ML20196F971

Owner Rept for ISI for Vogtle Electric Generating Plant, Unit 1 Eighth Maint/Refueling Outage

ML20196F971
Person / Time
Site:	Vogtle
Issue date:	05/31/1999
From:	SOUTHERN NUCLEAR OPERATING CO.
To:
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ML20196F921	List: ML20196F917 ML20196F971
References
NUDOCS 9907010021
Download: ML20196F971 (400)

Text

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Vogtle Electric Generating Plant Unit 1 -

Eighth Maintenance / Refueling Outage (IR8)

Owner's Report for Inservice Inspection Southern Nuclear Operating Company the southern electric system kNk 4

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'O OWNER'S REPO,RT FOR INSERVICE INSPECTION for the EIGHTH MAINTENANCE / REFUELING OUTAGE of VOGTLE ELECTRIC GENERATING PLANT, UNIT 1 (7821 River Road, P. O. Box 1600, Waynesboro, Georgia 30830) i l

COMMERCIAL OPERATION DATE: May 31,1987 DOCUMENT COMPLETION DATE: May 1999 i

O Prepared by SOUTHERN NUCLEAR OPERATING COMPANY (40 inverness Center Parkway, P. O. Box 1295, Birmingham, Alabama 35201) as LICENSEE AND OPERATING AGENT for GEORGIA POWER COMPANY (241 Ralph McGill Boulevard, N.E., P. O. E]x 4545, Atlanta, Georgia 30308-3374) as OWNER

TABLE OF CONTENTS Introduction 1-1 ASME NIS-1 Form with Classes 1 and 2 Abstract 2-1 ASME Class 3 and Augmented Examinations Summary 3-1 Examination Summary Listings introduction to Summary Listings 4-1 I

ASME Class 1 Equipment Examinations' 5-1 Piping Examinations 6-1 l ASME Class 2 Equipment Examinations 7-1 Piping Examinations 8-1 Supports introduction and Equipment Support Examinations 9-1 Introductica and Piping Support Examinations 10-1 Snubber Functional Examinations Introduction to Snubber Functional Testing Listings 11-1 Inspection Type i 12-1 Inspection Type li 13-1

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l Inspection Type ill 14-1 Inspection Type IV 15-1 inspection Type V  ? 3-1 Inspection Type VI 17-1 3 l

' Pressure Tests 18-1 Indication Notification Forms 19-1 NIS-2 Forms 20-1 O

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LIST OF ABBREVIATIONS

<n V ACC Acceptable

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AD- Anchor / Darling AFW Auxiliary Feedwater System Al GPC Action item (followed by unique no. denoting Action item number)

ANil Authorized Nuclear Inservice inspector ASME' American Society of Mechanical Engineers ASNT American Society for Nondestructive Testing ASTM _ American Society for Testing and Materials BC Branch Connection CCSS Centrifugally Cast Stainless Steel CCW Component Cooling Water CE Combustion Engineering CH Closure Head CS Containment Spray.

CVCS Chemical and Volume Control System DC VEGP Deficiency Card (followed by unique number denoting Deficiency Card number)

DS Downstream .

ET Eddy Current Examination j EVAL Evaluation j FAC Flow-Accelerated Corrosion (may also be referred to as " erosion / corrosion")

FB Flange B)lting FNR- FAC Notification Report FW Feedwater System FSAR VEGP Final Safety Analysis Report (includes updates thereto) x GEO Geometric Indications i GPC Georgia Power Company HHSI High Head Safety injection HL Hanger Lug HX Heat Exchanger HYD Hydraulic Snubber IEN NRC Information Notice (may also be shown as "IN" followed by unique no. denoting notice number)

IND Indication INF Indication Notification Form ISI Inservice Inspection ,

IST inservice Testing ITS VEGP Improved Technical Specification ID inside Diameter IR inside Radius LB Large Bore LD Longitudinal Seam Weld Extending Downstream LD-l Longitudinal Seam Weld Downstream Inside of Elbow l LMT . Lambert, MacGill and Thomas LU Longitudinal Seam Weld Extending Upstream LU-O Longitudinal Seam Weld Upstream on Outside of Elbow MECH Mechanical Snubber MS Main Stt am System MT- Magnet: ' Particle Examination NCI Nonconformance item NDE Nondestructive Examination i O

ll

,. 3 LIST OF ABBREVIATIONS -(continued) ,

i k/ NI No Indication NRC United States Nuclear Regulatory Commission NRC-B NRC Bulletin (followed by unique no. denoting Bulletin number)

NRI No Recordable Indication NSCW Nuclear Service Cooling Water System OR Outside Radius PL Pipe Lug PM Paul-Munroe ENERTECH PR Pipe Restraint i PROF Profile l PS Pipe Support PSA Pacific Scientific PSI Preservice inspection PT Liquid Penetrant Examination RCS Reactor Coolant System RCP Reactor Coolant Pump RHR Residual Heat Removal System RI Recordable Indicstion RLW Refracted Longitudinal Wave j RL Restraint Lug j RPV Reactor Pressure Vessel l RR Relief Request (followed by unique no. denoting relief request number) l RWST Refueling Water Storage Tank I SAT Satisfactory Examination Resuits e- SB Small Bore (N ' ' ,i SCS St Southern Conipany Services Safety injection System SSI Sonics Systems International SNC Southern Nuclear Operating Company ,

SUP Supplemental Data I T&C Thickness and Contour TDAFW Turbine Driven Auxiliary Feedwater (Pump)

UNSAT Unsatisfactory Examination Results US Upstream UT Ultrasonic Examination VEGP Vogtle Electric Generating Plant (common unless followed by "-1" or "-2" to designate a specific plant unit)

VT Visual Examination W Westinghouse r\

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A INTRODUCTION b This repod documents the examhations and tests performed at Vogtle Electric Generating Plant, Unit 1 (VEGP-1) between October 20,1997 (date of last examination performed during the seventh maintenance / refueling outage,1R7) and March 25,1999 (date of last examination performed during the

. eighth maintenance / refueling outage,1R8) to meet the requirements of Article IWA-6000 of the American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel Code,Section XI,1989 Edition (Code), in addition, a summary of the following augmented examinations are included in this report:

. VEGP Technical Specification 5.5.9 - Steam Generator Tube inspections, e VEGP Technical Requirement 13.7.2 - Snubber Visual Inspections and Functional Tests, e Georgia Power Company Action item No. 85-2515 - Crack Growth in Steam Generator Girth Welds, e United States Nuclear Regulatory Commission (NRC) Bulletin 88 Thimble Tube Thinnirig in Westinghouse Reactors,

. Westinghouse Technical Bulletin NSD-TD-90 BMI Condait Guide Tube Leaks, and

. Balance of Plant Examinations for Flow-Accelerated Corrosion.

This report also addresses Code-applicable repairs and/or replacements which were documented since the last maintenance / refueling outage at VEGP-1 through the completion of the eighth maintenance / refueling outage in March 1999. The Owner's Reports for Repairs and Replacements (Form

( NIS-2) are included herein.

I O 1 V l 11

q 4 FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS As required by the Provisions of the ASME Code Rules V.

1. Owner: Georgia Power Company,241 Ralph McGill Blvd., N. E.

P. O. Box 4545, Atlanta, Georgia 30308-3374

2. Plant: Vogtle Electric Generating Plant,7821 River Road P. O. Box 1600, Waynesboro, Georgia 30830

3. Plant Unit: One

4. Owner Certification of Authorization: N/A

5. Commercial Service Date: 05/31/87

6. National Board Number for Unit: N/A

7. Components inspected:

Component or Manufacturer or Manufacturer or Installer State or ProCnce National Board Appurtenance Installer and Serial Number Number Number Address Reactor Combustion Eng. 8971 N/A 21668 Pressure Vessel Inc.,

Chattanooga, TN (V ') Steam Generators 1 Westinghouse Elec.,

Tampa, FL GAGT 1881, GAGT 1882, N/A N/A, N/A, through 4, GAGT 1883, N/A, respectively GAGT 1884 N/A Reactor Westinghouse Elec., F1088, N/A N/A, Coolant Pumps Cheswick, PA F1089 N/A, I through 4, F1090, N/A, respectively F1091 N/A Pressurizer Westinghouse Elec., 62189 N/A N/A Pensacola, FL Selected Piping, Pullman Power 1201,1202,1204,1205, N/A N/A i Components, Products, 1206,1208,1301,1302,1305 l and Supports Williamsport, PA )

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. ,m FORM NIS-1 (Back)

8. Examination Dates: October 20,1997 to March 25,1999,

9. Inspection Period Identification: First Period of Second Inspection Interval,

- 10. Inspection Interval Identification: Second Inspection Interval

11. Applicable Edition of Section XI 1989 Addenda None

12. Date/ Revision ofInspection Plan: November 30,1998 / Revision i

13. Abstract of Examinations and Tests. Include a list of examinations and tests and a statement concerning status of work required for the Inspection Plan. (See Abstract and Examination Summary Listings)

14. Abstract of Results of Examinations and Tests. (See Abstract)

15. Abstract of Corrective Measures. (See Abstract)

We certify that a) the statements made in this report are correct, b) the examinations and tests meet the inspection Plan as required by the ASME Code,Section XI, and c) corrective measures taken conform to the rules of the ASME Code,Section XI.

Certificate of Authorization No. (if applicable) N]A Expiration Date N/A {

(J At i 0 19f Signed:

'IjjT Date: Southern Nuclear Operating By: N~ [ . Of&- - -

Company. Inc. for Georgia Power Company

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Owner CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State of Georgia and employed by The liartford Steam Boiler inspection and Insurance Company of One State Street, Hartford, CT 06102 have inspected the components described in this Owner's Report during the period October 20,1997 to March 25,1999, and state that to the best of my knowledge and belief, the Owner has performed examinations and tests and taken corrective measures described in this Owner's Report in accordance with the inspection Plan and as required of the ASME Code,Section XI.

By signing this certificate neither the inspector nor his employer makes any warranty, expressed or implied, concerning the examinations, tests, and corrective measures described in this Owner's Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected itt his inspection.

i _ h[ aI E Commission: NB 9288, GA 497, I, N, A National Board, State, Province, and Endorsements Inspector's Signature [

Date: bM 19 97 G.

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ABSTRACT

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Introduction / Status The ASME Boiler and Pressure Vessel Code,Section XI,1989 Edition (Code), is the applicable code for conducting inservice inspection activities during the second ten-year inspection interval at VEGP-1.

Examinations and tests required by the Code are scheduled in accordance with " Inspection Program B" as defined in Code paragmphs IWB-2412 and IWC-2412. This " Owner's Report for Inservice Inspection" is for those first inspection period examinations and tests which were performed between October 20, 1997 (date of last examination performed during the seventh maintenance / refueling outage,1R7) and March 25,1999 (date of last examination performed during the eighth maintenance / refueling outage, 1R8).

In addition to the summary of inservice inspection activities, this report addresses Code-applicable repairs and replacements documented at VEGP-1 since 1R7 through the end of 1R8. The Owner's Reports for Repairs or Replacements (Form NIS-2) are provided herein.

It should be noted that Authorized Nuclear Inservice Inspector (ANil) inspection services were provided for those examinations and tests required by the Code. ASME Section XI examinations and tests are I

itemized in the applicable sections by reference to Examination Category. Examinations which do not meet the Code required coverage either reference request (s) for relief or indicate that additional relief is required. I Class 1 Examinations I (7 Selected Class 1 compo.1ents were examined by Southern Nuclear Operating Company (SNC) personnel j

() utilizing ultrasonic testing (UT), dye penetrant testing (PT), magnetic particle testing (MT), and visual testing (VT) methods, as applicable. Specific components and examination areas are itemized in the j

applicable portions of this document. A summary of those components examined are listed below:

. Reactor Pressure Vessel (RPV) Flange Ligaments, e RPV Closure Head and Interior Surfaces, e RPV Closure Head Nuts and Washers, j

. Pressurizer Nozzle and Safe-End Welds,

. Piping Welds, e Valve Body internal Surfaces, and

. Valve Botting. ]

During the scope of VEGP-1 examinations conducted, no Class 1 components were observed to have either reportable ultrasonic, liquid penetrant, magnetic particle or visual indications.

In addition to components already identified in current requests for relief, one piping weld had hmited )!

volumetric coverage during ultrasonic examinations because of physical limitations due to the geometric configuration of the welded areas. In order for adequate ASME Section XI Code-required examination coverage to be attained, more than ninety percent (90%) of the required volume must be examined as addressed in ASME Code Case N-460. The subject code case has been approved for use in NRC l Regulatory Guide 1.147. It is impractical to achieve the ASME Section XI Code-required coverage due to the geometric configuration of the welded area. Relief from the ASME Section XI Code requirements will be requested from the NRC for the affected weld through the relief request process as allowed by 10 CFR 50.55a, The applicable weld is indicated by " Relief Request Required"in the Class 1 weld tables. l g

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The Eddy Current (ET) examinations of steam generator tubing, as required by VEGP Technical O Specification 5.5.9, were performed by Westinghouse and are discussed in the " Class 3 and Augmented d Examinations" portion of this document.

Class 1 Pressure Test ASME Section XI, Table IWB-2500-1, Examination Category B-P requires a system leakage test (lWB-5221) each maintenance / refueling outage. This system leakage test (LT-1) was performed prior to plant startup following the refueling outage. These visual examinations revealed minor boron residue at some mechanical connections such as valve packing and isolated pipe caps. The evidence of boron residue at these mechanical connections is considered acceptable for continued system operation.

ASME Section XI, Subparagraph IWA-5242(a) requires removal of insulation from pressure-retaining bolted connections for VT-2 examination during system pressure testing for systems borated for the purposes of controlling reactivity. Relief was requested from this Code requirement and subsequently approved as documented by NRC letters dated October 24,1997 for Class 1 components and December 31,1998 for Class 2 and 3 components. The approved alternative a! lows insulation to be removed while the connections are at atmospheric or static pressures. With the insulation removed a direct visual examination is performed to detect previously occurring leakage through the presence of boric acid crystals.

The test boundary of the system leakage test includes both Class 1 and Class 2 components. The Class ,

2 components comprise part of the reactor coolant pressure boundary but ate not required to be classified l as Class 1 per 10CFR50.55a(c)(2). The frequency for removal of insulation and direct visual examination j for Class 1 pressure-retaining bolted connections is once each refueling outage (refer to Table IWB-2500-1, Examination Category B-P) and as such those activities occurred during the refueling outage.

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The frequency for removal of insulation and direct visual examination for Class 2 pressure-retaining bolted connections is once each inspection period (refer to Table IWC-2500-1, Examination Category C-H). For the first inspection period those activities occurred either before or during the 1R8 refueling outage. l Those activities performed prior to the outage were performed with the components at nominal operating l pressure. Those activities performed during the outage occurred while the components were at i atmospheric or static pressures. I Class 2 Examinations Selected Class 2 components were examined utilizing MT, PT, and UT, as applicable. Specific components and examination areas are itemized in the applicable portions of this report document. A summary of those components examined are listed below:

. Steam Generator 1 Shell Welds, During the scope of VEGP-1 manual examinations conducted, no Class 2 components were observed to have either reportable ultrasonic, liquid penetrant, or magnetic particle indications.

Class 2 Pressure Tests ASME Section XI, Table IWC-2500-1, Examination Category C-H requires system pressure testing each inspection period. The specific system pressure tests performed are itemized in the ' Pressure Tests"

[ ,\ portion of this report document. The visual examinations performed during these system pressure tests

(.) found only minor leakage at mechanicaljoints such as valve stem packing and at flanged connections.

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{, These leaks were either corrected or evaluated and determined acceptable for continued system operation.

ASME Section XI, Subparagraph IWA-5242(a) requires removal of insulation from pressure-retaining bolted connections for VT-2 examination during system pressure testing for systems borated for the purposes of controlling reactivity. Relief was requested from this Code requirement and subsequently approved as documented by NRC letters dated October 24,1997 for Class 1 components and December 31,1998 for Class 2 and 3 components. The approved alternative allows insulation to be removed while the connections are at atmospheric or static pressures. With the insulation removed a direct visual examination is performed to detect previously occurring leakage through the presence of boric acid crystals. This approved altemative was implemented on applicable pressure-retaining bolted connections that were not uninsulated and examined while at the Code required test pressure.

Class 1 and 2 Component Supports Visual examinations were performed on supports for the following Class 1 and 2 components :

• Pressurizer, e Reactor Coolant System Piping, e Nuclear Service Cooling Water System Piping,

. Safety injection System Piping, e Containment Spray System Piping, e Chemical and Volume Control System Piping, e Auxiliary Feedwater System Piping.

Visual examinations resulted in one support having unacceptable conditions. The support is as follows:

1. Pressurizer - Equipment Support H06 (11201-V6-002-H06). Bolting which was required by the current revision of the support drawing was observed as not being present during visual examination.

It was determined that the bolting was actually not required and was not considered in the beam connection qualification. The "as found" support condition was determined to be acceptable "as is",

therefore not requiring scope expansion or successive inspections. The drawing will be revised to reflect the proper condition. (Refer to INF 199V1009)

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i n CLASS 3 EXAMINATIONS Class 3 Pressure Tests ASME Section XI, Table IWD-2500-1, Examination Categories D-A, D-B, and D-C require system pressure testing each inspection period. The specific system pressure tests performed are itemized in the

" Pressure Tests" portion of this report document. The visual examinations performed during these system pressure tests found only minor leakage at mechanical joints such as valve stem packing and at flanged connections. These leaks were either conected or evaluated and determined acceptable for continued system operation.

ASME Section XI, Subparagraph IWA-5242(a) requires removal of insulation from pressure-retaining bolted connections for VT-2 examination during system pressure testing for systems borated for the purposes of controlling reactivity. Relief was requested from this Code requirement and subsequently approved as documented by NRC letters dated October 24,1997 for Class 1 components and December 31,1998 for Class 2 and 3 components. The approved alternative allows insulation to be removed while the connections are at atmospheric or static pressures. With the insulation removed a direct visual examination is performed to detect previously occurring leakage through the presence of boric acid crystals. This approved alternative was implemented on applicable pressure-retaining bolted connections that were not uninsulated and examined while at the Code required test pressure.

Class 3 Supports and Integral Attachments Visual examinations were performed on the supports and/or the integral attachments for the Class 3 components listed below:

.. Boric Acid Filter 003,

. Spent Fuel Pit Heat Exchanger 001, e Spent Fuel Pit Pump 005, e Nuclear Service Cooling Water Piping, e Component Cooling Water Piping, e Auxiliary Feedwater Piping. ,

I Visual examinations resulted in no supports having unacceptable conditions 31 l

I p AUGMENTED INSPECTIONS Technical 6pecification 5.5.9 - Steam Generator Tube inspections NOTE The following discussion on the steam generator tubing inspections, in addition to fulfilling the reporting requirements of ASME Section XI for Inservice inspection activities, constitutes the report required by VEGP Technical Specification 5.6.10.b to be submitted to the NRC within twelve (12) months following completion of the steam generator tube inspections.

Accordingly, a separate submittal is not being made to the NRC on the inspection of the steam generator tubes performed during the eighth maintenance / refueling outage (1R8) at VEGP-1.

Introduction During 1R8, the Steam Generator Maintenance Services Group of the Westinghouse Nuclear Services Division performed eddy current testing of two Westinghouse Model F steam generators in parallel from March 7,1999 through March 15,1999. One hundred percent (100%) of the tubes from two steam generators, i.e., Steam Generators 1 and 4, were inspected rather than only one steam generator as required by VEGP Technical Specification Table 5.5.9. The extent of the examinations and their results are summarized in Table I (refer to pages 3-10 through 3-13), including the location and the accumulative number of previously plugged steam generator tubes. Although Steam Generators 2 and 3 were not examined during 1R8, Table i provides information for those steam generators also.

b Tables ll (refer to pages 3-14 and 3-15) and lli (refer to pages 3-16 and 3-17) identify the steam generator tubes with indications by location and percent of wall thickness penetration for Steam Generators 1 and 4, respectively. Information is provided only for the steam generators examined during 1R8.

Applicable procedures, personnel qualifications, material and equipment certifications, sign-off sheets, and supporting data, etc., can be found in Westinghouse Electric Company Nuclear Service Division Steam Generator Maintenance Services Field Service Report, GAE-15 " Steam Generator Eddy Current inspection ", which is available at the plant site for review upon request.

Tube Inspection Plan Bobbin Inspection Plan Steam generator tube inspections conducted during 1R8 met or exceeded the recommendations made in the Electric Power Research Institute (EPRI) guidelines for steam generator tube inspections which were adopted by SNC. The VEGP inspection plan requires that 100% of the tube population be inspected from two steam generators each outage rather than twenty percent (20%) of the tube population from four steam generators each cycle or forty percent (40%) of tube population from two steam generators each cycle. This plan offers the advantage of a shorter inspection interval in order to achieve complete steam generator inspection and offers an improved sensitivity to degradation mechanisms that might be initiating within a particular steam generator. Each of the tubes examined was tested fulllength.

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p Motorized Rotating Pancake Coll (MRPC) Inspection Plan

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The inspection program outlined in the VEGP response to NRC Generic Letter 95-03, "Circumferential Cracking of Steam Generator Tubes *, was met or exceeded during 1R8. During 1R8, the MRPC inspection plan for Steam Generators 1 and 4 for top-of-tubesheet circumferential cracking exceeded the minimum requirements specified in Revision 5 of the EPRI guidelines on steam generator tubing inspection in accordance with those guidelines, approximately 50% of the tube population in each of the two steam generators were inspected. The MRPC inspections typically were conducted at the top of the tubesheet in a region approximately three inches above to three inches below the top of the tubesheet.

The Plus-Point probe was used to conduct the inspections. In addition,40% of the low row U-bends (Rows 1 and 2) were inspected. A magnetically-blased (mag-bias) Plus-Point MRPC probe was used for the low row U-bend inspections. Special-interest MRPC inspections were performed using the 0.560 inch diameter Plus-Point probe. The inspection Summary Table provided below details the number of tubes inspected.

Inspection Plan implementation To summarize the bobbin inspection plan, most tubes were inspected with a 0.560-inch diameter probe throughout their entire length including those tubes above Row 3. The remaining straight lengths were tested using a 0.560-inch diameter probe. The U-Bends below Row 3 were inspected using either a 0.540 or 0.520 inch diameter probe. The inspections were performed in accordance with MWO 19801435.

Sixteen tubes in S/G 1 were re-examined with bobbin probes after the Upper Gundle Hydraulic Cleaning Head became stuck.

The bobbin probes used in the inspection of the steam generator tubes were manufactured by Westinghouse. Bobbin examinations were performed with replacero' le probe heads mounted on WA-

\ RLLC probe conduit. All bobbin examinations of the tubes abovo Row 2 and the straight lengths of Row 1 and 2 were conducted with WA-560-RPH probes. The Row 2 U-bends were examined with WA-540 probes and the Row 1 U-bends were examined with WA-520-BJFM-RPH probes.

The MRPC inspection plan and special-interest MRPC inspection were accomplished using the Zetec Plus-Point probes (560-115+PT36S80-52PH or M/+PT-520/MRPC/FH/52PH). After the completion of the bobbin inspection program, specialinterest MRPC inspections were performed to better characterize indications in the steam generators. Disposition of tubes for which specialinterest MRPC was performed confirmed that these indications did not represent service-induced degradation.

The eddy current bobbin and MRPC inspection programs were conducted in accordance with Westinghouse procedure MRS 2.4.2 GPC-3, " Eddy Current inspection of Preservice and Inservice Heat Exchanger Tubing", using Westinghouse Acquisition Technique Specification (ACTS) sheets GAE 199, GAE-02-199, GAE-03-199, GAE-04-199, and GAE-05-199. Per ACTS GAE-01-199, the bobbin inspection plan withdrawal rate was 40 inches per second and the test frequencies were 630 kilohertz (KHz),320 KHz,160 KHz, and 10 Khz. Per ACTS GAE-03-199, the bobbin withdrawal rate was 24 inches per second for low-row bobbin tube inspections. Per ACTS GAE-02-199, the withdrawal rate for the MRPC inspection plan was 0.4 inch per second and the test frequencies were 600 KHz,300 KHz,200 KHz,100 KHz and 20 Khz. Per ACTS GAE-04199, the specifications for the low row U-bends MRPC inspections are specified. ACTS GAE-05-199 was written to facilitate the inspection of locations masked by permeability but was not needed. Each probe, along with its inspection plan, corresponding ACTS number, and the EPRI Guidelines, Appendix H qualifications, is listed on the Probe Authorization dated February 1,1999.

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1 1

- Inspection Summary Table D

J Number of Tubes per 1

Inspectlen Extent Steam Generator (S/G)

S/G 1 S/G 4 Fulllength-bobbin 5377 5371 8 7H-TEH 244 242 7C-TEC 244 242 7C-6H 147 144 Restricted tubes 0 0 MRPC-0.560 inch dia. Plus-Point 2989 3027 MRPC-0.560 inch dia. Plus-Point (Specialinterest) 41 39 Hot Leo i

MRPC-0.560 inch dia. Plus-Point (Special Interest) 14 10 Cold Leo MRPC-Mag-biased Plus-Point (Row 1 and 2 98 98 U-bends)

SpecialInterest Bobbin 16 0 The above extents meet or exceed the original test program. In some cases, either the required minimum extent was exceeded or additional tubes were tested.

Data Evaluation Data collection was performed by Westinghouse using the SM-22 and MlZ 30A tester. Data was sent from the site via a T-1 line in the Eddynet format to the Westinghouse Waltz Mill, Pennsylvania facility and

,\ transferred to the other offsite facilities. Westinghouse and its subcontractors performed the primary analysis of the eddy current data. Framatome performed the secondary analysis of the eddy current data.

Resolutions were performed jointly by Westinghouse and Framatome at the Waltz Mill facility. All analysis was performed using Zetec Eddynet Software. SNC site-specific Data Analysis Guidelines and procedure MRS 2.4.2 GPC-37, Revision 3, " Steam Generator Eddy Current Data Analysis Techniques for Vogtle Units 1 and 2", were used to perform the analysis.

Analysts were required to complete a training session and then be tested on their performance. The analyst training meets the requirements of the EPRI guidelines which included training tapes, test tapes, and a training manual for SNC. Analysts are required to pass the testing prior to analyzing any new data.

Prior to the start of data acquisition a complete history review was performed of all baseline data for Unit 1 to minimize the impact history lookups would have on the analysis schedule, in an effort to minimize cost, the primary analysis was performed off site by Westinghouse. Secondary analysis was performed at the Framatome facility in Benecia, California. The performance of analysis at l the remote sites eliminated the expenses associated with relocating the analysts to the site. Remote analysis was accomplished using data transmission lines (T-1 lines) to communicate between the plant  !

i site and the remote locations. Data management was performed off-site with reports being generated on-site via the T-1 lines. Resolution analysts for Westinghouse and Framatome were located at the Waltz Mill site. A SNC Level 111 (ET) was located at the Waltz Mill site to facilitate the resolution of eddy current data and performed the duties of the independent qualified data analyst (ODA). In addition, SNC ODA and contract ODA perfomied random samples of test data to ensure the EPRI requirements were being followed.

- The bobbin /MRPC inspections conducted during 1R8 identified no pluggable indications in Steam

/\ Generators 1 and 4. The following table summarizes the indications found.

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c g . Indication Summary Table

V Indication Size Number of Tubes per Steam Generator (S/G)

S/G 1 S/G 4 40% ard greater wall 0 0 thickness penetration 30-39% wall thickness 7 6 i penetration 20-29% wall thickness 7 22 penetration Less than 20% wall 28 50 thickness penetution Possible loose Part Wear 5 0 Manufacturing Buff Marks (totaltubes) 457 719 Dent or Ding (total tubes) 243 332 It should be noted that the above table is based on the largest inaication per tube.

More details regarding indication distributions can be found in the maps, which follow the steam generator tubing inspection discussion.

Degradation Assessment Prior to maintenance / refueling outage 1R8, VEGP performed a degradation assessment as required by A the provisions of Nuclear Energy Institute (NEl) guideline NEl 97-06 and Revision 5 of the EPRI Q guidelines for steam generator tube inspection. The purpose of the degradation assessment was to ensure that the appropriate nondestructive examination (NDE) techniques and personnel were to be used during eddy current testing at VEGP, The degradation assessment provides assurances that the NDE techniques used are appropriate for detection and measurement performance to support growth rates,  ;

repair criteria, and structural limits for the degradation mechanisms.

Degradation mechanisms were grouped into categories according to their likelihood of occurrence. The  ;

categories include: active mechanisms for degradation previously found in the VEGP steam generators, relevant mechanisms for degradation found in similar plants with the same tubing material and similar design features, and potential mechanisms for degradation not found in similar plants but not judged to have a meaningful potential to occur based on historical or laboratory data. Other degradation mechanisms judged to be non-relevant for Westinghouse Model F steam generators were addressed in the assessment. A subgroup included in the assessment identified the process applied to resolve potential indication signals in order to classify the signals for disposition relative to leaving the tube inservice or repairing the indications.

The only observed degradation mechanism at VEGP is anti-vibration bar (AVB) wear. As defined by the EPRI guidelines, the AVB wear observed at VEGD is not considered as an active damage mechanism.

The VEGP inspection plan specifies that 100% of the tubes contacted by the AVBs are to be inspected using the bobbin probe. The VEGP inspection plan is more conservative than the EPRI guidelines.

Potential degradation mechanisms included in the assessment are Outside Diameter Stress Corrosion Cracking (ODSCC) and Primary Water Stress Corrosion Cracking (PWSCC) which have been detected in

thermally treated tubing in European plants. The VEGP inspection plan includes MRPC inspections at the i top of tubesheet expansion region and at the small radius U-bends for detection of stress corrosion cracking (SCC). The assessment also concluded that the likelihood of initiation of both ODSCC and O PWSCC at either the top of tubesheet expansion region and the small radius U-bends is considered low V for VEGP.

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l I Nnn-relevant degradation mechanisms include those degradation mechanisms observed in other steam V

generators with differing materials of construction and manufacturing practices. In general, these j mechanisms are associated with drilled-hole carbon steel tube support plates (TSP). The VEGP TSPs '

are broached, quatrefoil tube holes and stainless steel TSPs. The likelihood of initiation of these  ;

degradation mechanisms at VEGP is considered remote.

For each degradation mechanism identified, the assessment specified the probe (s) to be used during j inspection, the detection qua3fication including techniques sheet and estimated probability of detection 1 (POD) information, the inspection sample plan, and the basis for expanding the inspection, if required. l The degradation assessment also included information supporting the sizing qualification (when sizing is l applied) including technique sheet and uncertainty data.

{

Condition Monitoring There were no steam generator tubes identified during 1R8 that challenged the structural integrity recommendations of NRC Regulatory Guide 1.121. Furthermore, there were no tubes that required plugging, nor was in-situ leakage and pressure testing required, since none of the indications exceeded the Technical Specifications repair criteria. The only tube degradation mechanisms observed at VEGP-1 ,

during 1R8 were tube mechanical wear at anti-vibration bar (AVB) intersections and possible loose parts j wear observed at or near the top of the tubesheet. The AVB wear observed during 1RS was consistent with the historical performance and structural expectations as projected in the degradation assessment report. No tubes were found to have experienced excessive AVB wear. Based upon the results of the Wear Projection Technology none of the tubes with AVB wear indication had degradation sufficient to project a need for tube stabilization during the foreseeable operating life of the plant. The VEGP-1 pre-outage degradation assessment identified a structural limit of twenty-four (24%) (remaining wall thickness)

Q for AVB wear which satisfies the requirements of NRC Regulatory Guide 1.121. The following table V represents a summary of the eddy current results obtained upon final disposition. Only AVB percent wear indications are representative of a tube degradation in the VEGP steam generators.

1R8 Indications / Signals SIG 1 S/G 4 AVB % Wear Indications 78 146 Possible Loose Parts Wear 5 0 Benign freespan Signals 183 131 Freespan dings 286 228 Dents (TSP, baffle, TS) 230 443 Manufacturing buff marks 577 1044 VOGTLE 1R8 AVB WEAR INDICATION

SUMMARY

S/G # IND # 2 40 % Max. % Depth 2 cycle 95% A 1 78 0 38 6.5 %

4 146 0 36 11.4 %

Degradation Mechanisms As defined in the degradation assessment, indications were categorized as observed, relevant, and non-relevant based upon their likelihood of occurrence. The AVB indications observed during 1R8 were consistent with expectations. For the seventy-eight (78) indications reported in Steam Generator 1 and one hundred forty-six (146) indications reported in Steam Generator 4 that could be evaluated as to

[3 growth rate, based on actual comparisons of measured values, SG-1 and SG 4 exhibit 2-cycle (1R8-1R6)

Q average growth rates of 2.0% and 6.8% respectively. The corresponding 95% cumulative distribution 3-6

values for the 2-cycle growth rates are 6.5% and 11.4% respectively. The maximum indication depths G were thirty-eight percent (38%) and thirty-six percent (36%) in Steam Generators 1 and 4, respectively.

U The data for S/G 1 suggest the influence of loose parts wear obtained in three areas. Possible loose part indications were reported in S/G 1 in the vicinity of R22C21, R22C22, R22C23, R36C87, and R36C68. No indication of wear was reported at these locations during prior inspections. At the upper edge of the hot leg baffle plate at tube R58C70, a shallow bobbin indication (22%) was found by the bobbin probe. This indication was characterized as a volumetric indication associated with wear from a loose part by plus-point examination. Four tubes (R1C100,101,102, and 103) were identified as exhibiting small (maximum 0.36 volts) OD volumetric plus-point indications at or just above the top of tube sheet (TTS). Due to the alignment of these indications, the local wear alignment suggests wear from the interaction with a thin linear object, such as a weld rod. Review of historical data and resolution of the indications resulted in nc indication exceeding the Technical Specification plugging limit nor did the indications challenge the structuralintegrity of the tubes.

There were no indications of OD pitting or transition zone stress corrosion cracking detected. These l

degradation modes, though not observed at VEGP-1, have been observed in plants with similar design or l tubing configuration. I U-bend PWSCC, ODSCC related to the presence of frecspan ding or support plate level dents, and sludge pile ODSCC are degradation mechanisms that have not been observed in similar S/Gs but are considered on a contingency basis should such indications be detected. There were no indications attributable to any of these mechanisms at VEGP-1 during 1R8. The likelihood of occurrence of these indications have the lowest probability of occurrence in the Westinghouse Model F design steam generators.

Indications reported with flaw-like characteristics in the VEGP-1 steam generators include manufacturing i h

V burnish marks and benign indications. The signals associated with these categories do not represent in-service degradation. The locations of these signals were carefully monitored for change from baseline or l'

initial condition. Approximately 83 locations were re-examined with the plus-point rotating probe because of questions concerning the nature of the signals. All these locations were confirmed to exhibit 4 characteristics that were not indicative of tube degradation. j l

Twenty percent of the straight tube section dents (25 volts) in both S/G 1 and 4 were examined with plus-point probes. All of the locations tested in both S/Gs were reported as NDD. The dings and dents in Model F S/Gs do not result from TSP corrosion, because the 405 stainless plate quatrefoil tube hole design is unlikely to support in-service denting.

AVB Wear Projection Technology-based Assessment The AVB wear data has been reviewed and evaluations based on Wear Projection performed. There were no concerns identified which required stabilization based upon the 1R8 inspection data. The worst )

case observed has a positive margin of approximately 55 years from 1R8 relative to that site's wear level i reaching the stabilization criterion. Based upon Wear Projection Technology, there was no wear site data in either S/G 1 or 4 that required stabilization during 1R8.

Operational Assessment i

The tube degradatione identified during the 1R8 steam generator tube inspections were evaluated as i required to satisfy the Operational Assessment at the End-of-Cycle 8 (EOC-8) after approximately 949  ;

Effective Full Power Days (EFPDs). The most severe cases of tube degradation satisfied the structural margin requirements of NRC Regulatory Guide 1.121. No tubes were repaired during 1R8. In-situ leakage and pressure testing were not performed since none of the indications of tube degradation U exceeded the Technical Specification repair criteria. The basis for the forward-looking Operational 3-7

p i

[

l g)

(~ Assessment was a combination of as-found data and growth rate information. AVB wear degradation mechanism encountered during 1R8. The Operational Assessment demonstrated th structural margin required will be maintained during the upcoming operation intervals until the next scheduled inspection of S/G 1 and 4, at EOC-10, and that there will not be excessive leakage e normal or under accident conditions. Similarly, the historical growth data, as well as, the growth data Steam Generators 1 and 4 from the EOC-8 indicate that structural and leakage integrity will be ma in Steam Generators 2 and 3 until their scheduled inspections at the End-of-Cycle 9 (EOC-9).

Analysis of the S/G 1 and 4 eddy current data from 1R6 (both S/Gs) and 1R7 (S/G 4 only) was for locations with wear indications not previously reported and combined with indications pre observed to develop the AVB wear progression. After re-analysis the largest indication without outage counterpart was 22% in S/G 1. The total growth rate between inspections 1R4,1R6, and 1R determined as a 95% cumulative distribution allowance on the basis of prior cycles was found to be 1 percent for 1000 EFPD. This was documented in the Degradation Assessment Report and represent growth over the total operational period of two cycles. As adjusted for the 949 EFPD between 1R6 and 1R8, the observed should be less than 15.8%.

Evaluation of the 1R6 and 1R8 progression for AVB wearindications obtained from comparative (historical) analyses performed at VEGP-1 of corresponding wear indications yielded 2.0 perce throughwall growth for S/G 1 and 6.8 percent growth for S/G 4. A separate single cycle comparison of S/G 4 data for 1R7 to 1R8 was also performed. The result was a 2.8 percent growth rate for cycle when converted to a 2-cycle interval gives 5.4 percent. Assuming the AVB growth distribution from 1R6 to 1R8 is normal, the 95% growth allowance from 1R6 to 1R8 is 6.5 % for S/G 1 and 11.4% for S/G 4.

The 95% growth allowance assuming a normal growth distribution is 12.3 for both S/Gs, based on the combined population. Adjusted for the 978 EFPD projected operating interval until EOC-10, the gro;I rate allowance of 12.5% is calculated.

(q /

Based on the worst case, using both steam generator population growth rate, combining the largest indication left in service (38%) with the bobbin technique measurement uncertainty at 95% confidence (14.6) and the 2 cycle maximum growth allowance at 95% confidence (15.8) predicts a maximum indication of 68.4 % at EOC-10. This result is less than the 76% throughwall degradation depth structur limit. The growth rates determined from comparative analysis of AVB wear sites from 1R6 and 1R8 were not large enough to present a likelihood, that conditions exceeding the NRC Regulatory Guide 1.121 structurallimit would occur before the end of cycle 10 for S/Gs 1 and 4. In addition, operation of Steam Generators 2 and 3 until maintenance / refueling outage 1R9 is acceptable.

Visualinspeetion A visualinspection of the tubesheet was performed of plugged tube ends to identify signs of leakage.

There were no signs of visible leakage from plugged tubes.

Mechanical Plugging As noted above, there were no pluggable indications identified during 1R8 as a result of eddy current testing.

I By letter LCV-1336 dated March 29,1999, SNC notified the NRC pursuant to VEGP Technical Specification 5.6.10 and reported that no steam generator tubes were plugged during 1R8.

l l

n >

3-8

Maps I

1,. Steam Generator 1 - Bobbin Inspection Plan - Cold Leg (page 3-18)

2. Steam Generator 1 - Bobbin Inspection Plan - Hot Leg (page 3-19)

3. Steam Generator 1 - MRPC Inspection Plan- Hot Leg (page 3-20)

4. Steam Generator 1 - LowRow Bobbin (540 & 520) Inspection Plan (page 3-21)

5. Steam Generator 1 - LowRow MRPC Inspection Plan (page 3-22)

6. Steam Generator 1 - Bobbin Test Extents (Actual) (pages 3-23 through 3-25)

7. Steam Genera'.or 4 - Bobbin Test Program - Cold Leg (page 3-26)

8. Steam Generator 4 - Bobbin Test Program - Hot Leg (page 3-27)

9. Steam Generator 4 - MRPC Inspection Plan- Hot Leg (page 3-28)

10. Steam Generator 4 - Low Row Bobbin (540 & 520) Inspection Plan (page 3-29)

11. Steam Generator 4 - Low Row MRPC inspection Plan (page 3-30) i

12. Steam Generator 4 - Bob'>in Test Extents (Actual) (pages 3-31 through 3-33)

O 4

t l

l - '

3-9

.. =

1

O TABLEI V

Steam Generator 1 Total No. of Tubes: 5,6l16 No. of Tubes inspected: 5,021 No. of Tubes Degraded: 14 No. of Tubes Defective: 0 No. of Tubes Plugged Prior to Outage 1R8: 5 No. of Tubes Plugged during Outage 1R8: 0 Total No. of Tubes 5 (Row 28, Column 37; Row 45, Column 22; Row 47, Column 24; Row Plugged: 54, Column 35; Row 55, Column 55.)

O O

3-10

(

l l

TABLE I(continued)

L l Steam Generator 2

. Total No. of Tubes:' 5,626 ~

No. of Tubes inspected: N/A No. of Tubes Degraded: N/A No. of Tubes Defective: N/A l No. of Tubes Plugged i Prior to Outage 1R8: 11 No. of Tubes Plugged during Outage 1R8: 0

Total No. of Tubes 11(Plugged tubes located at Row 40, Column 106; Row 43, Column 90; P!ugged

Row 43, Column 102; Row 50, Column 95; Row 52, Column 86; Row 53, Column 90; Row 54, Column 87, Row 54, Column 88; Row 42, Column 102; Row 44, Column 102; Rcw 50, Column 94.)

O l

l 3 11 l

I l

TABLE I(continued)

Steam Generator 3 Total No. of Tubes: 5,626 No. of Tubes Inspected: N/A No. of Tubes Degraded: N/A-No. of Tubes Defective: N/A No. of Tubes Plugged Prior to Outage 1R8: 17 No. of Tubes Plugged l during Outage 1R8: 0 Total No. of Tubes 17 (Row 3, Column 33; Row 23, Column 108; Row 40, Column 17; Row 45, Plugged: Column 58; Row 47, Column 98; Row 48, Co;umn 97; Row 50, Column 28; Row 50, Column 94; Row 53, Column 88; Row 55, Column 82; Row 55, Column 83; Row 32, Column 112; Row 36, Column 110; Row 45, Column

' 59; Row 45, Column 99; Row 47, Column 99; and Row 49, Column 94.)

l O.

i O

3-12 I

I

TABLE I(continued)

Steam Generator 4 Total No. of Tubes: 5,626 No. of Tubes inspected: 5,613 No. of Tubes Degraded: 28 No. of Tubes Defective: 0 No. of Tubes Plugged Prior to Outage 1R8: 13 l

l No. of Tubes Plugged i during Outage 1R8: 0 Total No. of Tubes 13 (Plugged tubes located at Row 2, Column 23; Row 32, Column 67; Row Plugged: 32, Column 77; Row 32, Column 82; Row 43, Column 102; Row 44, Column

! 102; Row 50, Column 40; Row 1, Column 31; Row 4, Column 3; Row 4, Column 4; Row 37, Column 108; Row 42, Column 102; Row 49, Column 53.)

lO l

O 3-13

]

TABLE il Steam Generator 1 Row Column Reference Distance from Wall Thickness Plugged Poirt (Note 1) Ref. (in.) Penetration (%) (Y/N)

(Note 2) 38 16 AV4 0.00 34 N 43 21 AV5 0.00 29 N 44 21 AV5 0.00 15 N 50 29 AV2 0.00 12 N 45 30 AV3 0.11 13 N 52 33 AV2 0.00 21 N 40 34 AV4 0.00 17 N 54 37 Av1 0.00 13 N 52 39 Av3 0.00 32 N 42 43 AV4 0.00 13 N 41 44 AV3 0.00 32 N 52 44 AV4 0.00 28 N 57 44 AV5 0.00 38 N 57 45 AV3 0.00 32 N 40 47 AV4 0.00 31 N 39 48 AV3 0.00 23 N 54 53 AV2 0.00 11 N

^

40 62 AV5 0.00 13 N

(\

59 62 AV6 .35 11 N 58 76 AV6 0.00 10 N 37 77 AV3 0.00 19 N l 44 80 AV4 0.00 09 ,

N )

43 81 AV4 0.00 12 N 43 82 AV3 0.00 12 N 43 83 AV4 0.00 22 N 54 8? AV1 0.00 08 N 43 85 AV2 0.00 15 N 39 90 AV3 0.00 12 N 45 90 AV2 0.00 14 N 53 90 AV6 0.00 13 N 43 91 AV2 .22 33 N 52 91 AV1 0.03 09 N 50 95 AV1 0.00 10 N 47 99 AV2 0.00 09 N 27 100 AV5 .06 07 N 37 102 AV5 0.00 16 N 35 104 AV3 0.00 08 N 39 104 AV4 0.00 13 N 42 104 AV6 0.22 08 N 36 105 AV3 0.00 12 N 28 115 AV6 0.00 29 N A 26 116 AV6 0.00 22 fJ 3-14

- - . . ~

T ]

a t-TABLE 11(continued)

The above information is based on the largest indication observed for the respective tube during the sixth maintenance / refueling outage at VEGP-1.

- Note 1: Reference Point Location Description TSH, TSC - Top of Tubesheet Hot and Cold  ;

BPH, BPC - Baffle Plate Hot and Cold l #H, #C -(# = Number) of Support Plate Hot and Cold, e.g.,2H,2C l AV1; AV2, AV3, AV4, AV5, AV6 - Anti-vibration Bars i

l Note 2: Unless indicated otherwise, distance is above Reference Point. A negative number, e.g.,

l -2.00, indicates that the distance is below the Reference Point.

l l

l l

s 1

3-15

F I

l i

(% TABLE Ill O Steam Generator 4 Row Column Reference Distance from Wall Thickness Plugged Point (Note 1) Ref. (in.) Penetration (%) (Y/N)

(Note 2) 27 8 AV6 0.00 23 N 27 9 AV5 0.00 26 N 33 12 AV2 0.00 13 N 36 13 AV2 0.00 11 N 36 14 AV1 0.00 10 N 30 20 AV2 0.00 10 N 41 23 AV2 0.00 13 N 32 25 AV4 0.00 11 N 40 29 AV2 0.00 12 N 33 34 AV5 0.00 13 N 54 36 AV5 0.00 12 N 54 38 AV1 .20 13 N 36 39 AV3 0.00 22 N 40 39 AV3 0.00 14 N 28 40 AV5 0.00 26 N 30 40 AV5 0.00 19 N 55 40 AV6 0.00 14 N f

5 43 46 AV6 0.00 20 N

! 27 51 AV2 0.00 13 N 39 51 AV4 0.00 19 N 38 52 AV4 0.00 13 N 49 54 AV3 0.00 24 N 39 56 AV3 0 00 19 N 39 58 AV4 0.00 17 N 39 62 AV4 0.00 10 N 40 62 AV3 0.00 35 N 50 63 AV3 0.00 25 N 28 65 AV5 0.00 13 N 43 66 AV3 0.00 19 N 58 73 AV6 0.00 11 N 38 74 AV2 0.00 ._

10 N 39 75 AV5 0.20 18 N 38 76 AV4 0.00 23 N I 50 76 AV5 0.00 28 N 40 78 AV2 0.09 20 N 36 79 AV4 0.00 19 N 56 81 AV6 0.00 14 N 28 82 AV5 0.00 12 N 40 82 AV4 0.00 29 N 55 82 AV5 0.14 16 N 40 84 AV2 0.00 15 N 38 86 AV4 0.00 18 N

(~s)

l. 40 86 AV4 0.00 16 N 3-16 )

l

t I

-( TABLE lli(continued)

Steam Generator 4 l

Row Column Reference Distance from Wall Thickness Plugged

]

Point (Note 1) Ref. (in.) Penetration (%) (Y/N) {

(Note 2) 40 87 l

AV5 0.00 23 N 40 88 AV4 0.00 j

28 N  ;

40 90 AV4 0.00 13 N 40 92 AVS 0.06 16 N 43 92 AV3 0.08 16 N 40 93 AV5 0.08 14 N 40 95 AV4 0.00 30 N 49 95 AV3 0.00 14 N 38 96 AV2 0.00 12 N 44 96 AV4 0.00 30 N 41 97 AV5 0.00 16 N 44 97 AV5 0.00 29 N 48 97 AV6 0.00 09 N 40 100 AV2 0.00 11 N 42 100 AV2 0.00 22 N 42 101 AV4 0.00 25 N 43 101 AVS 0.00 32 N Oj 45 101 AV5 0.00 19 N D 38 103 AV4 0.00 09 N l 36 104 AV2 0.00 20 N I 38 104 AV4 0.00 26 N 42 104 AV3 0.00 23 N 36 105 AV5 0.00 16 N l 40 105 AV4 0.00 16 N 32 106 AV3 0.38 10 N 40 106 AV4 0.00 15 N 38 107 AV5 0.00 36 N 33 108 AV3 0.00 14 N 36 109 AV3 0.00 17 N 32 110 AV3 0.00 17 N 33 110 AV3 0.00 24 N 32 111 AV3 0.03 18 N 33 111 AV4 0.00 24 N 30 114 AV5 0.00 30 N The above information is based on the largest indication observed for the respective tube during the eighth maintenance / refueling outage at VEGP-1.

(1) See Note 1, page 3-15.

(2) See Note 2, page 3-15.

3-17

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% VEGP Technical Requirements Manual - TR 13.7.2 Snubbers I

V VisualInspections VEGP Technical Requirements Manual (TRM) Technical Requirement (TR) 13.7.2, Technical Requirement Surveillance (TRS) 13.7.2.1 requires each snubber to be visually examined. During the VEGP-1 sixth maintenance / refueling outage (1R6), two (2) snubber visual examination results were considered unsatisfactory as a result of a visual examination of one hundred percent (100%) of the  ;

snubber population subject to VEGP Technical Requirement (TR) 13.7.2 (435 snubbers). Subsequent to 1R6, the snubber population was reduced by three snubbers to 432. Based upon Tables 13.7.2-1 and  ;

13.7.2-2, Note 3 in the VEGP TRM, the next inspection interval may be twice the previous interval, i.e.,36 months vs.18 months, but not exceed 48 months. Therefore, a visual examination of snubbers was not required during the seventh VEGP-1 maintenance / refueling outage (1R7). The next TRM Visual Examination was performed during the eighth maintenance / refueling outage (1R8) at VEGP-1 per TR 13.7.2, Table 13.7.2-2, Note 3. Three (3) snubbers (1-1201-239-H001,1-1208-009-H003,1-1901-221- l H030) which were visually inspected were initially found to have unsatisfactory conditions; however, after engineering evaluations were complete, these conditions were deemed not to affect the operability of the snubber, The visualinspections also revealed nineteen (19) degraded conditions such as rusted spherical bearings. These conditions were also evaluated and determined not to adversely affect operability; however, appropriate corrective actions were taken to correct the degraded conditions.

The next TRM Visual Examination shall be during the tenth maintenance / refueling outage (1R10) at I VEGP-1 per TR 13.7.2, Table 13.7.2-2, Note 3. All of the snubber visualinspections were performed during the 1R8 maintenance / refueling outage; therefore, all 432 snubbers are considered the ' Population or Category" per Table 13.7.2-2. The total number of unsatisfactory snubber visual inspections for this inspection was 0. From Table 13.7.2-2, for a snubber population of 400 (using 400 instead of interpolating

] per Note 2 of the subject TRM table for an actual population of 432 is conservative, per Note 3),0 is less than the allowed 8 snubber visual failures allowed by the table. Therefore, the next interval may be twice l

, the previous interval but not greater than 48 months (the previous interval was 36 months). Visual inspections performed during 1R10 will provide an interval of approximately 36 months, which will not exceed the 48 month maximum allowed by the plant Technical Requirements Manual.

Functional Testing VEGP TR 13.7.2, TRS 13.7.2.3 also requires functional testing of snubbers. The snubbers were categorized into six types as follows:

Type 1 -

Pacific-Scientific mechanical snubbers (Models PSA-1/4 and PSA- 1/2),

Type 11 -

Pacific-Scientific mechanical snubbers (Models PSA-1, PSA-3, and PSA-10),

Type 111 -

Pacific-Scientific mechanical snubbers (Model PSA-35 and PSA-100),

Type IV - Anchor / Darling mechanical snubbers (Model series AD-40 through AD-500),

Type V - Anchor / Darling mechanical snubbers (Model series AD-1600 through AD-12500), and Type VI - Paul-Munroe ENERTECH 1000 kip steam generator hydraulic snubbers.

Each snubber type was functionally tested utilizing a test plan (as detailed in VEGP TRS 13.7.2.3 in accordance with Table 13.7.2-4) which requires that an initial representative random sample of ten 3-34

f. percent (10%) of the population to be functionally tested. The result of the functional testing of the

{ snubber types is as follows:

A TypeI -

Five (5) snubbers were included in the initial representative random sample to be functionally tested for the Type I snubbers. One (1) additional snubber from the same location as a snubber that failed the previous 1R7 functional test was tested. The six Type I snubbers were functionally tested and each met the functional test acceptance i criteria with the exception of one original scope snubber from the initial scope. In '

accordance with the requirements of VEGP TR 13.7.2, Table 13.7.2-4, paragraph 1.a, the functional test scope was increased. Subsequent testing of seven (five at random {

and two Type IV due to location) additional snubbers resulted in no failures. An appropriate engineering evaluation as required by VEGP TR 13.7.2, Table 13.7.2-4, {

paragraph 4, and subsequent corrective action was performed for the Type I snubber ,

which failed functional testing. In accordance with VEGP TR 13.7.2, Table 13.7.2-4, )

paragraph 2, the Type I snubber at tb same location as the snubber that failed to l meet the functional test acceptance criteria during the 1R8 outage will be retested j during the ninth VEGP-1 maintenance / refueling outage (1R9). To summarize, a total 1 of eleven (11) Type I snubbers were functionally tested with each meeting the j

' functional test acceptance criteria except as noted above. No additional functional  !

testing of Type i snubbers was performed. j Type II -

i4ine (9) snubbers were included in the initial representative random sample to be functionally tested for the Type ll snubbers. The nine snubbers were functionally i tested and each met the functional test acceptance criteria with the exception of one

]

original scope snubber from the initial scope. In accordance with the requirements of VEGP TR 13.7.2, Table 13.7.2-4, paragraph 1.a, the functional test scope was

.A increased. Subsequent testing of twelve (nine at random and three Type 11 due to

(] location) additional snubbers resulted in one failure. This failure did not require an expansion of scope because it was picked due to location. Another Type ll snubber was tested during 1R8 due to a deficient condition. It was found being used to hold a ladder upright. It passed the functional test. During Type IV functional testing, three additional Type 11 snubbers were functionally tested due to location and resulted in no failures. Appropriate engineering evaluations as required by VEGP TR 13.7.2, Table 13.7.2-4, paragraph 4, and subsequent corrective action were performed for the Type il snubbers which failed functional testing. In accordance with VEGP TR 13.7.2, Table 13.7.2-4, paragraph 2, the Type 11 snubber at the same location as the snubber that failed to meet the functional test acceptance criteria during the 1R8 outage will be retested during the ninth VEGP-1 maintenance /refuehng outage (1R9). To summarize, a total of twenty-five (25) Type il snubbers were functionally tested with each meeting the functional test acceptance criteria except as noted above. No additional functional testing of Type 11 snubbers was performed.

t .

! Type lil -

Six (6) snubbers were included in the initial representative random sample to be I l functionally tested for the Type 111 snubbers. The six Type 111 snub 5ers were functionally tested and each met the functional test acceptance criteria with the exception of one original scope snubber from the initial scope. In accordance with the j requirements of VEGP TR 13.7.2, Table 13.7.2-4, paragraph 1.a, the functional test scope was increased. Subsequent testing of eight (six at random, one Type V due to location, and one Type ill due to location) additional snubbers resulted in no failures. l An appropriate engineering evaluation as required by VEGP TR 13.7.2, Table 13.7.2-4, paragraph 4, and subsequent corrective action was performed for the Type lli snubber which failed functional testing. In accordance with VEGP TR 13.7.2, Table  :

O 13.7.2-4, paragraph 2, the Type lll snubber at the same location as the snubber that (d failed to meet the functional test acceptance criteria during the 1R8 outage will be i

l 3-35 i

j

m retested during the ninth VEGP-1 maintenance / refueling outage (1R9). To tj\ summarize, a total of thirteen (13) Type ll1 snubbers were functionally tested with each meeting the functional test acceptance criteria except as noted above. No additional functional testing of Type lli snubbers was performed.

Type IV -

Sixteen (16) snubbers were included in the initial representative random sample to be functionally tested for the Type IV snubbers. Two (2) additional snubbers from the same locations as snubbers that failed the previous 1R7 functional test were tested.

The eighteen Type IV snubbers were functionally tested and each met the functional test acceptance criteria with the exception of one original scope snubber from the initial scope. In accordance with the requirements of VEGP TR 13.7.2, Table 13.7.2-4, paragraph 1.a. the functional test scope was increased. Subsequent testing of twenty (sixteen at random, three Type li due to location, and one Type IV due to location) additional snubbers resulted in no failures. In addition, two Type IV snubbers were functionally tested due to location during Type I functional testing and resulted in no failures. An appropriate engineering evaluation as required by VEGP TR 13.7.2, Table 13.7.2-4, paragraph 4, and subsequent corrective action was performed for the Type IV snubber which failed functional testing. In accordance with VEGP TR 13.7.2, Table 13.7.2-4, paragraph 2, the snubber at the same location as the snubber that failed to meet the functional test acceptance criteria during the 1 R8 outage will be retested during the ninth VEGP-1 maintenance / refueling outage (1R9). To summarize, a total of thirty-seven (37) Type IV snubbers were functionally tested with each meeting the functional test acceptance criteria except as noted above. No additional functional testing of Type IV snubbers was performed.

Type V -

Eight (8) snubbers were included in the initial representative random sample to be

/7

.() functionally tested for the Type V snubbers. Two (2) additional snubbers from the same locations as snubbers that failed the previous 1R7 functional test were tested.

In addition, one Type V snubber was functionally tested due to location during Type ill functional testing and passed. The eleven Type V snubbers were functionally tested and each met the functional test acceptance criteria. No additional functional testing of Type V snubbers was performed.

Type VI -

One (1) snubber was included in the initial representative random sample to be functionally tested for Type VI snubbers. The one (1) Type VI snubber was functionally tested and met the functional test acceptance criteria. Therefore, no additional functional testing of Type Vi snubbers was performed.

The specific Types I through VI snubbers that were functionally tested in response to VEGP TR 13.7.2 are itemized in the Snubber Functional Testing Listings of this report document.

In accordance with VEGP TR 13.7.2, Table 13.7.2-4, paragraph 4, engineering evaluations were performed by Southern Company Services (SCS) for the one (1) Type I snuuber, the two (2) Type Il rnbbers, the one (1) Type 111 snubber, and the one (1) Type IV snubber which failed functional testing.

I he engineering evaluations were performed in order to determine the cause(s) of the failures and to determine if the piping systems to which the failed snubbers were attached were adversely affected. The affected piping systems to which the failed snubbers were attached were returned to their approved design configuration by replacing the failed snubbers with known operable snubbers. The following is a listing of snubbers and the correspondence associated with the engineering evaluations that are available at the plant site for review upon request:

O

! I V

3-36

I n AffectedSnubber(s) Applicable SC" (j Applicable Deficiency Evaluation Letter /Date Card Number 11305-119-H007 SG-16794, 03/03/99 119990155 1130153-H027B SG-16795, 03/03/99 119990168 11305-120-H003 SG-16811, 03/05/99 119990188 11208-002-H030 SG-16816, 03/08/99 119990201 11208-002-H035 SG-16816, 03/08/99 119990204 It should be noted that one (1) snubber,11202-140-H009, was deleted during 1R8 and four (4) sn 11202-231-H603,11202-140-H001,11202-225-H015, and 11202-212-H014, were deleted and rep by rigid struts during 1R8 per Design Change Package (DCP) 97-V1N0015. The ISI Plan document wil be revised to reflect these changes. The population of Unit 1 snubbers will change from 432 snubbers 427 snubbers for 1R9.

NRC Bulletin 88 Thimble Tube Thinning in Westinghouse Reactors in response to NRC concerns of thinning in Bottom-Mounted instrumentation (BMI) flux thimbles in Westinghouse reactors, eddy current examination of the fifty-eight (58) flux thimbles was performed of flux thimble F-14 (previously capped and then re-capped after ex examinations was to detect a% size indications of possible wear on the outer diameter of the flux thimbles. The examination o ' a flux thimbles was performed by Westinghouse in accordance with their procedure MP 2.3.1 GAE/GBE-2," Thimble T4e Eddy Current inspection at Vogtle Units 1 and 2".

I,\ An evaluat!on was performed by Westinghouse using WCAP-12688, " Bottom Mounted instrumentation Flux Thimble Wear", on BMI flux thimbles which were found to have indications of wear after the fuel cycle. VEGP-1 has forty-six (46) flux thimbles with some indication of wall loss. Wear rate projections through the end of the ninth and tenth fuel cycle indicate that all of the forty-six flux thimbles will remain below the eighty percent (80%) maximum wall loss acceptance criteria established in Westinghouse WCAP-12688. Therefore, it was concluded no corrective actions were required d eighth maintenance / refueling outage et VEGP-1.

The evaluation was transmitted to the plant site in the Westinghouse outage report for Flux Th Current Testing and is available at the plant site for review upon request.

Westinghcuse Technical Bulletin NSD-TD-90 BMI Conduit Guide Tube Leaks in accordance with the recommendations in Westinghouse Technical Bulletin NSD-TD-90-02, the BMI conduit (flux thimbles) guide tubes were visually examined for any signs of leakage. The examination was the performed BMI bytubes.

conduit guide SNC personnel. There were no signs of cracks, pitting, or other signs of degradation to GPC Action item No. 85-2515 - Steam Generator Cracking Commencing with the second !nspection period of the fitst ten-year inservice inspection interval, one w is ultrasonically examined every maintenance / refueling outage as a result of generic concern in steam generator transition cone to upper shell barrel welds (NRC IEN 85-65). This augmented examination is per GPC Action item No. 85-2515.

During ultrasonic examination of weld 11201-B6-001-O acco,rdance with ASME Section XI. The flaws were determitted to be 3-37

c5rrective action was taken (reference INF 199V1008). The examination is itemized in the Class 2 l Equipment section of this report.

GPC Action item No.18270 - Examination Techniques and Personnel Qualifications for Cold Le_g Accumulator Piping (10-inch Schedule 140, ASTM SA-376, Type 316)

As a nsult of GPC Action item No.18270, selected ultrasonic examinations were performed using nondestructive examination procedures and examination personnel qualified in the detection of intergranular stress corrosion cracking (IGSCC). There were no non-geometric indications observed during the ultrasonic examinations.

The specific welds examined are itemized with the Class 1 piping welds.

Balance of Plant Examinations for Flow-Accelerated Corrosion Ultrasonic thickness measurements were performed on selected components (fittings and/or piping) in the Condensate, Heater Drain, Heater Vent, Main Feedwater, Turbine Drain, Turbine Drive Steam, Main Steam, Steam Generator Blowdown, Extraction Steam, and Chemical & Volume Control systems. In all, sixty-two (62)large-bore components were examined during the 1R8 maintenance / refueling outage. Two of these componentinspections, 11301504-42-PXXX and 11301506-42-PXXX, consisted primarily of visual inspections performed from the inside of the 42" pipe via a manhole entry with ultrasonic readings taken at specified locations from the inside diameter surface of the subject piping. In addition, at the request of the VEGP Engineering Support Department, ultrasonic examinations were performed on twenty-four (24) small-bore areas. Included in the "small-bore" inspections was the inspection of piping downstream of the RCS letdown orifices which was performed in response to NRC information Notice 98-

45. The large and small-bore inspections were performed using SNC procedure UT-V-466 Rev,4, A " Ultrasonic Flow-Accelerated Corrosion Examination Procedure",

Twenty-three (23) large-bore components were identified to have wall thickness measurements which indicated possible wear due to flow accelerated corrosion (FAC) (also referred to as " erosion / corrosion").

The affected components had wall thickness readings which were at or below the " Action Level" wall thickness value assigned to each of the components. The " Action Level" value is defined as the wall thickness which is fifty percent (50%) of the difference between the nominal wall and Code minimum wall.

The examination results for large-bore components which had wall thickness readings at or below their

" Action Level" were reported by SNC Inspection and Testing Services (ITS) to VEGP Engineering Supput by means of either FAC Notification Reports (FNRs) or Indication Notification Forms (INFs) which can be found in the applicable section of this report. SCS engineering personnel were requested by VEGP Engineering Support to evaluate the continued acceptability of each of these components. The continued acceptability of small-bore components was determined by VEGP Engineering Support personnel. The following is a listing of correspondence associated with the engineering evaluations which are available at J

the plant site upon request:

Affected Component FNR/INF Number /Date SCS Eval. Letter Type and System NoJDate 11304030-14-P006 F99V1001, SG-16800, 14" Pipe Section, 03/03/99 03/04/99 Heater Drain System 11304030-14-P008 F99V1002, SG-16800, 14" Pipe Section, 03/03/99 03/04/99 l Heater Drain System ' i 11304031-14-P006 F99V1003, SG-1680' (s 14" Pipe Section, Heater Drain System 03/03/99 03/05/99 1

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FNR/INF Number /Date SCS Eval. Letter Type and System No./Date 11304030-14-P010 F99V1004, SG-16800, 14" Pipe Section, 03/03/99 03/04/99 Heater Drain System 11304504-4-P012 F99V1005, SG-16812, 4" Pipe Section, 03/04/99 03/05/99 Heater Vent System 11304501-4-P012HD15 F99V1006, SG-16812, 4" Pipe Section, 03/04/99 03/05/99 Heater Vent System 11304031-14-P010 F99V1007, SG-16807, 14" Pipe Section, 03/05/99 03/05/99 Heater Drain System 11304031-14-P008 F99V1008, SG-16807, 14" Pipe Section, 03/05/99 03/05/99 Heater Drain System 11304004-12-R033HD31 F99V1009, SG-16822, 6"x12" Expander, 03/08/99 03/09/99 Heater Drain System 11304123-12-R035HD42 F99V1010, SG-16822, 6"x12" Expander, 03/09/99 03/09/99 Heater Drain System 11305057-16-E010MFW24 F99V1011, SG-16827, 16" Elbow, 03/09/99 03/10/99 q Main Feedwater System Q 11305056-16-E029MFW20 16" Elbow, F99V1012, 03/10/99 SG-16827, 03/10/99 Main Feedwater System Upstream Ext u. F99V1013, SG-16833, 11305546-20-E004 03/12/99 03/15/99 20" Pipe Section, Main Feedwater System 11305055-36-P015 F99V1014, SG-16833, 36" Pipe Section, 03/15/99 03/15/99 Main Feedwater System Downstream Ext of F99V1015, SG-16842, 11305029-24-E039CND10 03/13/99 03/15/99 24" Suction Nozzle, Main Feedwater System 11305055-24-P001MFW21 F99V1016, SG-16851, I 24" Pipe Section, 03/17/99 03/18/99 Main Feedwater System 11305157-6-P001, 199V1001, SG-16791, 6" Pipe Section, 03/01/99 03/02/99 Main Feedwater System 11305157-6-E002, 199V1002, SG-16791, 6" Elbow, 03/01/99 03/02/99 Main Feedwater System 11305157-6-P003, 199V1003, SG-16791, 6" Pipe Section, 03/01/99 03/02/99

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.( p) Type and System FNR/INF Number /Date SCS Eval. Letter doJDate L 11305154-6-P003, 199V1004, SG-16819, 6" Pipe Section, 03/08/99 03/09/99 Main Feedwater System 11305154-6-P001, 199V1005, SG-16819, 6" Pipe Section, 03/08/99 03/09/99 Main Feedwater System 11305156-6-P001, 199V1006, SG-16819, 6" Pipe Section, 03/08/99 03/09/99 Main Feedwater System 11305155-6-P001, 199V1007, SG-16819, 6" Pipe Section,- 03/08/99 03/09/99 Main Feedwater System Examination results concerning each of the affected components were evaluated by SCS and it was determined that no corrective action was necessary for the 1R8 maintenance / refueling outage. However, several of these components are recommended to be replaced or at least reinspected during the 1R9 maintenance / refueling outage. While not a wear issue, the visual inspection inside component 11301504-42-PXXX discovered a short piece of angle iron that was tack welded inside the pipe. The piece of angle iron was subsequently removed. In regards to small-bore examination results,5 small-bore lines showed signs of wear significant enough to require immediate action during the maintenance / refueling outage.

These I!ws were associated with either the Extraction Steam Drains, Main Steam Drains, Moisture Separc or Reheater (MSR) Pocket Drains, or Heater Vent System. The affected portions of those small-bore lines were subsequently replaced. One additional small-bore line, the drain line from the turbine-driven Auxiliary Feedwater (AFW) Pump, showed signs of excessive wear, The affected portions of that O line are expected to be replaced with the Unit on-line since isolation of the line is possible while at power.

It is also noted that, due to previous outage examination results, the 2 %" diameter portions of the MSR Pocket Drain lines were replaced with chrome alloy piping.

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A

O Tag Number ISI Class Snubber Mfgr/ Size Scope Examined Results See Note A See Note B See Note C See Note D See Note E NOTES:

A. The unique tag number for the snubber being examined is listed in this column.

B. The ASME Section XI class no., e.g.,1,2,3, for the system on which the snubber being examined is listed in this column.

C. This column lists the name of the manufacturer of any snubbers functionally tested and the size of the snubber, e.g., PSA-1/4. Manufacturer designations are abbreviated and can be found in the List of Abbreviations.

D. This column lists the scope of examination in which the snubber is functionally tested, i.e.,

original scope or expanded scope. Snubbers included in the expanded scope of examination are generally as a result of other snubber functional test failures.

E. The results of the functional test of the snubber tested is listed in this column.

O O FIGURE 4. EXPLANATION OF SNUBBER FUNCTIONAL TEST RESULTS

SUMMARY

TABLE FORMAT 11-1 l

VEGP-1 ElGHTH MAINTENANCE / REFUELING OUTAGE SNUBBER FUNCTIONAL TESTS TYPEISNUBBERS TAG ISI SNUBBER SCOPE NUMBER CLASS MFGR/ SIZE EXAMINED RESULTS 11201-051-H007 1 PSA-1/2 EXPANDED PASS 11204-031-H015 2 PSA-1/2 ORIGINAL PASS 11208-002-H030 2 PSA-1/4 ORIGINAL FAILURE 11208-047-H006 1 PSA-1/4 PREV FAILURE PASS 11208-068-H002 2 PSA-1/2 EXPANDED PASS 11208-106-H008 2 PSA-1/4 EXPANDED PASS 11301-148-H015A -

PSA-1/2 ORIGINAL PASS 11301-157-H012 -

PSA-1/4 EXPANDED PASS 11301-168-H008 -

PSA-1/4 ORIGINAL PASS 11901-221-H027 -

PSA-1/4 EXPANDED PASS 11901-221-H028 -

PSA-1/4 ORIGINAL PASS I

i 12-1

3 VEGP-1 EIGHTH MAINTENANCE / REFUELING OUTAGE SNUBBER FUNCTIONAL TESTS TYPE ll SNUBBERS TAG ISI SNUBBER SCOPE NUMBER CLASS MFGR/SlZE EXAMINED RESULTS 11201-030-H020 1 PSA-3 ORIGINAL PASS 11201-030-H026 1 PSA-3 ORIGINAL PASS 11201-031-H001 1 PSA-1 EXPANDED PASS 11201-048-H001 1 PSA-3 EXPANDED PASS 11201-048-H002 1 PSA-3 EXPANDED PASS 11202-187-H002 3 PSA-1 EXPANDED PASS 11204-021-H013 1 PSA-10 EXPANDED PASS 11204-021-H022 1 PSA-10 ORIGINAL PASS 11204-024-H029 1 PSA-3 ORIGINAL PASS

/'s i

'Q 11204-024-H038 PSA-10 EXPANDED PASS 11204-034-H002 1 . PSA-1 ORIGINAL PASS 11204-043-H013 1 PSA-3 EXPANDED PASS 11206-006-H020 2 PSA-1 EXPANDED PASS i 11208-001-H024 1 PSA-3 EXPANDED PASS 11208-001-H028 1 PSA-3 EXPANDED PASS 11213-006-H007 3 PSA-1 ORIGINAL PASS 11301-010-H037 3 PSA-3 ORIGINAL PASS 11302-003-H003 -

PSA-3 ORIGINAL PASS 11302-010-H003 3 PSA-10 EXPANDED PASS 11305-057-H005A - PSA-10 EXPANDED PASS l

11305-118-H002 -

PSA-3 EXPANDED PASS 11305-119-H003 -

PSA-3 EXPANDED PASS b

g 13-1 I

VEGP.1 ElGHTH MAINTENANCE / REFUELING OUTAGE SNUBBER FUNCTIONAL TESTS TYPE 11 SNUBBERS (continued)

TAG ISI SNUBBER SCOPE

. NUMBER CLASS MFGR/ SIZE EXAMINED RESULTS 11305-119-H007 -

PSA-3 ORIGINAL FAILURE 11305-120-H003 -

PSA-3 EXPANDED FAILURE j 11407-003-H020 -

PSA-1 EXPANDED PASS O

13 2

I VEGP-1 ElGHTH MAINTENANCE / REFUELING OUTAGE lD l

SNUBBER FUNCTIONAL TESTS

( TYPElilSNUBBERS l

l TAG ISI SNUBBER SCOPE NUMBER CLASS MFGR/ SIZE EXAMINED RESULTS 11201-049-H002 1 PSA-35 EXPANDED PASS l

l 11201-064-H001 A -

PSA-35 ORIGINAL PASS l 11201-064-H001B -

PSA-35 ORIGINAL PASS l

11204-126-H601 1 PSA-35 ORIGINAL PASS i 11301-007-H002B -

PSA-35 EXPANDED PASS l

11301-007-H004 -

PSA-35 EXPANDED PASS ,

I l

11301-008-H017A -

PSA-35 EXPANDED PASS 11301-008-H027A -

PSA-35 ORIGINAL PASS 11301-008-H027B -

PSA-35 ORIGINAL FAILURE t 11305-058-H006 2 PSA-100 EXPANDED PASS 11305-062-H007 2 PSA-100 ORIGINAL PASS 11305-064-H005 2 PSA-35 EXPANDED PASS l

11335-064-H007 2 PSA-100 EXPANDED PASS 4

t 1 4

14-1

F' l

l h VEGP-1 ElGHTH MAINTENANCE / REFUELING OUTAGE i SNUBBER FUNCTIONAL TESTS TYPE IV SNUBBERS

' TAG ISI SNUBBER SCOPE NUMBER CLASS MFGR/ SIZE EXAMINED RESULTS 11201-030-H051 1 AD-503 EXPANDED PASS I

11201-042-H005 1 AD-71 ORIGINAL PASS 11201-044-H602 2 AD-73 ORIGINAL PASS q l

11201-097-H601 2 AD-73 EXPANDED PASS I 11201-107-H015 -

AD-43 EXPANDED PASS 11201-107 H021 -

AD-153 ORIGINAL PASS 11202-088-H045 3 AD-153 ORIGINAL PASS 11202-486-H003 3 AD-503 ORIGINAL PASS 11204-020-H005 2 AD-501 EXPANDED PASS j G '

11204-141-H601 2 AD-41 EXPANDED PASS 11208-001-H032 1 AD-503 EXPANDED PASS i

11208-002-H035 2 AD-151 ORIGINAL FAILURE 11208-002-H050 2 AD-501 EXPANDED PASS 11208-002-H053 2 AD-41 EXPANDED PASS 11208-007-H004 1 AD-71 ORIGINAL PASS l

11208-007-H005 1 AD-153 EXPANDED PASS '

11208-009-H003 1 AD-73 EXPANDED PASS 4 11208-039-H601 A 2 AD-73 EXPANDED PASS ,

11208-042-H077 2 AD-71 PREV FAILURE PASS 11208-488-H015 2 AD-501 EXPANDED PASS 11217-067-H015 -

AD-503 ORIGINAL PASS 11217-073-H602 3 AD-153L ORIGINAL PASS v

15-1

VEGP-1 ElGHTH MAINTENANCE / REFUELING OUTAGE d SNUBBER FUNCTIONAL TESTS TYPE IV SNUBBERS (continued)

TAG iSI SNUBBER SCOPE NUMBER CLASS MFGR/ SIZE EXAMINED RESULTS 11217-278-H008' -

AD-151 EXPANDED PASS 11301-012-H015A 3 AD-153 ORIGINAL PASS 11301-012-H015B 3 AD-153 ORIGINAL PASS 11301-012-H034 3 AD-73 EXPANDED PASS 11301-012-H035A 3 AD-151 EXPANDED PASS 11301-108-H002 2 AD-73 PREV FAILURE PASS 11301-110-H004 2 AD-151L EXPANDED PASS l 11301-126-H031 2 AD-151 EXPANDED PASS 11301-138-H002 2 AD-153L ORIGINAL PASS l f^) l

\j 11301-157-H014 -

AD-73 ORIGINAL PASS 11301-165-H001 2 AD-41 EXPANDED PASS 11302-107-H014 2 AD-501 ORIGINAL PASS 11407-003-H021 -

AD-153 EXPANDED PASS 12402-024-H005 -

AD-41 ORIGINAL PASS 12402-025-H004 -

AD-71 ORIGINAL PASS 15-2

l I

i VEGP-1 ElGHTH MAINTENANCE / REFUELING OUTAGE SNUBBER FUNCTIONAL TESTS TYPE V SNUBBERS TAG ISI SNUBBER SCOPE l NUMBER CLASS MFGR/ SIZE EXAMINED RESULTS 11201-064-H003A -

AD-5503 ORIGINAL PASS i

11201-064-H028A -

AD-1603 ORIGINAL PASS j 11201-064-H0288 -

AD-1603 ORIGINAL PASS 11202-004-H075 3 AD-1601 ORIGINAL PASS 11204-020-H010 2 AD-1601 ORIGINAL PASS i

11204-023-H002 1 AD-1603 PREV FAILURE PASS j 11301-007-H011 A -

AD-5501L EXPANDED PASS 11301-008-H015A -

AD-5501 ORIGINAL PASS 11301-008-H015B -

AD-5501 ORIGINAL PASS 11302-107-H010 2 AD-1601 PREV FAILURE PASS 11302-109-H023 2 AD-1603 ORIGINAL PASS i

l l

l 16-1

VEGP-1 ElGHTH MAINTENANCE / REFUELING OUTAGE SNUBBER FUNCTIONAL TESTS TYPE VI SNUBBERS TAG ISI SNUBBER SCOPE NUMBER CLASS MFGR/ SIZE EXAMINED RESULTS 11201-B6-001-S06 2 PM-25701 ORIGINAL PASS O

O 17-1 I

J

SYSTEM PRESSURE TESTS

.h s The following pressure tests were included in the scope of the eighth maintenance / refueling outage at VEGP-1. These pressure tests included system functional tests, system inservice tests, and system leakage tests. Boundaries for these pressure tests are described in the VEGP-1 Inservice inspection Plan - Second 10-Year Interval document. Examination results are discussed in the applicable sections of the "NIS-1 Abstract" and the " Class 3 and Augmented Examinations" portions of this report document.

The examination data for these pressure tests is available at the plant site for review upon request.

System Functional Test Schedule (FTs)

FT Exam. Test Number Cat. Description 1 C-H Reactor Head Vent Functional Test 3 C-H Penetration 32 (High Head Safety injection (HHSI) to Cold Legs) Functional Test 4 C-H Safety injection (SI) Pump 1204-P6-003 Discharge Functional Test

,. 5 C-H Safety injection Pump 1204-P6-004 Discharge Functional Test 6 C-H Penetration 33 (Sl to Hot Legs 1 & 4) Functional Test 7 C-H Penetration 31 (Si to Hot Legs 2 & 3) Functional Test 8 C-H Penetration 30 (SI to Cold Legs) Functional Test 9 C-H Penetration 56 (Residual Heat removal (RHR) Hot Leg injection) Functional Test 10 C-H Safety injection Pump Suction Functional Test

. 11 C-H RHR to Chemical and Volume Control System (CVCS) Suction Functional Test 14 C-H Turbine Driven Auxiliary Feedwater (TDAFW) Pump 1302-P4-001 Functional Test (See Note j D-B 1) j System inservice Test Schedule (ITs)

IT Exam. Test Number Cat. Description

, 1 C-H Charging Line inside Containment inseivice Test 2 C-H Letdown Line inside Containment inservice Test

, 3 C-H Reactor Coolant (RC) Pumps 1, 2, 3, and 4 Seal Leakoff inside Containment inservice Test 4 CH RC Pump 1 Seal injection from Penetration 54 to Valve 006 Inservice Test 5 C-H RC Pump 2 Seal Injection from Penetration 53 to Valve 359 Inservice Test 6 C-H RC Pump 3 Seal injection from Penetration 52 to Valve 360 inservice Test 7 C-H RC Pump 4 Seal Injection from Penetration 51 to Valve 361 Inservice Test 8 C-H Reactor Coolant System (RCS) Hot Leg Sample Lines to Penetration 24 Inservice Test 9 C-H Sample Line from Valve 101 to Valve HV-3514 Inservice Test

- 10 C-H CVCS Inservice Test with Positive Displacement Charging Pump Operating (Outside Containment) 11 C-H Centrifugal Charging Pump 1208-P6-002 (Train "A") Discharge Inservice Test 12 C-H Centnfugal Charging Pump 1208-P6-003 (Train "B") Discharge Inservice Test 13 D-B Boric Acid Transfer Pump Suction Inservice Test 14 C-H Accumulator Tank 1 (1204-V6-002) Inservice Test 15 C-H Accumulator Tank 2 (1204-V6-003) Inservice Test

. 16 C-H Accumulator Tank 3 (1204-V6-004) Inservice Test l- , 17 C-H Accumulator Tank 4 (1204-V6-005) inservice Test l'

( 18 C-H RHR Train "A" Inservice Test ,

19 C-H RHR Train "B" inservice Test 18-1 I

I'

'( IT Number Exam.

Cat.

Test Description

'( 20 D-C Spent Fuel Cooling Train "A" Inservice Test 21 D-C Spent Fuel Cooling Train "B" Inservice Test

! , 23 C-H Refueling Water Storage Tank (RWST) Inservice Test 24 C-H Sample Line from Valve 097 to Valve HV-3508 Inservice Test 25 C-H Penetration 24 Outside Containment inservice Test (Post-Accident Sampling) 30 C-H Nuclear Service Coo!ing Water (NSCW) Train "B" Inservice Test (Outside Containment) (See D-B Note 1)

, 64 C-H Auxiliary Feedwater (AFW) Inservice Test With Pump 1302-P4-002 Operating (See Note 1)

D-A 65 C-H AFW Inservice Test With Pump 1302-P4-003 Operating (See Note 1)

D-A 5

66 D-B Main Steam to TDAFW Pump Turbine isolation Valve HV-5106 Inservice Test (See Note 1) 67 D-B Essential Chilled Water System Train "A" Inservice Test

. 68 D-B Essential Chilled Water System Train "B" Inservice Test 79 C-H Excess Letdown Heat Exchanger Inservice Test 80 C-H RHR Cleanup Inservice Test 93 D-A Boric Acid Transfer System inservice Test with Pump 1208-P6-007 Operating 94 D-A Boric Acid Transfer System Inservice Test with Pump 1208-P6-006 Operating System Leakage Test Schedule (LT)

LT Exam. Test Description Number Cat.

1 B-P Class 1 System Leakage Test NOTES:

1. Portions of these pressure test boundaries were previously performed and documented in " Owner's Report for Inservice Inspection" for the seventh maintenance / refueling outage. The portions not previously performed were completed prior to the end of the eighth maintenance / refueling outage.

'O l 18-2 l j j

1 p) t V

INDICATION NOTIFICATION FORMS l The following Indication Notification Forms (INFs) were issued by inspection and Testing Services of Southern Nuclear Operating Company (SNC) due to reportable indications or conditions being observed during the examination of either Class 1,2, or 3 components and/or safety related flow-accelerated corrosion components during the eighth maintenance / refueling outage at VEGP-1 (referenced '

attachments are available at the VEGP plant site upon request):

INF No. Affected Component / Area INF Disposition 199V1001 i1n 5157-6-P001 FAC readings below " Action Level". Acceptable "as is". (Refer to l the " Flow-Accelerated Corrosion" section of this report for details) l 199V1002 11305157-6-E002 FAC readings below " Action Level". Acceptable "as is". (Refer to the " Flow-Accelerated Corrosion" section of this report for details) 199V1003 11305157-6-P003 FAC readings below " Action Level". Acceptable "as is". (Refer to the " Flow-Accelerated Corrosion" section of this report for details) 199V1004 11305154-6-P003 FAC readings below " Action Level". Acceptable "as is". (Refer to ,

the " Flow-Accelerated Corrosion" section of this report for details) 199V1005 11305154-6-P001 FAC readings below " Action Level". Acceptable "as is". (Refer to the " Flow-Accelerated Corrosion" section of this report for details) 199V1006 11305156-6-P001 FAC readings below " Action Level". Acceptable "as is". (Refer to the " Flow-Accelerated Corrosion" section of this report for details)

V 199V1007 11305155-6-P001 FAC readings below " Action Level". Acceptable "as is". (Refer to the " Flow-Accelerated Corrosion" section of this report for details) 199V1008 11201-B6-001-WO3 Sub-surface planar flaws acceptable per ASME Section XI.

199V1009 11201-V6-002-H06 Bolting missing (per drawin0). Acceptable "as is" per engineering evaluation.

Copies of the INFs are provided in this report document. Refer to the respective INFs for details on the nature of the indications. The INFs in this section constitute only those reportable indications observed during the SNC !nspection Testing Services Department (ITS) scope of work. Any reportable indications observed by VEGP Site personnel or outside contractors during their scope of work should be identified by/to VEGP s .:in report document (s) which are referenced herein.

G 19 1

1

! Southern Nuclear Operating Company INF-Form-002-A

! Indication Notification INF No.199V1001 P., t eenmune l

j ees. om noe moeise. P.-- n m.:

m 02/28M UT-V 446 / 4 / NA l

UT E PT D MT D ET C RT U VT Q Other D cem nts.

During Flow-Accelerated Corrosion Examination of component 11305157-6-P001, thickness measurements were detected which were at or boiow the " pre-assagned" action level. See attached report (S99V1UO42).

siensi-e .Leen woe Leve m: m:

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l Per SCS letter SG-16791, dated 3-2-99, a wear calculation was generated which shows that FAC component 11305157-6-P001 could reach its ASME code minimum wall thickness during the next several fuel cycles; however SCS believes the pipe will last through another fuel cycle before the code minimum is reached. Based on this, the component may be returned to service.

4 No corrective action required for 1R8. Cancel the planned replacement of this component which was to  !

occur per MWO# 19802040 (Note: OSCR# IR08-0314 initiated and approved to delete from 1R8 scope).

No scope expansion required since equivalent inspection locations are already included in the list of i inspected components. A determination on rescheduling this component for possible replacement will be made at a later date.

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1 Southern Nuclear Operating Company INF-Form-002-A Indication Notification INF No.199V1002 Part 1 Pinmaan Emma Date: NDE RInghed:

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02/2m

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UT E PT D MT D ET D RT D VT D Other Q UT-V-466 / 4 / NA During Flow-Accelerated Corrosion Examination of component 11305157-6-E002, thickness measurements were detected which were at or below the " pre-assigned" action level. See attached report (S99V1UO44).

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Conunents Per SCS letter SG 16791, dated 3-2-99, a wear calculation has been generated which shows that component 11305157-6-E002 will not reach its code minimum wall thickness during the next two more fuel cycles. Based on this, the component may be retumed to service.

can.m mannan.

No corrective action required for 1R8. No scope expansion required since equivalent inspection locations are either Elready on the 1R8 inspection list or else were inspected during 1R7. A schedule for reinspection of 11305157 E002 will be determined at a later date, k $~ "N

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r-Southern Nuclear Operating Company INF-Form-002-A Indication Notification INF No.199V1003 Part 1 Finanna Emern Date: NDE Mothed:

' Precedure#ReWDev.s l 02/28/99

[\ cer.o  :

UT E PT C MT U ET D RT U VT D Other a UT-V-466 / 4 / NA l

r During Flow-Accelerated Corrosion Examination of component 11305157-6-P003, thickness measurements were detected which were at or below the " pre-assigned" action level. See attached report (S99V1UO45).

Signetwo . Land NDE Level W:

Date::

D.R. Cordes / L lli (1 C.- 03/01/99 signesw .rrs Engineer / Does : Signature . fr8 Date:

l W.H. Cole h b 7 eteto4 Part 2 Acknaartadaarnant A.G. Maze i 1_ h a-3-2 99 8 knesseedged S Titto: Date:

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Per SCS letter SG-16791, dated 3-2-99, a wear calculation has been generated which shows that component 11305157-6-P003 will not reach its code minimum wall thickness during the next two more fuel cycles. Based on this, the component may be returned to service.

Cervecthfa Action'.

No corrective action required for 1R8. No scope expansion required since equivalent inspection locations are either already on the 1R8 inspection list or else were inspected during 1R7. A schedule for reinspection of 11305157 P003 will be determined at a later date.

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Part 4b. Additional Examinattena (Scone Exnanaional Part 4c succanalve Emant'intions (Futura Exarn Raoutremental Segnature . ITS Engineer: Date:

Part 5 APE Ravkie Date:

Part a per Finst Rawlam/Clamanut Dele:

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I l Southern Nuclear Operating Company INF-Form-002-A Indication Notification INF No.199V1004 Port t Findings l l

Exam Dete'. NDE tietnod, l Pi - . J._ .Osv.;

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I 03/04/ # ^

UT E PT C MT D ET C RT U VT D Other D UT-V-466 / 4 / NA

\_/ com e Dunng Flow-Accelerated Corrosion Examination of component 11305154-6-P003, thickness measurements were detected which were at or below the " pre-assagned" action level. See attached report (S99V1 UO39).

seeneture.La a Not Leven ist Date::

D.R. Cordes / L lil segnature if 3 Engineeri Date :

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4 commarrte- l Per SCS letter SG-16819, dated 3-9-99, a wear calculation has been generated which shows that FAC component i1305154-6-P003 is not expected to reach its ASME code minimum wall thickness of 0.379" j during the next two fuel cycles. Based on this, the component may be returned to service.

C, .- we Actaen-l No corrective action required for 1R8. No scope expansion required since equivalent inspection locations are already included in the list ofinspected components. A schedule for reinspection of i1305154-6-P003 will be determined at a later date.

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f Southern Nuclear Operating Company INF-Frrm.002-A Indication Notificatiin INF No.199V1006 emet i Findmg.

Esem Date: NDE teethod.

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W05/99

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UT E PT U MT U ET U RT U VT U Other D UT-V.466 / 4 / NA During Flow. Accelerated Coriosion Examination of component 11305154.&P001, thickness measurements were detected which were at or below the " pre-assigner action level. See attached report (S99V1 UO37).

Signsture. Lead NoE Levellil: Date:;

D.R. Cordes / L lli g 3 4.q q Signature . ITS Eng6neer i Date ;

Deae:

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Per SCS letter SG-16819, dated 3-9-99, a wear calculation has been generated which sFaws that FAC component i1305154-6-P001 is not expected to reach its ASME code minimum wall thickness of 0.379" during the next two fuel cycles. Based on this, the component may be returned to service.

C -eve Accon:

No corrective action required for 1R8. No scope expansion required since equivalent inspection locations are already included in the list ofinspected components. A schedule for reinspection of 11305154 6-P001 will be determined at a later date.

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Port do . $wwe Exem::.__ _. .sfuture Exem Requirements)

Signature . lTS Engineer. Date:

l M S. ANit Review Date:

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Southern Nuclear Operating Company I INF Ftrm 002-A Indication Notificati n INF No.199V1006 Pen i Pineine.

Exam Date; NOE tiestod-ProceeuredtewfDev.:

/ OMS UT-V 466 / 4 / NA UT E PT U MT Q ET Q RT Q VT D Other Q O] -m._

During Flow-Accelerated Corrosson Examination of component 11305156-6-P001, thickness naasurements were detected which were at or below the "nre-assignes action level. See attached report (S99V1UO41).

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Per SCS letter SG-16819, dated 3-9-99, a wear calculation was generated which shows that FAC component 11305156-6-P001 is not expected to reach its ASME code minimum wall thickness of 0.379" during the next two fuel cycles. Based on this, the component may be returned to service.

C ._;.we Action.

No corrective action required for iR8. No scope expansion required since equivalent inspection locations are already included in the list ofinspected components. A schedule for reinspection of 11305156-6-P001 will be determined at a later date.

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Part 8 INF Finsi Rn ._ J' '

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Southern Nuclear Operating Company INF-F rm-002-A Indicati:n Notification INF No.199V1007 P.n , r.,,dm .

e,em com NOE W ProcedurWRevtDew; f7 (j

03/04/88 Comments.

UT E PT C MT U ET U RTU VTU Other a UT-V-466 / 4 / NA Dunng Flow. Accelerated Corrosion Examination of component 11305155-6-P001, thickness measurements were detected which were at or below the ' pre-assigned" action level. See attached report (S99V1UO40).

siensture.t.ad Noe t.vei ni. n oste::

D.R. Cordes / L lli Jo L bagnature . 4Is Engineer i Date :

5 g e:;4 Signature.ITS Su e. Ook W.H. Cole (h h f.

Part 2. Acknowledgeme_nt O,t, A.G. Maze OD11 mo, Pfd 99

~ Notericanon Acknowledged Bt title: Date.

Port a . ones _;. by f.

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3" 'H Comments.

Per SCS letter SG-16819, dated 3-9-99, a wear calculation was generated which shows that FAC component i1305155-6-P001 is not expected to reach its ASME code minimum wall thickness of 0.379" during the next two fuel cycles. Based on this, the component may be returned to service.

C,,,. eve Action:

No corrective action required for 1R8. No scope expansion required since equivalent inspection locations are already included in the list ofinspected components. A schedule for reinspection of 11305155-6-P001 will be determined at a later date.

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Part da . Re4xameWatiort After Corraigove Ac00n l j

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Signature . Exammer $NT Levet Date:

Part 40. Addruonal Emammations tScope, Expanssonsj Part_4cluccessave Examinations (Future Exam Roguerements_j

$63 nature . lT S Engineer.

Date:

Part,6. ANW Revtew Date.

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S:uth:rn Nucle:r Operat!ng C:mpany INF-Fcrm402-A Indic^ tion Notific-tion INF No.199V1008 Part 1 emyg Esam Date: NDE Method: Procedure 4tovtDev.:

03/08/99 UT-V 411/ 9 / NA UT E PT U MT D ET D RT U VT D Other D Con mente:

During a Ultrasonic Examination of component 11201-806-001.WO3 seven indications were recorded using the 60 degee 2.25 MHZ and one wa the 45 degree. Four of the 60 degree 2 23 k (Z indications were Code unacceptable. See attached report (S99V1U144). These indications were evaluated using a 60 degree 4 MHZ wkte ta id transducer which provided a more reahstic dimension of the true indication sizes. All four indicatiork ',.ere found to tw Code acceptable. See attached report (S99V1U147).

sign.iure .c d noe L.v.i a n oa.::

D.R. Cordes / L lli s6gnature . iTs Engmeeri Date a

.J4 L 03/11/99 _

Dase:

W.H. COLE bt Tetws 0// C. signature.

A.G. Maze tis _superv[i h. g): e w 1 yylm c, 03/11/99 Pad 2.Ack.- __

47 Notificatton Ackn-Scott Hargis' ey: ^ /d j // M#

Part 3 Dispoemon by Project /sete /'

Titie:

Engineering Group Supervisor Date:

J /g,[99 C _ _ _ _ :o:

None Required. Code Acceptable.

Correcteve Action:

N/A O ~

signature:

Scott Hargis [ /[k Tntie: Date:

Part da . Re-Emammation After Corrective Acteorn V Engineering Group Supervisor Jh' y

N/A signature . Esamaser: sNT Level: Date:

E Part eb. AddL. anal Examinations tscope Espanssojn N/A Part ac . successive Exammations (Future Enam Requarements)

N/A Signature . ils Engmeer: Date:

W. H. Cole ppe Tpgg Ogc ~3 -l g ch

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/~~, Frank Bellais hm ) } th eart s .

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y S:uth:rn Nucle:r Operating Company INF-Form-002-A Indication Notification

INF No.199V1009 Port 1."' __

rm y en03/08/99 o_ .e - ,,oco._.ev.v.,

Commones:

UT u PTu MTC ET u RTu VTe Other u VT-V-735 / 3 / N/A Dunng visual examination of component 11201.V6 002.H06 (Pressurizer Support Steel)It was noted that bolts were missing which the design drawing on record (1X2D48 LOO 4 Rev 13) specified as being required (reference attached visual report S99V1V643). The condition was also reported dunng the 1R2 refueling outage (reference 190V1011) and evaluated as acceptable "as is'.

begnature . Lead NDE Lovet ul:

n Date:

D.R. Cordes / L 111 .J/k 03/12/99 segnature . lTS Engineer J oote Segnature . lis supervisor: Date:

W.H. Cole h hu.,.2 Part 7 - Acknowlesigement O/tc A.G. Maze ( M k_,1 h a - 03/12/99 r

Notencation Acknowledged By:

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Title:

oate: j ,_

Scott Hargis /4 4 , Engineering Group Supervisor ]//,2/99 Part 3 Despooneen by Pr-s-_ ^ T::_

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lls r3 uti r AfsrtrE # 34/45 hMS GJk1247/D 70 VFD.4TE ONWM

/X2D4BL OOf To /A' air.47E A S f d V4'O F ffl 0 00AD/ S-Corrective Acteon:

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~"s>& a Part ea'. Re-Ema.-.- .on After Corrective Action b mm "h DT / fh0lSfD Segr.ature . Emanuner: $NT Level: Date:

At/A Njb1 N/A Part eb . Addemonai Emanunatsons tscape Espanssonen NC4'E SfG(//2ED can . soccesse.e enar.na.one i, ture ea.. neito,r onio, Afe4'E XEQt//PEb L R c/ ~ddv9 i

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WY V

OWNER'S REPORTS FOR REPAlRS OR REPLACEMENTS

] (FORL NIS-2)

The following Owner's Reports for Repairs or Replacements (Form NIS-2) are provided for work activities documented at VEGP 1 since the last maintenance / refueling outage (1R7) through the completion of the eighth maintenance / refueling outage (1R8) in March 1999. Reports are identified by their respective traveler number which is denoted on each of the NIS-2 reports. The originals of the NIS-2 reports are filed with their respective traveler packages at the plant site. Only those NIS-2 reports applicable to VEGP-1 are included in this report document. Any attachments, e.g., code data reports, etc., referenced in the NIS-2 reports will be made available for review upon request at the plant site.

The NIS-2s for the following travelers are included herein:

96000 197088 97124 97151 97181 97208 98156 96080 & 081 i97092 & 093 97125 97153 97182 97210 98158 96098 97095 97126 97154 97183 97218 98160 96100 97096 97127 97155 97184 97219 98179 96122 97097 97128 97156 97185 97247 98192 96124 97098 97129 97157 97186 98009 98206 96140 97100 97130 .

97158 97187 98030 98207 96310 97101 97131 97160 97188 98031 98208 96311 97103 97132 97161 97189 98035 98209 96349 97104 97133 97163 97192 98039 98210 97002 97109 97134 97165 97193 98040 98211 97007 97110 97135 97167 97194 98047 98212 97036 97112 97136 97170 97195 98048 98215 97040 97113 97137 97171 97196 98049 98225 97042 97115 97142 97172 97197 98058 I 98233 97043 97116 97143 97173 97200 98069 99006 97044 97117 97144 97174 97201 98077 '99020 97057 97118 97145 97175 97202 98080 99024 97064 & 065 97119 97146 97176 97203 98081 99025 97076 97121 97147 97177 97204 98092 99031 97077 97122 97148 97179 97205 98133 97080 j97123 97150 97180 97207 98155 I

20-1  ;

1 l l

?

UniblWAL FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required Cy The Provisions Of The ASME Code Sect 6on XI Traveler # 96000

1. Owner southern NucJeeroperedne ConmanyISNC) 0 gam, 40 inverness CenterParenvey, C._ _ .AL Date Sheet I 12/1297 of 5

2. Plant Voede Edoctric Generaans Pfent Unit 1 Wepneeboro, GA 30830 MWOM 19600075,19600076.19600077.19701065.19701066 and 19701068 Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by NucJear Operadons Afeintenance Plant Vogtle Name Address

4. Identification Of Syntam 1302/Auxhary Feedwater System

5. (a) ap.ada construction Code ASME SEC llI 1977 Edition, Wmter 1977 Addenda, WA Code Case (b) Applicable Edition of section XI Utilities For Repairs or .- , __..ts 19)LCode Case N-416-1

8. IdentlAcetion Of Components Repairs or F , _ _l Components NAME NAE MANUFACTURER NATIONAL OF REPAIREO, ASME CODE OF SERIAL BOARD OTHER YEAR COMPONENT MANUFACTURER REPLACED OR STAMPED NO NO IDENTIFICATION SUllT REPLACEMENT (YES OR NO) 1302 PPING PULLMAN POWER WA WA 1K51302-01501 1987 SYSTEM REPLACEMENT YES PRODUCTS 1K51302-022-01 1302 P PING PULLMAN POWER WA WA 1KS1302-027-01 1967 REPLACEMENT YES SYSTEM PRODUCTS 1K$1302-04501 1302 PIPING PULLMAN POWER WA WA 1KS1302-046-01 1967 REPLACEMENT YES SYSTEM PRODUCTS 1302 PIPING SNC WA WA 1KS1302-713-01 1997 REPLACEMENT NO SYSTEM 1K51302-71501 7

n of a second Auxharv Feedwater numa trini now kne for each oumo The O . Deecription Of Work Psoina m;;,c.&t,&n reauwed svstem the MstaBahonwas mocMed ofinaplpn bvonnce valves. now the and=mnice enn""rts in emo* dance wtth DCP 95-V1N0018 Flow ornice 1F05114A and 1F05117A were febncated under Tr : l;r 96tm Ptcrna modrRcabons comoteted under Tr:z.:;; 97073. 97074. 97087 and 97209. Ploe en=+i. were instaned under Traveler 97075.

1v 05take test ;;.%; -,; under Wo# 19701068. Comes of Form NPV-1 for reolacement valves attached.

B. Test Conducted: Hydrostatic Pneumatic NominalOperating Pressure X Code Case N-416-1 N/A Other [] @ Pressure N/A PSI Test Temp. N/A 'F CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPLACEMENT rules of the ASME Code,Section XI. conforms to the

.. repair or replacement Type Code fymbolStamp N/A Certificate of Authorizat -

N/A Expiration Date N/A

( Signed -

M bC Date /C /t.19 f 7 Owner or Owner's Designee. Titief CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Province of Georcia inspected and employed by Herttbrd Steam boeerInsoechon andinsurance Co. of Hartford. Connechcut have the components described in this Owner's Report during the period 060596 13 /fa/7 97 and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

!y signing this certificate, neither the inspector nor his employer makes any warranty, esp.ressed or implied, concerning the Imaminations and corrective measures described in this Owners Report. Furthermore, neither the Irispector nor his employer shall be liable in any menner for any personal injury or property damage or a loss of any kind arising from or connected with this

/b inspector's Signatufe' Commissions b4 MU National Board, State, Province and Endorsements Date _M, 17 to 97

r .

UMlbilNAL l

FORM NIS 2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS  !

As Required By The Provisions Of The ASME Code Section XI Traveler # 96080 It6081

1. Owner Southern NuclearODerating ComDany Date 9/16197 Name .

40 inverness Center Parkway. Birmingham, AL Sheet t of 3

2. Plant Vogtle Electric Generating Plant Untt 1 Waynesboro, GA 30830 MWO# 19600G22 Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by Nuclear Operations Maintenance Plant Vogtle Name Address

4. Identification Of System 13011 Main Steam System

5. (a) App!! cable Construction Code ASME SEC111 1977 Edition, Winter 1977 Addenda, N/A Code Case (b) Applicable Edition of section XI Utilities For Repairs Or Replacements 1983_ Code Case N416-1

8. Identification Of Components Repairs or Replacement Components NAME NAME MANUFACTUR NATIONAL REPAIRED, ASME CODE OF OF ER BOARD OTHER YEAR REPLACED OR STAMPED <

COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION BUILT REPLACEMENT (YES OR NO) I NO.

VALVE ENERTECH 10420 N/A 1-1301-U4-006 1996 REPLACEMENT YES VALVE ENERTECH 10421 N/A 1-1301-U4-404 1996 REPLACEMENT YES 1301 PULLMAN N/A N/A 1KS-1301-012-021 1987 REPLACEMENT YES PIPING POWER SYSTEM PRODUCTS

7. Description Of Work Valves 11301-U4-000 and (-404) were reDioced with a new desIan check valve Der DCP 96-V1N0014.

O Condensate virain Ilnes were also added to the Divina UDstream of each Check Valve. ANil review of 1"and smaller DlDieb Bnd SUDDort welds is for Rnal documentation onlV.

8. Test Conducted: Hydrostatic Pneumatic Nominal Operating Pressure X Code Case N416-1 N/AO Other Pressure N/A PSI Test Temp. N/A 'F CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code,Section XI. repair or replacerrent l Type Ccde Symbol Stamp NIA (C' Certificate of A it zation No. N/A Expiration Date N/A

/ APPROVED BY /

Signed \ .

- SAMNTENANCEMANAGER Date Owner or Owner's Designee, Title

/O/ U 19 7 7 '

CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Province of Georale and employed by Hartford Steam boiler InsDeCtion andineurance Co. of Hartford. Connecticut have inspected the components described in this Owner's Report during the period 03I18/96 t) // / 5 -9 7 .

and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

By signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the examinations and corrective measures described in this Owners Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any pers9nal injury or property damage or a loss of any kind arising from or connected with this e N Commissions MA M97 Inspector's Signature u' National Board, State. Province and Endorsements Date //* &5 19 h7 L -

.a

%y ORIGINAL l

• 22 -

FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS f As Required By The Provisions Of The ASME Code Section XI l Treveier# es.000 l

1. Owner Geersie Power Commenv Date 11/14tts Name 333 Pfsehnent Avenue, Adente GA. Sheet I of 1

s. Plant ussee Eisee* - - -_- _ Puent unit 1

~'

WaynesborcL GA 30830 MWO# 19601220 Address Repair Organization P.O. No., Job No., etc.

s. Work Performed by Nucieer C-_ assewenance Plant vestie Name Address

4. sdentencation Of System - tnos 1 Chemical volume and Control System E. (a) Apphcable Construction Code ASAlf SEC SI 1974 Edition, N/A Addenda, 1837 Code Case (b) Applicable Edition of sectlon XI Utilities For Repairs Or Replacements 10E

8. Identification Of Components Repairs Or Repiscement Components NAE NAE MANUFACTUR NATIONAL REPAIRED. ASME CODE OF OF ER BOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER SERLAL NO. IDENTIFICATION SUILT REPL.ACEMENT (YES OR NO)

NO VALVE FISHER 6499458 WA 1FV-0121 1979 REPLACEMENT YES CONTROLS CO.

WA WA WA WA WA WA WA WA

7. Description Of Work Valve adup agammbly was rundeced wth serialnumber 880697 f.

1

8. Test Conducted: Hydrostatic PneumaticC NominalOperating Pressure g%

N/A X OtherC Pressure N/A PSI Test Temp. N'A T g '

CERTIFICATE OF COMPLAANCE l

t We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code,Section XI. repair or replacement Type Code Symbol Stamp N/A Certificate of Auj ion No. N/A Expiration Date N/A

. APPROVED BY lI /ff9 Signed anamereuauer uauseen Date it @d l Owner or Owner's Desionee Title -'

a_.,.

CERTIFICATE OF $NSERVICE INSPECTION

{.a I, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or

- Province of Geonnis and employed by Hartford Steam boNerinamoctfon andinsurance Cp,,of NarfArnt Connecticur have inspected the components described in this Owner's Report during the per6od to 3 -J.] - 7 6

/- 2 3-T 7. and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

' By signing this certificate, neither the inspector nor his employer makes any warranty, empressed or implied, concerning the fj

• examinations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising trom or connected with this

%, D uL Commissions C/7N inspdor's Signature Natsonal Board, State, Prov6nce and Endorsements Date /-2 3 1e 97 O

i 1

= '

ORIGINAL l FORM NIS-i OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS i As Required By The Provisions Of The ASME Code Section XI Traveler # es100

1. Owner Georede Power Company Date S/18/98 Name m Piednont Avensis, Adande GA. Sheet } of }

1. Plant Vesde Electric Generedne Pfent Unit 1 Wisynesboro. GA 30830 MWO# 19403709 Addrass Repair Organization P.O. No., Job No., etc.

3. Work Performed by NucJoer Operadons A8sindenence Plant Voette Name Adgress

4. Identification Of System 11204/ SAFETY INJECTION FNsTEM i

4. (a) Applicab e Construction Code ASAGE SEC Nf 19 TT Edition, WWTER 19T/ Addenda, N/A Code Case i (b) Applicable Edition of section XI Utuities For Repairs Or F ' _ .;e 19E

6. Identification Of Components Repairs Or Replacement Components l NAME NAME MANUFACTUR NATIONAL REPAlRED. l ASME CODE l

OF OF ER BOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION BUILT REPLACEMENT (YES OR NO)

NO.

PIPE PULLMAN NfA NfA 1120402SH015 1986 REPLACEMENT YES SUPPORT POWER PRODUCTS

. Dst.cription Of Work INSTALLED NEW BTUD 1EA AND NUTE 4EA ON PIPE CLAhfP

s. TestConducted: Hydrostatic Pneumatic Nominal Operating Pressure @

N/A X Other Pressure N/A PSI Test Tamp. N/A T 4A CERTIFlCATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code,Section XI. repair or . . . -. .;

Type Code Symbol Stamp N/A l C:stificate of ? " M-n No. N/A Expiration Date N/A Signed b9 Date D it N Owner or Owner's Desionee, Titti I CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Province of Geornis and employed by M .; ~

--i . and " --- - - Co. of Hartford. Connecdcut have mspected the components described in this owner's Report during the period 1 - 2'1- %

t2 . .T. 5- 9 7 . and atste that to the best of my :. .n . and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code. Section XL Iy signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the

mamirrions and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be liste in any ma ner for any per al injury or property damage or a loss of any kind arising from or connected with this db '

Commissions MAI(/97 Inspector's signature / National Board, State, Province and Endorsements Date M8 19 k

OR GINAL FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required By The Provisions Of The ASME Code Section XI Traveler # 96122

1. Owner Southern NuclearOperethe Company Date 6/12/98 40 frwomees CenterParisway, BL -- . AL Sheet 1 of 1 l

2. P! ant Voede EJoctric Genersons Plant Unit 1

1 i

W;r- _MX,, GA 30830 MWO# 19800894 Address Repair Organization P.O. No., Job No., etc. I i

3. Work Performed by NucAsarOperadons Afaintenance Plant Vogtie Name Address l

4. Identification Of System l 1201/ REACTOR COOLANT PUMP j

5. (a) Applicable Construction Code ASAGE SECl# 197f Edition, WNTER 1972 Addenda, N/A Code Case (b) Applicable Edition of section XI Utilities For Repairs Or Replacements 1981 j

8. Identification Of Components Repairs or Replacement Components NAME NAME MANUFACTUR NATIONAL OF REPAIRED, ASME CODE OF ER COARD jf.FA COMPONENT MANUFACTURER OTHER YEAR REPLACEO OR STAMPED SERIAL NO. 10ENTIFICATION BUILT rinJeg NO REPLACEMENT (YES OR NO)

REACTOR WESTINGHOUSE 1 23 11201P6001 1986 REPAIR YES COOLANT CORP. 9744D35G0f ,

11208432H602 '

PUMP 7, Deecription Of Work DRnLLED AND TAPPED NOLES N BOLTNG RING OF NEW ROTATNG FIM*^'T SERIAL NUMBER 9 97WT^^2 TO FACILITATE NETALL^ TION OF PIPE SUFFORT 1-1.*'* 222-M002

8. Test Conducted: Hydrostatic Pneumatic 0 NominalOperatingPressure X N/A X Other Pressure N/A PSI Test Temp. N/A T CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPAIR rules of the ASME Code, Section XL conforms to the repair or replacement Type Code Symbol Stamp N/A Certificate of Authorizat No. N/A Expiration Date N/A Signed dN b Date S 24 19 %

Owner or Owner's Desionee Title /

CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Prtvince of Geoross and employed by Hartford Steam boiler h_---d~r eruf insurance Co. of Nortford, Connecdcut have 12 *).inspected E- 9 Y the . components described in this Owner's Report during the period // /6 -9 5 and state that to the best of my knowledge and belief, the Owner has performed examinations and taken conictive enessures described in this Owners Report in accordance with the requirements of the ASME Code, Section XL Sy signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the Imaminations and corrective measures described in this Owners Report Furthermore, nedher the inspector nor his employer shall be liable in any manner for any - 1 injury or property damage or a loss of any kind arising from or connected with this

% .IIAE inspector's $4 nature /

Commissions d4 M9'7 National Board. State, Province and Endorsements

%t l' Z 19 W Oe

rf /

ORIGINAL FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required By The Provisions Of The ASME Code Section XI Traveler # es.124 V 1.

Owner Southem Nuclear Operatine Company Date S11 499 7 Name d0invemess Center ParkwayBirmingham, AL Sheet 1 of 1

2. Plant Voede Electric Generatine Piant Unit 1 Waynesboro, GA 30830 MWO# 19800761 Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by Nuclear Operations Maintenance Plant Vogtie Name Address

~

4. Identification of System 1202 / Nuclear Service Cooling Water

8. (a) Applicable Consttuction Code ASME SEC #1 1977 Edition, Winter 1977 Addenda, WA Code Case (b) Applicable Edition of section XI utilities For Repairs Or Replacements 1931

8. Ic;entification Of Components Repairs Of Replacement Components NAME NAK MANUFACTUR NATIONAL REPAIRED. ASME CODE i I

OF OF ER BOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION BU!LT REPLACEMENT (YES OR NO) l NO. '

PIPNG PULLLMAN WA WA 1K5-1202 512-01 1966 REPLACEMENT YES <

SYSTEM - POWER 1 PRODUCTS WA WA WA WA WA . WA WA WA

+

1. Description Of Work Plaina llance boltina was r"& at valve 1 1202-Ud-A07.

8. Test Conducted: Hydrostatic Pneumatic Nominal Operating Pressure N/A X OtherC Pressure N/A __ PSI Test Temp. N/A T.

CERTil ICATE OF COMPLlANCE We certify that the statements made in the report are correct and this _

replacement conforms to the l rules of the ASME Code,Section XI. repair or replacement Type Code symbol Stamp N/A Certificate o A o ion No. _. N/A Expiration Date N/A I

- Amwveu uT j j Signed 4AINTENANCE MANAGER Date / C"/ 26 it 'T '7 i Owner or Owner's Designee, Title CERTIFICATE OF INSERVICE INSPECTION t, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Province of Georata and employed by Hartford Steam boiler Inscoction and Insurance Co. of Hartford. Connecticut have inspected the components described in this owner's Report during the period 03/24/96 to /M 2(-#

nd state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code, Section XI.

!y signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied,'concerning the

maminations and corrective measures described in this Owners Report. Furthermore, neither the Inspector nor his employer shall

' be lia in any man for ny rsonal injury or property damage or a loss of any kind arising from or connected with this

. *>A -

Inspector's Signature O "

Commissions bNational N7Board, State, Province and Endorsements

& D.t. 4 2th 97 19 9,7

ORIGINAL J FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required By The Provisions Of The ASME Code Section XI Traveler s 96140

1. Owner Southern NuclearOperaung Company Date 10/3M7 Name 40 Inverness Center Parkway, Birmingham, AL Sheet I of i

2. Plant Vogtle Electric Generatlng Plant Unit 1 Waynesboro, GA 30930 MWON 19600855 Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by Nuclear Operadons Maintenance Plant Vogtle Name Address

4. Identification Of System 1204 / Safety Injection System

5. (a) Applicable Construction Code ASME SEC III 19ZZ Edition, Winter 1977 Addenda, N/A Code Case (b) Applicable Edition of section XI Utilities For Repairs Or Replacements 1912

6. Identification Of Components Pr pairs Or Replacement Components NAME NAME MANUFACTURER NATIONAL REPAIRED. ASME CODE OF OF SERIAL BOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER NO. NO- IDENTIFICATION BUILT REPLACEMENT (YES OR NO)

VALVE DRAGON RX3032 N/A 1-1204-U4-119 1964 REPAIR YES VALVES. INC.

7. Description Of Work Performed machinina ort valve duo culde rinas to remove oaRina damaae.

8. Test Conducted: Hydrostatic Pneumatic Nominal Operating Pressure p

U N/A X Other Pressure N/A PSI Test Temp. N/A T CERTIFICATE OF COMPLtANCE We certify that the statements made in the report are correct and this REPA/R conforms to the rules of the ASME Code,Section XI. repair or replacement Type Code Symbol Stamp N/A Certificate of Aut ri a ion No. 3 N/A Expiration Date N/A Signe h tt- !I te l[ 1997 '

Owner or Owner's Designee, Title CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vesselinspectors and the State or Province of Georals and employed by Hartford Steam BoIIer Inss>ection and Insurance Co. of Hartford. Contrecticut have inspected the components described in this Owner's Report during the period OY2M6 to // f/o - 07 . and state that to the best of my knowledge and belief, the Owner has performed examinations and taken

corrective measures described in this Owners Report in accordance with the require 1ents of the ASME Code,Section XI.

By signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the examinations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any pet onal injury or property damage or a loss of any kind arising from or connected with this s~ V L[ Commitisionc _ 8 A 97 Inspector's Signatur[ National Board, State, Province and Endorsements Date //-76 19 h7 G

v

L ORIGINAL FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required By The Provisions of The ASME C Me Section X(

Traveler # 96310 1

1. Owner Southern Nuclear Operating Company Date 1 0114197 \

1 Name 40Invemens Center Parirway, Birminoham, Ala. Sheet I of 1

2. Plant Vogtle Electric Generatina Plant Unit 1 Waynesboro, GA 30830 MWOW 19801889 Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by Nuclear Operations Maltstenance Plant Vogtle Name Address 4 Identification Of System 1202 i Nuclear Srvice Cooling Water

5. (a) Applicable Construction Code ASME SEC #l 1977 Edition, Winter 77 Addenda, N/A Code Case CLASS 3 (b)Apphcable Edition of section XI Utihties For Repairs Or Replacements 190J l - 6. Identification Of Components Repairs or Replacement Components MANUFACTURER NATIONAL REPAlRED. ASME CODE

,pi Q NAME g OF COMPONENT NAME OF MANUFACTURER SERIAL NO BOARD NO.

OTHER INNTIFICATION YEAR BUILT REPLACED OR REPLACEMENT STAMPED (YES OR NO)

G PIPING PULLMAN N/A N/A 1 1202-512-H602 1986 REPLACEMENT NO SYSTEM POWER PRODUCTS i

Beolaced sn&r with claid Dice strut at suaaort number 11202-612-H007 per DCP 06-V1N000T.

O l. DescriptionOf Work j 1

S. Test Conducted: Hydrostatic Pneumatic Nominaloperating PressureO l

N/A@ Other Pressure N/A PSI Test Temp. N/A Y CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPLACEMENT _ conforms to the rules of the ASME Code, Section XL repair or replacement Type Code Symbol Stamp N/A Certificate of A h Ization No. N/A Expiration Date N!A l

/0// N APPROVED BY Signed untNTENANcF MANAnra Date 19 N Owner or Owner's Designee. Title CERTIFICATE OF INSERVICE INSPECTION l

1, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or i Province of Georcia and employed by Hartford Steam boiler Insoection and Insurance Co, of Hartford. Connecticut the components described in this Owner's R6 port during the have inspied to /d /hM7 period M 4'& 06 ,

Lnd state that to the best of my knowledge and belief,the Owner has performed examinations and taken corrective measures described this Owners Report in accordance with the requirements of the ASME Code, Section XI.

in By signmg this certificate, neither the inspector nor his employer malies any warranty, expressed or implied, concerning the

xaminations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shaft be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this f AEe ' Commissions 84(./97 Inspector's Signature () National Board, State, Province and Endorsements Date /6 - PA 19 9 *7

)

! )

m

/ FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS ORIGINAL As Required By The Provisions Of The ASME Code Section XI l

i q Traveler # 96311

• l 1. Owner Southern Nuclear Operating Company Date 10l15197 Name 40 Inverness Center Parkway, Birmingham, Ala. Sheet i of 1 j

2. Plant Vogtle Electric Generating Plant Unit 1 Waynesboro, GA 30630 MWO# 19601490 Address Repair Organization P.O. No., Job No., etc.

3, Work Performed by Nuclear Operations Maintenance Plant Vogtle  !

Name Address

4. Identification Of System 1202 i Nuclear Srvice Cooling Water

6. (a) Applicable Construction Code ASME SEC111 1977 Edition, Winter 77 Addenda, N/A Code Case CLASS 3 (b) Applicable Edition of section XI Utihties For Repairs Or Replacements 1999

6. Identification Of Components Repairs or Replacement Components NAME MANUFACTURER NATIONAL REPAIRED. ASME CODE NAME BOARD OTHER YEAR REPLACED OR STAMPED

)

OF OF SERIAL 1 COMPONENT MANUFACTURER NO NO. IDENTIFICATION BUILT REPLACEMENT (YES OR NO)

PIPING PULLMAN N/A N/A 1-1202 516-H602 1986 REPLACEMENT NO SYSTEM POWER PRODUCTS Description Of Rep _ laced snubber with riald cloe strut at support number 11202-616-H602 ver DCP 96.V1N0007.

p)

( 7. Work ,

8. Test Conducted: Hydrostatic Pneumatic Nominal Operating Pressure N/A X Other Pressure N/A PSI Test Temp. N!A 'F

\ CERTIFICATE OF COMPT. LANCE We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code,Section XI. repair or replacement Type Code Symbol Stamp N/A Certificate of Auth I on No. ._....m N/A Expiration Date N/A p Arrnwvr.uoi j Signed s AfMNTENANCE MANAGER Date /O/ ? E 19 O Owner or Owner's Designee, Title CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the national Board of boiler ar:d Pressure vessel inspectors and the State or Province of Georale and employed by Hartford steam boiler inspection and Insurance Co. of Hartford. Connecticut have inspected the components described in this Owner's Report during the period 8299(., to k~ 07// 7

nd state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code, Section XI.

Zy signing' this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the

xaminations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shpil be li ble in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this

(~ A > ( Commissions d 4 t,/9 ")

Inspector's Signature [/ ' National Board, State. Province and Endorsements l

Date JD-7'l 13 Of l

" U NiuIIML.

FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required iy The Provisiom: Of The ASME Code Section X: l Traveler # 96349 0

V

1. Owner Southern NuclearOperating Company Name Date 02/27AB 40 inverness CenterParinway, Birmingham, AL Sheet i of 1 1

2. Plant Voede EJoctric Generating Plant Unit 1 Waynesboro, GA 30830 MWO# 1960199f Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by Nuclear Operrions Maintenance Plant Vogtle Name Address

4. Identification Of System 1202 / Nuclear Service Cooling Water System

6. (a) Appilcable Construction Code ASME SEClll 1974 Edition, Wfnter 1975 Addenda, N-24.1516-2 Code Case (b) Applicable Edition of section XI utillues For Repairs Or Replacements 1989

8. Identification Of Components Repairs Or Replacement Components NAME NAME MANUFACTUR NATIONAL REPAIRED, ASME CODE OF OF ER BOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION BUILT REPLACEMENT (YES OR NO)

NO.

MALVE FISHER 7688571 6700 1CV-9447 1983 REPLACEMENT YES CONTROLS CO. \

7. Description Of Work ya&e DIuo was roolaced.

C.)/ 3. Test Conducted: Hydrostatic Pneumatic NominalOperating PressureO N/A X OtherC Pressure N/A PSI Test Temp. N/A 'F CERTIFICATE OF COMPLlANCE We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code, Section XL repair or replacement  :

Type Code Symbol Stamp N/A Certificate of Aut ation No. N/A Expiration Date N/A Signed M b Date Owner or Owner's Designee, Titl(/

d it

]

CERTIFICATE OF INSERVICE INSPECTION t, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Plovince of Georais and employed by Harttbrd Steam boRetInsoecton and Insurance Co. of Hartford. Connec0 cut have inspected ~s components described in this Owner's Report during the period 10/08/96 to .1 . ,

. and state that to the best of my knowledge and belief, the Owner has performed examinations asures described in this Owners Report in accordance with the requirements of the ASME Code, Section XL and taken correct .

)

By signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the examinations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising frorn or connected with this J I

'~

Commissions M4Q~7 I Inspector's Signature V National Board, State, Province and Endorsements Date 3-5 19 9 fr'

ORIGINAL FORM NIS-2 OWNER'S' REPORT FOR REPAIRS OR REPLACEMENTS As Required By The Provisions Of The ASME Code Section XI Traveler N 97002

1. Cwner Southern Nucleeropereuna Comi ny Date 02/27/98 Name 40 Jnverness Center Parkway, BirmMaham, AI. Sheet 1 of 1

2. Plant Voethe Electric Generating Plant Unit 1 Waynesboro, GA 30830 MWON 29602741 Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by Nuclear Operations Afaintenance Plant Vogtfe Name Address

4. Identification Of System 1205 /ResidualHeat RemovalSystem

5. (a) Applicable Construction Code ASME SEC til 1977 Edition, Winter 1977 Addenda, N/A Code Case (b) Applicable Edition of section XI Utilities For Repairs Or Replacements 19M

6. Identification Of Components Repairs Or Replacement Components NAME NAME MANUFACTUR NATIONAL REPAIRED, ASME CODE OF OF ER BOARD OTHFR YEAR REPt. ACED OR STAMPED COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION BUILT REPLACEMENT (YES OR NO)

NO 1205 PULLMAN N/A N/A 2K3-1205 003-01 1989 REPAIR YES f

\

PIPING SYSTEM POWER PRODUCTS 7, Description Of Work Arc strikes identmed bv DC 2-07-036. were removed bv IMna.

(( B. Test Conducted:

N/A X Hydrostatic OtherO Pneumatic Pressure NominalOperating PressureC N/A PSI Test Temp. N/A 'F j I

CERTIFICATE OF COMPLIANCE

]

We certliy that the statements made in the report are correct and this REPAIR conforms to the j rules of the ASME Code,Section XI. repair or replacement j

~

\

Type Code Symbol Stamp N/A Certificate f Aut ri ion No. N/A Expiration Date N/A Signed mM b/L b-Owner or Owner's Designee, TitleI -

Date 3 '

19 N l V '

CERTIFICATE OF INSERVICE INSPECTION i 1, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Province of Georgle and employed by Hartford Steam boilerInsoection and Insurance Cp, of Hart /brd. Connecticu_t have ;

inspected the components described in this Owner's Report during the period 02/05/97 '

to 3M.OC and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

By signing this certificate, neither the inspector not his employer makes any warranty, expressed or implied, concerning the  !

examinations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall  !

be liable in any manner or any personal injury or property damage or a loss of any kind arising from or connected with this  :

- O Commissions hN 4h7 Inspector's Signatureg National Board, State, Province and Endorsements Date d 19 k l n

v

. UNIGINAL FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required By The Provisions Of The ASME Code Section Ki Traveler # 97007 L , Owner Southem Nuclearoperatng Company Date 10/17197 Name 40 inverness Center Parkway, Birmingham, AL Sheet I of I Plant Vogde Electnc Generabng Plant Unit 1 j 2.

Waynesboro. GA 30830 MwoN 19700541 Address Repair Organization P.O. No., Job No., etc.

1 Work Performed by Nuclear Operakons Maintenance Plant Vogde 3.

Name Address f Identification Of System 12011 Reactor Coolant System l

4. l 1

6. (a) Applicable Construction Code ASME SEC Ill 1977 Edition, Winter 1977 Addenda, N-249-1 Code Case (b)Apphcable Edition of section XI Utilities For Repairs Or Replacements 1999, S. Identification Of Components Repairs Or Replacement Components NAME MANUFACTuR NATIONAL REPAIRED, ASME CODE NAME OF ER BOARD OTHER YEAR REPLACED OR STAMPED OF MANUFACTURER SERIAL NO. lOENTIFICATION BUILT REPLACEMENT (YES OR NO)

COMPONENT NO.

N/A N/A V1 1201-030-H601 1966 REPLACEMENT YES PIPE PULLMAN SUPPORT POWER PRODUCTS

1. Descript\on Of Work Snubber AD 151. serial # $26 was reciaced with AD 151. serial # 427 to succort surveillance tesbna.

3. Test Conducted: Hydrostatic Pneumatic 0 NominaiOPeratins Pressure 0 Other Pressure N/A PSI Test Temp. N/A 'F N/A@

CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code,Section XI. repair or replacement

, Type Code Symbol Stamp N/A ation No. _.N/A Expiration Date N/A CIrtificate fA ..m.__

h m r nwycu py j Signed m MAINTENANCE MANAGER Date lOl PE' 19 /9 Owner or Owner's Designee, Title CERTIFICATE OF INSERVICE INSPECTION t, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Province of Georaia and employed by Hartford Steam Boiler Insoection end Insurence Co of Hartford. Connecticut have th components described in this Owner's Report during the period 05/30 S 7 inspected t3 /M - 7t/ 'yr7 , and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

Zy signing this certificate, neither the Inspector nor his employer makes any warra..ty, expressed or implied, concerning the ixaminations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be li ble in any ma ner for any per nel injury or property damage or a loss of any kind arising from or connected with this f J-f a d- O Commissions d A N7 i

-" Inspector's Signature U National Board, State, Province and Endorsements Date }t ')LY 19 $Y

, OHililNAL.

FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required Cy The itsvisions Of The ASME Code Section XI

~

Traveler # 97036 Southern Nuclearoperahng Company Date . 09Q7/97 Q 1. Owner Name

' 40Invemess CenterParkway. Barmongham, AL Sheet I of 1

2. Plant Vogte Electnc Generenne Plant Unit 1 Waynesboro, GA 30830 MWO# 19700598 Address Repair Organization P.O. No., 'ob No., etc.

3. Work Forformed Yj Nuclear OpereVons Mamtenance Plant Vogde Name Address

4. Identification Of Itystem 1208 i Chemical and Volun e Control System _

5. (a) Applicable Construction Code ASME SEC til 1977 Edition, Mintor 1977 Addenda, N-249-1 Code Case (b) Applicable Edition of section XI utilities For Repairs or Replacements itg

8. Identification Of Components Repairs or Replacement Components l

NAME NAME MANUFACTUR NATIONAL REPAlRED, AsME CODE OF OF ER SOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION SulLT REPLACEMENT (YES OR NO)

NO.

PIPE PULLMAN N/A N/A V1-1208-488-H021 1986 REPLACEMENT YES SUPPORT POWER PRODUCTS

7. Description Of Work Snubber AD-151. senal# 154 was recleced with AD-151. seris!# 416 to succort surveience testina.

Test Conducted: Hydrostatic 0 Pneumatic Nominal Operating PressureO O B. N/A X OtherO Pressure N/A PSI Test Temp. N/A T CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code,Section XI. repair or replacement Type Code Symool Stamp N/A Certificate of rization No. . _ _ _ _ . _ _ . N/A Expiration Date N/A nrrnovr.uWT f Signed 3

o MANTENANCE MANAGER Date 10/ N - it'77 Owner or Owner's Des 40 nee, Title l

CERTIFICATE OF INSERVICE INSPECTlON t, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Province of Georain and employed by Hartford Steam boRet Insoec00n and Insurance Co. of Hartford. Connecticut have the 05/30/97 inspected to /M- M / 47 components.

described and state that to the bestinofthis Owner's and my knowledge Report belief,during thehas the Owner period performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code.Section XI.

By signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the Imaminations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this

.s -

- o L[b Commissions G,/ Mf7 National Board, State Province and Endorsements Inspe(tor's Signatur(

Date Jo-2d te l}7 O

s- 6 64 Z !l % ," m - 1 FORM NIS-2 OWNER'S REPORT _,FOR REPAIRS OR REPLACEMENTS

, As Required By The Provisions of The ASME Code Section XI Traveler # 97040 Southem Nuclearoperakng Company Date 0913a97 (VD '. Owner Name 40Invemens CenterParkway. Brrmangham. AL Sheet 1 of 1

2. Plant Vogne Electnc Generasng Plant Unit 1 Waynesboro. GA 32830 MWO# 19700609 Address Repair Organization P.O. No., Job No., etc.

3. Work performed by Nuclear Ooera00ns Maintenance Plant Vogue Name Address

4. Identification Of System 1301/ Main Steam System

6. (a) Applicable Construction Code ASME SEC fil 1977 Edition, Winter 1977 Addenda, N.249-1 Code Case (b) Applicable Edition of section XI Utilities For Repairs Or Replacements 1989

6. Identification Of Components Repairs Or Replacement Components NAME NAME MANUFACTUR NATIONAL REPAIRED, ASME CODE OF OF ER BOARD OTHER YEAR REPLACILD OR STAMPEQ COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION BUILT REPLACEMENT () E5 OR NO)

NO.

PIPE PULLMAN N/A N/A V1 1301-012-H033 1985 REPLACEMENT YES SUPPORT POWER PRODUCTS 7, Description Of Work Snubber AD-503. serial # 374 was reDInced with AD-503. seria! # 201 to svooort surveRiance testina Also reDioced load stud assembiv.

L Test Conducted: Hydrostatic C Pneumatic 0 NominalOperating Pressure N/A@ Other Pressure N/A PSI Test Temp. N/A 'F CERTIFICATE OF COMPLlANCE We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code,Section XI. repair or replacement Type Code Symbol Stamp N/A Certificate of Authoriza ion o. N/A Expiration Date , N/A Signed  % Wa b b ,

Owner of Owner's Designee, Title <

~

Date l/ $ 19 h ~/ '

v CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vesselinspectors and the State or Province of Georaia and employed by Hartford Steam Coller Inspection and Insurance Co. of Hartford. Connecticut have inspected the components described in this Owner's Report during the period 05/3097 t.3 /=le*9f , and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

Iy signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the

maminations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this adfAA3 inspector's Signature /

.. Commissions b4N7 National Board, State, Province and Endorsements Datej- [a 19 Od' b

i UHlUINAL i

FORM NIS 2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS j As Required By The Pr: visions of The A5ME Code Section XI Traveler # 97042 l 0 , Owner 1 Southem Nuclearoperating Company Date 09/29197 Name -

40 twemess CenterParkway Birmingham. AL Sheet I of I 2.- Plant Vogde Electnc Generabng Plant Unit 1 Waynesboro. GA 30830 MWO# 19700611 Address Repair Organization P.O. No., Job No., etc.

' 3. Work performed by Nuclear Opersbons Maintenance Plant Vogue Name Address

4. Identification Of System 1301/ Main Steam System

6. . (a) Applicable Construction Code ASME SEC til 1977 Edition, Wnter 1977 Addenda, N-249-1 Code Case (b) Applicable Edition of section XI utilities For Repairs or Replacements 19H l . 6. Identification Of Components Repairs or Replacement Components NAME NAME MANUFACTUR NATIONAL REPAIRED, ASME CODE OF OF ER BOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION SUILT REPLACEMENT (YES OR NO)

NO.

PIPE PULLMAN N/A N/A V1-1301-105-H002 1986 REPLACEMENT YES

. SUPPORT POWER -

PRODUCTS 1, Description Of Work Snubber AD-5503. sedal# 260 was reDInced with AD 5503. serial # 177 to succott survemance testina.

( B. Test Conducted:

N/A X Hydrostatic 0 PneumaticD NominalOperating Pressure Pressure OtherO N/A PSI Test Temp. N/A 'F CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code, Section Xt. , repair or replacement Type code Symbol Stamp N/A Certificate of A tion No. .___ _ _ N/A Expiration Date N/A g arrnwvu ny j Signed A . b MAINTENANCE MANAq8 Date Owner or Owner's Designee, Title mR E 19 7 7 CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the national Boird of boiler and Pressure vessel inspe a s and the State or Province of Georoin and employed by Hartford Steam BoIIerInsoection and Insurance Co. of Hartforo Connecticut have inspected the components described in this Owner's Report during the period 05/30/97 to /M.2 4 97 . and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

By signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the xamination6 and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any personalinjury or property damage or a loss of any kind arising from or connected with this i ._

+ a d Commissions $A M97 j inspector's Signatufe National Board, State. Province and Endorsements Date Ad is 97 O

l l

l

ORIGINAL '

i

. FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required By The Provisions Of The ASME Code Section XI

~

Traveler # 97043

%.J 1. Owner Southem NuclearOperating Company Date 09/29t97 Name 40Invemess CenterParkway, Birmingham. AL Sheet I of 1

2. Plant Vogue Electric Generatsng Plant Unit 1 Waynesboro. GA 30830 MWO# 19700612 Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by Nuclear Operations Maintenance Plant Vogue Name Address

4. Identification Of System -

13011 Main Steam System

5. (a) Applicable Construction Code ASME SEC til 1977 Edition, Winter 1977 Addenda, N-2491 Code Case (b) Applicable Edition of section XI Utilities For Repairs Or Replacements 1989

6. Identification Of Components Repairs Or Replacement Components NAME NAME MANUFACTUR NATIONAL REPAlRED, ASME CODE OF OF ER BOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION BulLT REPLACEMENT (YES OR NO)

NO.

PIPE PULLMAN N/A N/A V1 1301106-H002 1986 REPLACEMENT YES SUPPORT POWER PRODUCTS 7, Description Of Work Snubber AD-5503. seriel# 245 was roolaced with AD-5503. senal# 224 to sucoort survemance testino.

B. Test Conducted: Hydrostatic Pneumatic Nominal Operating Pressure N/A X Other Pressure N/A PSI Test Temp. N/A 'F CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPLACEMENT conf arms to the rules of the ASME Code,Section XI. repair or replacement Type Code Symbol Stamp N/A Certificate of Autho : i n No. N/A Expiration Date . N/A

[ Signed p\ g . APPROVED BY MAINTENANcp UAMAhro Date

/

M/ M 19 D Owner or Owner's Designee, Title ~

CERTIFICATE OF INSERVICE INSPECTION

1. the undersigned, holding a valid cortunission issued by the national Board of boiler and Pressure vesselinspectors and the State or Province of Georoia and employed by Hartford Steam BoIIerInsoection and Insurance Co of Hartford. Connecticut have inspected the components described in this Owner's Report during the pet #od 05/30/97 13 /O.1/- 9 7 . and state that to the best of my knowledge and belief, the Owner has performed examinations and taken ctrrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

By signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the

xaminations and corrective measures described in this Owners Report. Furthermore, neither the Inspector not his employer shall be liable in any manner for any perso I injury or property damage or a loss of any kind arising from or connected with this v JI N Commissions NA M97 Inspector's Signature f National Board, State, Province and Endorsements Date /d -N 19 7 i

l l

3 ORIGINAL FORM NIS.2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required By The Provisions Of The ASME Code Section XI

- Traveler # 97044 N. 1. Owner Southem Nuclearoperabng Company Date 09r29197 Name 40 Invemess CenterParkway, Birmingham, AL Sheet I of I

2. Plant Vogue Electnc Generabng Plant Unit 1 Waynesboro. GA 30830 MWO# 19700613 Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by Nuclear Operations Maintenance Plant Vogtte Narne Address

4. Identification Of System 1301/ Main Steam System

5. (a) Applicable Construction Code ASME SEC lit 1977 Edition, Winter 1977 Addenda, N-249-1 Code Case (b) Applicable Edition of section XI Utilities For Repairs Or Replacements 19H

8. Identification Of Components Repairs Or Replacement Coinponents NOR NAME MANUFACTUR NATIONAL REPAIRED, AS'AE CODE OF OP ER BOARD OTHER YEAR REPLACED OR F.TA MPED COMPDNENT MANUFACTURER SERIAL NO. IDENTIFICATION BUILT REPLACEMENT (YES OR NO)

NO.

PIPE PULLMAN N/A tWA V1-1301-107-H003 1986 REPLACEMENT YES SUPPORT POWER PRODUCTS

7. Description Of Wask Snubber AD 12501. serial # 23 was reolaced with AD-12501. sen'ai# 118 to sucoort surveRIance teshna.

p i s. Test Conducted: Hydrostatic Pneumatic Nominal Operating Pressure N/A@ Other Pressure N/A PSI Test Temp. N/A 'F CERTIFICATE OF COMPLlANCE We certify that the statements made in the report are correct and this REPLACCMENT conforms to the rules of the ASME Code,Section XI. repair or replacement Type Code Symbol Stamp N/A Certificate of Atth zation No. . _ _ _ . _ _ . N/A Expiration Date N/A y arrnvvcupy /

Signed N u MAINTENANCE MANAGER oate /0/22. 19 D Owner or Owner's Designee, Title CERTIFICATE OF INSERVICE INSPECTION I, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vesselinspectors and the State or Province of _ Georoie and employed by Hartford Steam BollerInspection andInsurance Co. of Hartford. Connecticuf have inspected the components described in this owner's Report during the period 05/30/97 to / 6 2t/~ 9 7 . and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

By signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the examinations and corrective measures described in this Owners Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any pe 1 injury or property damage or a loss of any kind arising from or connected with this

% [' / Ad7 Commissions M N7 inspector's Signature [ National Board, State Province and Endorsements Date /b 2 19 N O]

L

E . UHililNAL i I

FORM NIS-2 OWNER'S REPORT FOR REPAlRS OR REPLACEMENTS

, As Rsquired By The Provision 2 Of The ASME Code Section XI i

Traveler # 97057

1. Owner Southem NuclearOperapng Company Date 09129/97 Name 40invemess Center Parkway. Birmingham. AL )

Sheet I of I i

3. Plant Vogtle Electric Generabng Plant Unit 1 Waynesboro. GA 30830 MWO# 19700627 Address Repair Organization P.O. No., Job No., etc. j

3. Work Performed by Nuclear Operakons Maintenance Plant Vogde Name Address I

4. Identification Of System 1301/ Main Steam System i

8. (a) Applicable Construction Code ASME SEC til - ff77 Edition, winter 1977 Addenda, N-249-1 Code Case '

(b) Applicable Edition of section XI Utliities For Repairs Or Replacements 1919

8. Identification Of Components Repairs Or Replacement Components WAME NAME MANUFACTUR NATIONAL REPAIRED, AsME CODE OF OF ER BOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION SUILT REPLACEMENT (YES OR NO)

NO.

PIPE PULLMAN N/A N/A V1 1301-137.H004 1906 REPLACEMENT YES SLIPPORT POWER PRODUCTS _

1. Description Of Work Snubber AD-151. serla!# 485 was teolaced with AD-151. serialM 709 to supoort survdan_ge testina.

O 8. Test conducted: Hydrostatic C Pneumatic Nominal Operating Pressure N/A X Other Pressure N/A PSI Test Temp. N/A *? 1 CERTIFICATE OF COMPLIANCE l We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code,Section XI. repair or replacement Type Code Cymbol Stamp N/A Certificate of Auth Iz n No. _ _ _ _ N/A Expiration Date N/A AtTHuytu pT /

Signed '

& MAINTENANCE MANAGER Date

' Owner or Owner's Designee, Title

/fW2 is D CERTIFICATE OF INSERVICE INSPECTlON 1, the undersigned, holding a valid commission issued by the national Board of beller and Pressure vessel inspectors and the State or Province of Georain and employed by Hertford Steam boite!Jns.pection andInsurance Co of Hartford. Connecticut have inspected the components described in this Owner's Report during the period 05/30'97 to /B. N -97 . and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corre'ctive measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

By signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the examinations and corrective rneasures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be 11 le in any manner for any per al injury or property damage or a loss of any kind arising from or connected with this G c e d$<P Commissions M YM inspector's Signature / National Board, State. Province and Endorsements Date /8 -k 19 N fO t

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ORIGINAL ,

l FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS j As Required Cy The Provisions of The ASME Code Section XI

! . Traveler # 97064

1. Owner Southem Nuclearoperatina Company Date 1W2187 Name 40 Invemess Center Parkway, Birmingham, AL Sheet I of I

2. Plant Vogtle Electric Generating Plant Unit 1 l Waynesboro, GA 30830 MWO# 19700355 i

Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by Nuclear Operadons Afalntenance Plant Vogtle Name Address

4. Identification Of System _

1302 / AuxRiary Feedwater System

6. (a) Applicable Construction Code ASME SEC 111 1977 Edition, Winter 1977 Addenda, N/A Code Case (b) Applicable Edition of section XI Utilities For Repairs Or Replacements 1SH

8. Identification Of Components Repairs Or Replacement Components NAME NAME MANUFACTUR NATIONAL REPAIRED, ASME CODE OF OF ER DOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION BUILT REPLACEMENT (YES OR NO)

NO.

1302 PIPING PULLMAN N/A N/A 1K5-1302-1 f 6-01 1967 REPLACEMENT YES SYSTEM POWER 1K5-1302116-01 PRODUCTS

1. Description Of Work Redaced boluna on ddna Manoes located vostream of valve 1-1302-U4-137 on Rne 116 and vostream of valve _1:

1302-U4-139 on kne 118. This redecement was comdeted under Sechon XI Travelers 97064 and 97065.

B. Test Conducted: Hydrostatic Pneumatic Nominal Operating PressureO N/A@ OtherO Pressure N/A PSI T63t Temp. N/A 'F CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are corract and this REPLACEMENT conforms to the rules of the ASME Code,Section XI. repair or replacement Type Code Symbol Stamp N/A Certificate of uthort ade No. N/A Expiration Date N/A I Signed -

.' M k@ [ loDate Il 19 h ')

\ Dwner or Owner's Designee, Title /

CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Province of Georaia and employed by Hartford Steam boller InscecVon and Insurance Q_c, o of Hartford. Connectcut have inspected the components described in this Owner's Report during the period 03/10/97 to //25 97 and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

By signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the examinations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this

.O Commissions NA N7 inspector's Signatured National Board, State, Province and Endorsements Date }l- 25 19 9/

I

ORIGINAL FORM NIS 2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS ,. 4 e 0 As Required By The Provisions Of The ASME Code Section XI gu*S

• M Traveler # S34N- Nb S hl'

1. Owner Southern Nuclear Operating Company Date 10129/97 Name 40 Inverness Center Paritwer, Birmingham, Ala. Sheet t of I

2. Piant Vogtie Electric Generating Plant Unit 1 Waynesboro, GA 30830 MWO# 19600906 Address Repair Organization P.O. No., Job No., etc.

3. Work Performed by NucAserOperatJons Alaintenance Plant Vogtle Name Address

4. Identification Of System 1217 / Auxillary Component Cooling Water System E. (a) Applicable Construction Code ASME SEC #l 1974 Edition, Summer'75 Addenda, 18f6.2,1835.f Code Case (b) Applicable Edition of section XI Utilities For Repairs or Replacements 331. Code Case N4161

8. Identification Of Components Repairs Or Replacement Components NAME NAME MANUFACTURER NATIONAL l REPAIRED, ASME CODE OF OF SERIAL BOARD OTHER YEAR REPLACED OR STAMPED COhrONENT MANUFACTURER NO. NO IDENTIFICATION BUILT REPLACEMENT (YES OR NO)

SWING ANCHOR / E Z8101-1 N/A 11217U4087 1997 REPLACED YES l CHECK DARLING l VALVE VALVE CO \

1. Description Of Rectaced check valve due leakaae by the seat.

Work

)

Test Conducted: Hydrostatic 0 Pneumatic Nominal Operating Pressure x Code Case N 416-1 i N/A Other Pressure N/A PSI Test Temp. N'A T CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the ASME Code,Section XI. repair or replacement Type Code Symbol Stamp N!A Ca.rtificate of Apth r ion No. N/A Expiration Date N/A Signed hW G 'date OD 19 D Owner or Owner's Designee, Title ( l CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Province of Georcia and employed by Hartford Steam boiler Insoection and Insurance Co. of Hartford. Connecticut l have inspected the components described in this Owner's Report during the l period to //./O.97 l and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described

( in this Owners Report in accordance with the requirements of the ASME Code, Section XI.

By signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the examinations and corrective measures described in this Owners Report. Furthermore, neither the Inspector nor his employer shall be i ble in any marner for any rsonal injury or property damage or a loss of any kind artsing from or connected with this

. M & -r Commissions 64M97 inspectcir's Signature f National Board. State, Province and Endorsements Dnie //-# 1997 i

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i. ..

l . FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required By The Prrvisions Of The ASME Code Section XI l

Traveler # 97077

~

Q 1. Owner Southern NuclearOnera0ne Company Date 10tf341 U N*"*

40invemess CenterParkway, Birminoham, AL l Sheet 1

• of 1

2. Plant Vocue Electric Generatine Piant Unit 1 Waynesboro, GA 30930 MWO# ___

f 9002924, f 9002023 and PO# 7031332 Address Repair Organization P.O. No., Job No., etc.

3. Work performed by Nuclear Operadons Maintenance Plant Vogtle l Name Address 1

4. Identification Of System 120f / Reactor Coolant System

9. (a) Applicable Construction Code ~ ASMESECNI 197f Edition, Winter 1972 Addenda, N/A Code Case l (b) Applicable Edition of section XI Utilities For Repairs Or Replacements 19tt j 9. Identification Of Components Repairs Or Replacement Components l

NAME NAME MANUFACTUR NATIONAL REPAIRED, ASME CODE f

OF OF ER BOARD OTHER YEAR REPLACED OR STAMPED l COMPONENT MANUFACTURER SERIAL NO. IDENTIFICATION BUILT REPLACEMENT (YES OR NO) l NO.

j SAFETY CROSBY VALVE N59994 00- N/A fPSV.0010A 1979 REPLACEMENT YES VALVE & GAGE CO. 0036 l

I l 7, Description Of Work Valve notale was realaced Valve nonste was hwdrostaticallv tested by the ;-J_ _;_=or to 4679 asl. Asustem

^

leahace test Visual =- --__- _ T was conducted after nozzle rectacement under WOC 19902923 and Test VerfliceWon Form # 97009,

9. Test Conducted: Hydrostatic Pneumatic 0 NominalOperating Pressure X N/AC OtherO Pressure N/A PSI Test Temp. N/A 'F i

CERTIFICATE OF COMPLIANCE i We certify that the statements made in the report are correct and this REPLACEMENT conforms to the rules of the AS,ME Code, Section XL repair or replacement

Type Code Symbol Stamp N/A CIrtificate of Author a No. N/A Expiration Date N/A

) S n.dP

I L) k Uwner or Owner's Desiones,1st19f D n /m ,9 v' CERTIFICATE OF INSERVICE INSPECTION 1 the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Pr:vince of Georcia and employed by Hartibrd Steam boiler IneDection and Insurance Co. of Hartford. Connecticut have inspected the components described in this Owner's Report during the period OS/f697 13 // M 4 7 , and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

Iy signing this certificate, neither the inspector nor his employer makes any warranty, expressed or impiled, concerning the Imaminations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this lbo *, 2 Commissions MN inspector's Signature j7 National Board, State Province and Endorsements Dete- //W 19 97

ORIGINAL 7I

• FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required Cy The Pr: visions Of The ASME Code Section XI Traveler # 97080

1. Owner Southem Nuclearoneratina Company Date 1W29197 N.me 40 inverness CenterParinway, Birminoham, AL Sheet I of 1

2. Piant Vo06e Electric Generoung Plant Unit 1 Waynesboro, GA 30830 - MWO# 19601073 Address Repair Organization P.O. No., Job No., etc.

3. Work performed by Nuclear Operations Maintenance Piant voette Name Address

4. Identification Of Syotem 1204 / Safety injeckon System

- 5. (a) Apphcable Construction Code ASME SEC111 1924 Editiori, Summer 1974 Addenda, 1553-1, 1649 Code Case (b) Applicable Edition of section XI Utilities For Repairs Of Replacements 199 i

S. identification Of Components Repairs Or Replacement Components NAME NAME MANUFACTURER NATIONAL REPAIRED. ASME CODE OF OF SERIAL BOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUPACTURER NO NO IDENTIFICATION BUILT REPLACEMENT (YES OR NO)

VALVE WESTINGHOUSE 06001CS990000 W18907 1 1204-U6-127 1979 REPAIR YES ELECTRO. 0000ST40012 MECHANICAL DIV.

7.' Description Of Work Comoleted body-to-bonnet sealweld on valve amer oerforrruna valve maintenance.

B. Test conducted: Hydrostatic O N/A@ Other PneumaticC Nominal Operating Pressure 0 Pressure N/A- PSI Test Temp. N/A 'F CERTIFICATE OF COMPLIANCE We certify that the statements made in the report are correct and this REPAIR conforms to the rules of the ASME Code,Section XI. repair or replacement Type Code Symbol Stamp N/A Y Certificate of Authortz son N/A

. Expiration Date N/A Signed I ,co St 2 krt_. Date _ U Y 19 7 )

Owner or Owner's Designee. Title J CERTIFICATE OF INSERVICE INSPECTION

( l, the undersigned, holding a valid commission issued by the national Board of boiler and Pressure vessel inspectors and the State or Province of Georola and employed by Hartford Steam Boller insDection and Insurance Co. of Hartford. Connecticut have inspected the components described in this owner's Report during the period 050897 to /. 7 9 F .

and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owners Report in accordance with the requirements of the ASME Code,Section XI.

By signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the

sammations and corrective measures described in this Owners Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any pers al injury or property damage or a loss of any kind arising from or connected with this

% s W /e Commissions 684/97 inspector's Signature / '

National Board, State, Province and Endorsements Date /= 7 19 $ )(_

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c-ORIGINAL i FORM NIS-2 OWNER'S REPORT FOR REPAIRS OR REPLACEMENTS As Required By The Provisions Of The ASME Code Section XI Traveler # 97084 V - ,

1. Owner Southern Nuclear Operating Company Date 1013019 7 \

Name 40 invemess Center Parkway, Birmingham, Ala. Shett 1 of 1 l

2. Plant Vogtle Electric Generatir'a Plant Unit 1 l Waynesboro, GA 308J0 MWO# 19701185 i Address Repair Organization P.O. No., Job No., etc. j

3. Work Performed by NuclearOperations Afaintenance Plant Vogtle Name Address

4. Identification Of System 1204 / RESIDUAL HEAT REMOVAL SYSTEM

6. (a) Applicable Construction Code ASME SEClli 1974 Edition, Summer '75 Addenda, N-154(f 79f), N-30 Code Case (b) Applicable Edition of section XI utilities For Repairs Or Replacements 198J

6. Identification Of Components Repairs Or Replacement Components NAME NAME MANUFACTURER NATIONAL REPAJRED, ASME CODE OF OF SER!AL BOARD OTHER YEAR REPLACED OR STAMPED COMPONENT MANUFACTURER NO. NO. IDENTIFICATION BUILT REPLACEMENT (YES OR NO)

ROCKWELL BE-561 N/A 11204X4203 1981 REPAIR YES VALVE INTERNATIONAL i

l' 7, Description Of BONNET TO BODYSEAL WELD Work