
<150 <150 <150 <2DO, <200 <200 'I 2 VENt fRGH 2E TO 2716 4G TO 2769 DRAIN fRGH 2E TO 2720 1 .7588.AC6-1$ 2 CC-52$ N/A A53 0.75 0.113 IIO 1220.1 <150 <200 1 41 10 2766 .7S 8 I -AC6.152 CC-SI0 NIA ASS 0.75 0.113 I 40. 1220. I <150 <200 2 2E 10 766 .258)-ACS.ISZ CC-SZS N/A ASS D.TS O.its IIO 1220.1 <150 <<200 1 41 10 2767 .7$ $ X.ACS.ISZ CC-310 N/A As'3 0.75 0.113 IM).1220.1 <150 <200 1 CA TO TTS
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R. E. GIMXA NUCLEAR PANNER PLANT Inaervice Exewination Stxxx>ary Line Liat Thtrd Inspection Interval Class: 3
.Syateat AUXILIARY COOLANT PS ID Not 33013.1246 Rat E GILBERT ISI Site Thkns Ex<op! Ion NDE Line Mo. Line No. Line Mo. fls. Matri. (in.> (in.) basis Method I'o Teep Inl Line Deacrlption/Remarks .TSSL.AC&.>st Cc.sts N/A A53 0.75 0.1'l3 IN->220.1 c>50 <<200 1 4/ To 2768 .5SN-AC&->St CC.>60 NIA - A53 0.75 0.113 IN 1220.1 <150 <200 4A 10 2718 .7$ sx.AC&->$2 CC-55 N/A A53 0.75 0.113 IN 1220.1 <150 <200 1 4H 10 2751 ex3 MQ Tsso.Ac6-152 CC. 1 &0 MIA A53 0.75 0.113 IN-1220. > <150 <200 4A To 727R 4 S OWH .TSSP AC6 152 .Tssa-Ac&-152 CC-55 CC-160 M/A M/A A53 A53 0.75 0.75 0.113 0.113 IN.>220.'I IN 1220.'I <150 <200 cl5 0 <200 '1 7
27S4 10 4H 68 10 2722 gag
.TSSR AC& >52 CC-Sts M/A A53 0.75 0.113 IN 12C0.1 c1 50 <200 1 68 ID bib H
~ ..TSSS-AC& ISC CC.310 MIA A53 0.75 0. I 13 IN 12to.'I <150 <200 'I DRAIN FRCH 4A TO 272> $
.75ST.AC& 1st CC-55 M/A A53 0.7S 0.113 IlO->220.1 c>50 <200 '7 68 10 2734 >, td 0
r7SStI-AC6.1st CC.260 NIA A53 0.7S 0.113 IIO->220.1 <150 <200 CS Ptstp I TO 2C
.TSSV-AC&.>52 CC-220 M/A A53 0.75 0.113 >N 1CCD.> <<150 <200 1 60 10 2725 ~ o '4 .Tssu-Ac&-152 CC.260 NIA A53 0.75 0.113 IN->220.'I cl5 0 <<200 1 CS PWP 2 To 2C .Tsc-AC6-152 CC.300 N/A A53 0.75 0.'l13 IN->220.1 <>So <COO '7 60 'lo 7748 ~ .7$ 0-Ac6-1st iTSE-Ac&->52 CC-220 CC-220 N/A NIA A53 ASS 0.75 0.75 0.113 0.113 IN.1220.1 IIO '>220.1 <150 <150 <200 <200 7 68 To 73&A 6 8 21 10 2727 ooRR .75f.AC6.152 CC-220 NIA A53 0.75 0.113 IN 1220.1 <150 <200 30 10 2729 .TSG AC6 1st CC-700 N/A ASS 0.75 0.1>3 IN 1220.> <1S0 <200 DRAIN fRCH 4D ;TSN AC6 1st CC-700 NIA A53 0.75 0.113 IN lt20.1 <150 <200 1 1.5A TO 755A ,.751-AC&-1st CC-700 M/A AS'3 0.75 0.113 IN->220.> clso <2 DO VENT FRCH 'I.SA TO 2773 .75/-AC&->52 CC-700 N/A ~ A53 0.75 0.113 Ilo-1220.1 IN. > 220. >
ci5 0 <200 7 DRAIN FRDH IA 70 2759 OR
..TSC-AC&-1st CC-600 M/A A53 0.75 0.113 cls0 <200 3D TO 2774
.TSL-AC6-152 CC-600 M/A A53 0.75 0.'l13 llO l220.1 <150 <<200 48 TO 2757 .TSM.AC6-152 CC-600 MIA A53 0.75 0.1'l3 IN->220.> <150 <200 1 48 To 2772 .75N-Ac6-152 CC 600 N/A A53 0.7S 0.113 IN 1220.1 c iso <200 DRAIN FRDH 3C To 27SS .750.AC6-152 CC-400 M/A 'ASS 0.75 0.113 IN.>220.1 ciso <<200 1 1*58 To 7558 'TSP-AC&-152 CC.220 N/A A53 0. 75 0. 113 IN 1220.1 c>50 <<200 1 38 lo 273> ..TSa-Ac&. >St CC.SCS M/A ASS 0.75 0.'I>3 ItO.I'220.1 c>50 <<200 4L 'ID 2749 75k-AC6 ISC CC 700 . M/A A53 0.75 0.1 I3 IN 'l220.1 <150 <200 1 VENt fRDH 4E TO 2775 .7$ 5-AC&-1$2 CC.700 M/A A53 0.75 0.'I >3 IlO 1220.1 c>50 <200 VENT fRCH 4C 10 2758 O
0 lO R. E. GINNA NUCLEAR POIER PLANI lnservice Exeelnat i on Bouxlary l.ine List 1hird Inspection Interval H Classl 3 Systcnl AUXILIARY COOLAR1 PS ID Not 33013-1216 ROSE 0 ILBER1 SVR I ISI Site lhkns Exception NDE Line No. Line No. Line Mo. fig. Matrl. (In.) <In.) Basis Ilcthod Po leep ln2 Line Description/Recaarks .7$ 1 AC6.1$ 2 CC-200 N/A A53 0.75 0.113 IIO-1220.1 <150 <<200 DRAIN fRDH 017 10 2709
.75U.AC6-152 CC-RSO M/A A53 0.75 0.113 IlO-1220,1 <150 <200 2B 10 CS Ptalp 2 0.75 0.113 IlO-1220.1 <150 <200 2 DRAIN fROH 2D 10 2710 le H Q
.75V.AC6 1$ 2
.7SN AC6.152 CC.300 CC-200 N/A N/A A53 A53 0.75 0. 113 IlO. 1220. I <150 <200 2 DRAIN fROH bA 10 2723 OWH P .75X-Acb-152 CC-260 M/A A53 0.75 0.113 IlO-1220.1 <150 <200 2B 10 727D f, E 10 774C g my .7Sy-AC6-152 CC-300 N/A A53 0.75 0.113 IIO-1220.1 <150 <<20D 2 RD .7SR.AC6.1S2 CC 330 N/A A53 0.75 0. 113 I lO. 1220. I <<150 <200 2 DRAIN IROH 3A 10 2730 V'H 'I Ul gQ LEIX<Hg a =-
1000'~
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R. ED GINHA NUCLEAR PDVER PLANT Inservice Exatainatlon Boundary Line List Third Inspection Interval Closet 3 O Systen: AUXILIARY FEEDVATER PSID Mot 33013 1237 H RGCE GILBERT SVR I III Slee Thkns 0 Exception NDE rr =-rex r Line No. Line No. Line No. f IB. Hatri. I in.) tin.) Basis Method Po fecp In) 'Line Description/Roaarks
, t lc 'SA FM 900-1 AfM-200 C- I A106 5.00 0.375 VT-3 1250 100 fM = AUX PUMP DISCHARGE TO 3998 SB.FV.900.1 AFM-200 C IA A106 5.00 0.375 VT-3 1250 100 2 3F ID REDUCER AT C003 SC FV-900-1 CA-CD-ISO. I AfM-C00,200 A106 5.00 C.DD 0.375 0.237 IIO.1220.1 Vi-3 '1250 100 2 2
3H TO 3J SERVICE MATER TO AUX fM PLNP
~ <MQ .OgH CA.CD- ISD IA SM.1520 C-33 A53 C ~ 00 0.237 IIO-1220.1 12 80 COll TO AUX fM PLRIP A SUCTION ' gtnC CA.CD 150 18 Ql. 1520 C 33 A53 4.00 0.237 IIO ~ 1220.1 VT-3 12 80 C016 10 AUX fV PUNP 8 SUCTION CA Ql 12$ IA C 33 A53 4.00 0.2)7 Ito. 1220.1 75 80 2 STATION SERVICE MATER TO AfM PLIIP A CA-SV.12$ -IB 0.237 Ilo-1220.1 C.OD SER MATER TO C013, 4098 TO 4A CD 1SD ~ I CC.CD-150.1 Ql 1520 C.33 A53 C.DO 0.237 llO.1220.I 12 80 2 4A TO 4027 AND CA SV 125 1A CD.QI 125 IA C-33 A53 4.00 0.237 IUD-1220.1 75 80 4028 TO 43CC CE CD '150 'I 34.fV 900.1A Ql 1520 Afll.100,500 C-33 IA A53 C.OD 0.237 IVO R )220.I 12 80 2, 401C TO 402C ogHU) tE) 3A-FV.900-18 3C.fM-900-1 AFV.IDD,CDO AFV 100 C
C C 10 lf A106 A106 A106 3.00 3.00 3.00 0.300 0.300 0.300 VT-3 VT.3 VI-3 1250 1250 1250 100 100 100 2 2 AUX fV PUNP A DISCHARGE TO CDODC AUX FM PLRIP 8 DISCHARGE TO CDOGD 3A TO 3A-FM-900-18, ~ C356,7, 4000ASB I tf) a-ta<HQ 3D.FM 900 I AFM-100 3.00 O.C3& VT-3 1250 100 BYPASS BETVEEM 4357 AMD C356 tJ) 00 N ~ 3E.fll 900 1 AfM 100 C.1D A106 3.00 O.C38 V1.3 'I 250 100 3C TO SA fM.900-1 H 5 Ixf m 3f.fV.900 'I AFV 200 C. I AI06 3.00 0.300 VT-3 1250 100 2 SA TO CODI 1-1 0g 30.fV.BDO-I AfM 200,5OD C IA A106 3.00 0.300 VT.3 1250 100 SB TO C003 3H IM 900-1 AfV.200 ~ A106 3.00 0.300 VT-3 1250 100 SA TD SC,.CDOO, 4002 3J.F M.900-1 AFM.200 A106 3.00 O.C38 VT.3 '1250 IDO 5C 'IO C004 2 2A.IV 900-1 C-I 2A FV.900 'IA AFM 100 C IG A106 A106 2.00 2.DD O. ICS 0.14$ VT-3 VT.3 1250 1250 100 100 2 2 SA TO C291 AMD 4290A 3A 'IO 4304 $ 8H 2I FV 900 2B.fV 900.18 IA AFV.IDD C C 1H 10 A106 2.00 2.00 0.145 O. ICS VT.3 VI.3 1250 1250
'100 100 2 2A TO CC82, CCBO, 4C83 2A 10 CCBC, 4CBI, CCBS ~
3R 2A.fM 900.18 AFV-100 C 18 A106 1.50 0.200 VT 3'250 100 7 3A TO 4310 1.2$ A.QI.12$ .1A C-33 A53 1.25 0.133 IlO-1220.1 75 80 4A TO C091 1.25I.QI.125.1A C.35 A53 1.25 0.133 Iso- 1220. I 7S 80 CA TO .SB IA.CD-ISD.IA SM 1520 C-33 A53 1.00 0.133 IUD-1220,1 12 DRAIN fRON 4C TO C3C3
'IA.SV-125-1A C-33 A53 1.00 0.133 IUD-1220.1 75 80 2 SA TO LUBE OIL CLEANER ~ r O TI o (
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Q R. E ~ GINNA NUCLEAR PNIER PLANT Inservice Exanlnation Boundary line List M g" Third Inspection Interval Class: Sya ten: AUXILIART FEEDMATER PAID Nol 33013-1237 RGCE GILBERT SMR I ISI Site Thkns Exe<<pt Ion NDE line No. line No. Line No. F IS. Natri. (In.). I ln.) Seals Nethod Po Te<<p In'I Line Description/Re<<xtrks IA.QI 125.1B I ~ 00 0.133 II0.1220. I 2 4A BTPASS TO C292 B C293 . IB ~ CD 150.'IA SM 1520 C-33 A53 1.00 0.133 II0.1220.1 12 BO 4083 TO 429C, .SA IB ~ SM. IES-IA C.33'.33 A53 1. 00 0. 133 IIO-1220. I 75 BO 2 ~ SB TO LUBE OIL CLEANER W M Q'@H
.7$ A CD-150 ~ IA SM-1520 A53 0.75 0. 11$ IIO. 1220.1 12 BO CA TO C026 AND 4A CD 150.1B ~ 7SA CD- 150. IS QI.1520 C.33 A53 0.75 0.113 II0-1220.1 VT-3 12 BO 2 ' CA TO 4022 gmg .TSA fM.900 ~ IA A FM-100 C IA A106 0.75 0.113 VT 3 1250 100 3A TO 4351A ~ 7$ A fM 900 IS AFM.IDD C IN A106 0.75 0.11$ VT-3 1250 100 3A TO C$ 50A 0.75 0.11$ II0.1220.1 2 . 4020 .TSA-SM.I25 ~ IS TSS'CD 150 IA . QI. 1520 C-33 A53 0.75 0.113 II0.1220.'I 12 BO CA TO CA 'fO C02'I n .75B-CD-ISO-IB SM-1520 C-33 A53 0.75 0.1'13 IIO 1220.1 VT.3 12 BO 2 CA 10 C305 .7$ B 900-IA AfM-100 A106 0.75 0.1'IS VT-3 1250 100 2 3A 10 C353A FM C 1A OQ .75B FM.900-1S AfM 100 C IN A106 0.75 0.113 VT-3 1250 100 2 3A TO C352A g
0.75 0.'113 IIO 1220.1 .SA TO 4324 U LE)XWH Q
.TSB SM 125 IB 2 Q .75C. fM-900-TA .QC'FM 900 lB AFM-100 C.IA A106 0.75 0.75 0.113 0.113 VT-3 VT-3 1250 1250 100 100 '2 DRAIN FROIl 2B TO 4C93 DRAIN FRDN 2B TO CCB7 ~now ~ ~ 75D fM.900 I .TSE.FM.900.1 AFM-200 AFM.200 A106 A106 0.7S 0.75 0.113 0.113 Vf.3 VT-3 '1250 1250 100 100 2
2 5C TO 434B SC TO 4346 H3m~ Hog
.5A.CD 150.1 SM 1520 C-33 A53 0.50 0.100 IIO 1220.1 12 7 ~ 75A TO 4024 ~ SA-QI.125-1A C.33 A53 0.50 0.100 II0.1220.1 7S BO 1.25A TO AUX FM PNIP A .SA-QI.125.1B 0.50 0.100 II0-1220.1 CA TO 40B9 t AUX PINP SS QI '125 IA C-33 A53 0.50 0.100 II0.1220.1 2 1.25B TO AUX fM PLWP B C) lll O
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R~ E. GINMA MUClEAR POVER PLANT Inservice Exaeinat lan Bouxlary Line List 1hird Inspection Interval Class: 3 systeet cHEHIclL voltatE 6 coNTRDL PAID Not 33013.1267 RCAE GILSER'I SVR I ISI Sl to lhlns Ea sept Ion NDE line Mo. Line No. Line No. FIB. Hatrl. Iln.) (In.) Basis Method Po Feels In2 Line Descript Ion/ReeLarks 64-CHT-IS) A53 6.00 0.280 VT 3 2 48, 4C, 4D 10 4E 4A-CHT 15'I A53 4.00 0.237 lt0 1220.1 IIDOA, 1103A 10 HOLDUP 1ANKS A/BfC 4S-CH7.151 .A53 4.00 0.237 II0 1220.1 HOlOUP 1ANK A TO 6A, 1127 4C.CHT ISI A53 4.00 0.237 II0.1220.1 MHQ 4D.CNT 151 4.00 HOLDUP TANK S 10 1126, 6A O g.H 4E ~ CHT. IS) A53 A53 4.00 0.237 0.237 I)0-1220.1 IL0.1220.I HOLDUP TANK C 10 1113, 6A X rn'g 2 6A 10 RECIRC PLFIP SUCTION 4F.CH7-151 A53 4.00 0.237 lt0.1220.1 RECIRC PISIP DISCHARCE 10 4A 34-CHT. ISI A53 3.00 0.216 110-1220.1 2 .HOLDUP TANK B 10 1266 3$ -CMT ISI A53 3.00 0.216 lt0-1220.1 HOLDUP TAMK C TO 1265 3C-CH7.151 3D.CH7-151 A53 3.00 0.216 I)0-1220.1 ~ 2 2 4A, I'100$ 10 3D &tdng ~ A53 3.00 0.216 I)0-1220.1 4A, 1100C TO 11000 3E CHT ISI A53 3.00 0.216 It0-1220.1 ION EXCHANGER TO 1164 3F ~ CH7-151 A53 3.00 0.216 Il0-1220.1 3G CHT 151 A53 3.00 0.216 I)0 1220.1 2 IDH EXCHAHCER 10 1172 IOM EXCHANGER 10 1184 i LI) ITS K FEF 5H 5 Ls5 3II.CH7-151 CHT-151 A53 3.00 0.216 110-1220.1 ION EXCHANGER 10 II89 LT)AOR M RA A53 2.00 0.154 II0 1220.1 2 HOLDUP I'ANKS A,B,C TO VEN'1 HEADER RB-CHT-)51 A53 2.00 0.154 II0.1220.1 2 2A TO 1123C RC CHT-'IS I IIO. )220.I A53 R.DO 0.154 ~ '2 2A TO 11238 RD-CMT-ISI 2.00 A53 0.154 II0-1220.1 2A TO 1123A r 2E CN7 '151 A53 2.00 0.154 1t0.1220.1 2 HOLDUP 1ANK A 10 1267 2F-CH7.151 2r-cH7-151 A53 2.00 0.154 110.1220.1 2 4A TO 361 4WQH OR A53 2.00 0.154 lt0 1220.1 RM-CHT-151 RI.CIIT.'IS I
. A53 A53 2.00 2.00 0.154 0.154 II0.1220.1 II0.1220.1 2
2 HOLDUP TKS A,B,C TO GAS SIPR PHPS A 8 B DEHIN TO IOH EXCNAMCERS CATIOM IOH EXCH 2 TO 1163 Nio 2)-CHT. IS) A53 2.00 0.154 II0.1220. I '2 CATION !ON EXCH 1 TO I'170 2K-CHT-151 A53 2.00 0.154 I t0-1220. 'I BASE REMOVAL IOM EXCH 2 10 1183 2L-CNT-IS I A53 2.00 O.IS4 lt0 '1220.'I BASE REHOVAL IOM EXCH I 10 '1186 RM.CN7-151 A53 2.00 0.154 lt0-1220.1 HOIDUP TANK A TO 1272 2N-CHT-IS I A53 2.00 0.154 IM)-1220.1 2 HOIDUP 1AMK B TO 1271 o m Is
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~ AN R. E. GIMMA WC(EAR PO4ER PLANT Inservlce Exaoinat ion Boundary Line List Ihird Inspection Interval Classt 3 O
Systent DIESEL CENERATDRS P(IO Mot 33013-1239 RCIE CILSERI S4R I ISI Site lhkns Except Ion NDE Line Mo. Line Mo. Line Mo. fig. Matrl. (In.) (in.) Basis Method Po T<<ets In) Line Description/Roaarks ISED 1.25A. I0-150-6A 1.25 0.133 110 1220.1 DAY 'IAMK A TO 1 58 I.ZSA-FO.I50.68 I ~ 25 0.133 I l0. 1220. I 2 1.5C TO DAT TAML'TPASS IA-fO 150.6A 1.00 0.133 140-1220.1 FRY 1.58 'IO ,75A H rs$ Q IA.FO 150 68 1.00 0.133 110-1220.1 2 1.5A 10 2A 9 4,H IA.SA.150 (8 1.00 0. T33 140. '1 220.1 7 59(6A TO 59(ZA, 59(28 g rn g 18 fO 150 6A 1.00 0.133 I(0. IZZO. I OAY TANK TO ZA f0.150 '8 1.00 0.133 l40 1220.1 2 1.5C TO 5938
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R. E. GIHHA NUCLEAR POVER PLAMT Inservice Exaainat ion Btxadary Line List Ihird Inspection Interval ciasss 3 Systee: VASTE DISI'OSAL PAID Mot 33013 1271 'RGIE GILBERT SVR I ISI Site Thkns Exception HDE Line Ho. Line No. Line No. f lg. Liat rl. (In.) (In.) Basis Method Po In2 Line Oescrlptlon/Renarks 0.1(5 IL0-1220.1 '2 7750 2A ACI ~ IS2.A 2.00 CCLLPOMENT COOL IMG TO 2A LOI IA 2.00 0.1(5 ILO- 1220. I -2 fEEO TANK '10 VHT RS.ACI ~ 152.A 2. 00 0. 1(5 ILO. 1220. 'I 2 COHCEHIRATOR TO N(B CCLLPONEMT COOLING Ls5& Q 2C.ACI ~ 152-A 2.00 0.1(5 I VO-1220. I 2A TO DISTILLATE COOLER NE OQH RD AC1.152 A 2.00 0.1(5 IL0-1220.1
'2 DISTILLATE COOLER ILE TO 2B ~ 2620 grng.
IA.AC1.15 R.A 1.00 0.133 IL0.1220.1 20 TO 2627A IA.LOI~ IA 1.00 0.133 ILO. 1220. I 2 , fEEO TANK TO fEED TANK PUMP SUCTION IS LOL ~ LA 1.00 0.133 LLO-1220. I 2 ffED TANK 10 fEEO TAN'K PULLP DISCHARGE, LLO-1220. I IC LOI IA 10 LOI ~ IA 1.00
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R. ED GINNA NVCLEAR POWER PLANT Q gA Inservlce Exaainatlon Boundary Line List M Third inspection Interval P Class: Systast 3 SERVICE llATER n F410 Not 33013-1250 RGIE G!llfRT SVR I IS! Site Thkns Exception NDE Line No. Line No. line No. F IB. Hatrl. (In.) (in.) Basis Hethod Po Tarp 'In) line Description/Raeerka BR-S10.125 9 C-168 A53 8.00 0.327 VT-3 75 80 2 4627 10 1CE bl QO.125 9 C.17 A53 8.00 0.327 Vl~ 3 25 80 2, 20A 10 4609
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REV. PAGE QUALITY ASSURANCE MANUAL 1 OF 1B GINNA STATION EFFECTIVE DATE: January 1, 1990 ROCHESTER GAS & ELECTRIC CORPORATION SIGNATURE DATE TITLE: ATTACHMENT B PREPARED BY: APPENDIX B GINNA NUCLEAR POWER STATION QUALITY ASSURANCE INSERVICE INSPECTION PROGRAM REVIEW FOR THE 1990-1999 INTERVAL APPROVED BY: ATTACHMENT B INTRODUCTION The drawings included in this section are divided into four(4) groups. The four groups are classified as follows:
1) Class 1 Non-exempted Systems

2) Class 2 Non-exempted Systems

3) Class 3 Non-exempted Systems

4) Exempted System Drawings Each drawing is a "Class Boundary" drawing that have been used to identify lines in the preparation of "Line Lists" as shown in Attachment A. The first three groups identify Class 1, 2 and 3 Systems that have lines and/or systems requiring examination as indicated on the line list. These drawings identify examined lines by incorporating a color code for Class 1, 2 and 3 Non-Exempted Systems.
The color code for examined line for Class 1 is blue; Class 2 is red and Class 3 is green. Exempted lines and systems shown in the fourth group are not colored for easy reference.
42 52B TITLE: ATTACHMENT B REV. QUALITY APPENDIX B ASSURANCE GINNA NUCLEAR POWER STATION 0 MANUAL INSERVICE INSPECTION PROGRAM PAGE GINNA STATION FOR THE 1990-1999 INTERVAL OF
'-.ATTACHMENT B Class 1 Non-Exem ted S stem Drawin s Introduction All Systems/Lines that require examination by Code Requirements or Rochester Gas and Electric are indicated in blue overlay.
The following Class 1 Non-Exempted PAID Drawings are included after this listing: 33013-1247 Rev.8 33013-1258 Rev.3 33013-1260 Rev.6 33013-1262 Rev.9 33013-1264 Rev.7 33013-1265 Rev.7
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ATTACHMENT B Exem ted S stem Drawin s Introduction This section lists Class 1, 2, and 3 PAID Drawings that are exempted from examination. This section is provided to support the Line List Section as found in Attachment A. The following is a listing of Exempted .System P&ID Drawings that is included in this section. 33013-1232 Rev.4 33013-1234 Rev.5 33013-1241 Rev.5 33013-1248 Rev.5 33013-1263 Rev.2 33013-1268 Rev.4 33013-1269 Rev.3 33013-1270 Rev.2 33013-1271 Rev.2 33013-1272 Rev.5 33013-1273 Rev.8 33013-1274 Rev.5 33013-1275 Rev.2 33013-1276 ..Rev. 2 33013-1277 Rev.5 33013-1278 Rev.9 33013-1279 Rev.4 33013-1865 Rev.2 33013-1870 Rev.2 j s i,'s IO I I I l2 KIIA II 0 IOII 5/4>> ZANCNCO I 0510 ZSO 2/4 I 053 Xstt M 291 I io-2) SXOI X 1904 16 STCO VL CL COI CCQ 2) ~ 5501) IZSS (XQQCCTICH 4S IA IZ m 0 g (A-12) PX (AJ4O STUi(XQC, PX D 2 D STOI 3 IKTI I WIN SIKIU C/IC SIU. (Xt(L ILAIC STU. Cittl. 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1.0 INTRODUCTION

1.0 INTRODUCTION

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