ML20072Q796
| ML20072Q796 | |
| Person / Time | |
|---|---|
| Site: | South Texas  |
| Issue date: | 08/24/1994 |
| From: | Haning J, Timmaraju S, Younger J HOUSTON LIGHTING & POWER CO. |
| To: | |
| Shared Package | |
| ML20072P216 | List: |
| References | |
| NUDOCS 9409120230 | |
| Download: ML20072Q796 (150) | |
Text
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O SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION 2RE03 INSERVICE INSPECTION
SUMMARY
REPORT FOR WELDS, STEAM GENERATOR TUBING, AND COMPONENT SUPPORTS of the O
SOUTII TEXAS PROJECT ELECTRIC GENERATING STATION - UNIT 2 P.O. Ilox 289 Wadsworth, Texas 77483 Owner:
Houston Lighting and Power Company City Public Service Board of San Antonio Central Power and Light Company City of Austin Address:
P.O. Box 1700 Houston, Texas 77001 Commercial Operation:
JUNE 19,1989 O
Issue Date:
AUGUST 1994 PDR DD K 050 0 99 G
_ _ _ _ _ _ - _ _ _ - _ _ _ _ _ ~
O 2REo31NSERv1Ce 1NSPECT1ON sUMmARv REeORT FOR WELDS, STEAM GENERATOR TUBING, AND COMPONENT SUPPORTS of the SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT NO. 2 USNRC DOCKET NO.: 50-499 OPERATING LICENSE NO.: NPF-80 C05151ERCIAL OPERATION DATE: JUNE 19,1989 f
Prepared by:
^~7 e Od'e'/ 74-J C. Yo6'nger' Date f
ISI Engineer - Welds & Component Supports 6/22. /fg Prepared by:
S. /_
%A J.(ll IIaning d
Date ISI Engineer - Steam Generator Tubing Reviewed by:
~,mn%'
57' L / W S. Timmaraju Da'te Supervising Engineer - ISI Group
/ V Approved by:
'~
h!. Aleier '
Date Afanager - Engineering Programs
(
TABLE OF CONTENE 1.0 2RE03
SUMMARY
REPORT Page 1.1 Introduction 1-1 1.2 Scope of Summary Report 1-1 2.0 WELD EXAMINATIONS 2.1 Introduction 2-1 2.2 Scope of Examinations 2-1 2.3 Personnel, Procedures, and Equipment 2-3
(
2.3.1 Personnel Qualifications 2-3 l
2.3.2 Examination Procedures 2-3 l
2.3.3 Equipment 2-3 2.3.4 Materials 2-3 l
2.3.5 Calibration Blocks 2-4 2.4 Summary of Examinations 2-4 l
l 2.4.1 Examination Methods 2-4 2.4.2 Augmented Examinations 2-4 2.4.3 Data Comparison 2-5 2.4.4 Additional and Successive Examinations 2-5 l
l l
2.5 Examination Results and Corrective Actions 2-5 2.6 Certification of Inspections 2-6 i
Appendix 2-A Summary of Examinations l
Appendix 2-B Personnel Appendix 2-C HL&P Procedures Appendix 2-D ISI Examination Limitations Appendix 2-E Owner's Report for Inservice Inspections - NIS-1 Forms I
TABLE OF CONTENE (cont'd) 3.0 STEAM GENERATOR TUBING EXAMINATIONS 3.1 Introduction 3-1 3.2 Scope of Examinations 3-1 3.3 Personnel, Procedures, and Equipment 3-2 3.3.1 Personnel Qualifications 3-2 3.3.2 Examination and Analysis Procedures 3-2 3.3.3 Equipment 3-3 3.3.4 Calibration Standards 3-4 3.4 Summary of Examinations 3-4 3.5 Examination Results and Corrective Actions 3-5 3.6 Certification of Inspections 3-8 Appendix 3-A Changes to the ISI Outage Plan Appendix 3-B List of Examination and Data Analysis Personnel Appendix 3-C Tubes Examined by MRPC Appendix 3-D Flaws with Tube Wall Thickness Reduction Appendix 3-E Dings and Dents Appendix 3-F Owner's Report for Inservice Inspections - NIS-1 Form O
ii
0 4
s 4.0 COMPONENT SUPPORT EXAMINATIONS i
4.1 Introduction 4-1 4.2 Scope of Examinations 4-1 4.3 Personnel and Procedures 4-2 4.3.1 Personnel Qualifications 4-2 4.3.2 Examination Procedure 4-3 4.4 Summary of Examinations 43 4.4.1 Examination Results and Corrective Actions 4-3 4.4.2 Additional and Successive Examinations 4-4 4.5 Certification of Inspections 4-4 Appendix 4-A Summary of Examinations j
Appendix 4-B Personnel
'f
- Appendix 4-C Owner's Report for Inservice Inspections - NIS-1 Forms s
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1
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l O
iii
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l.0 2RE03
SUMMARY
REPORT 1.l '
Introduction This Summary Report describes Houston Lighting & Power Company's (HL&P) inservice inspection (ISI) of selected Class 1,2, and 3 components of the South Texas Project Electric Generating Station, Unit 2 (STPEGS-2) performed during of the third refueling outage (2RE03) of STPEGS-2 from February 3,1993 to May 30,1994. The STPEGS ISI program for welds and component supports is scheduled in accordance with Program B of the American Society of Mechanical Engineers (ASME)Section XI Code " Inservice Inspection of Nuclear Power Plant Components". The STPEGS ISI Program for steam generator tubing is scheduled in accordance with STPEGS Technical Specification 3/4.4.5.
The first ten year inspection interval of STPEGS-2 began June 19, 1989. Because STPEGS-2 was out of service continuously for 16 months, the inspection interval will be extended for a period equivalent to the 2RE03 outage in accordance with IWA 2400(c) of ASME Section XI. This would extend the inspection interval to October 19,2000. The second inspection period began June 19,1992 and will extend to October 19,1997. The ISI summarized herein constitutes the third ISI performed during the first ten year inspection interval and the first ISI of the second inspection period of STPEGS-2. Figure 1 of this Section depicts the first ten year interval and Periods 1 through 3 for STPEGS-2.
The percentages completion of examinations performed thragh 2RE03 for STPEGS-2 O-welds and component supports are also summarized in Figure 1.
The STPEGS-2 ISI program for the first inspection interval is described in the Ten Year ISI Plan previously filed with the Nuclear Regulatory Commission (NRC) and the State of Texas. The STPEGS-2 ISI program was developed and is being implemented in accordance with 10CFR50.55a, the 1983 Edition of Section XI Code with the Summer 1983 Addenda, and other regulatory and Code bases as specified in the Ten Year ISI Plan.
This Summary Report satisfies the reporting requirements of IWA-6000 of the Section XI Code for welds, steam generator tubing, and component supports.
1.2 Scope of Summary Report This Summary Report describes the ISI examinations performed up through 2RE03 on welds (Section 2), steam generator tubing (Section 3), and component supports (Section 4).
Each of these sections describes the scope of examinations performed; describes the personnel, procedures, and equipment utilized for the examinations; provides a summary of the examinations, examination results, and corrective actions; and includes copies of the examination certification (NIS-1) forms.
The ISI examinations performed on Class 1 and 2 welds and other examination areas (e.g.,
bolting) are described in Section 2 of this Summary Report. These examinations were performed in accordance with Subsections IWB and IWC of Section XI and other bases as 1-1
specified in the Ten Year ISI Plan. ISI examinations performed on steam generator tubing are described in Section 3. These examinations were performed in accordance with IWB (Examination Category B-0), STPEGS Technical Specifications 4.4.5, and other bases as specified in the Ten Year ISI Plan. The ISI examinations performed on Class I,2, and 3 component supports and Class 3 integral attachments are described in Section 4. These examinations were performed in accordance with Subsection IWF (Class I,2, and 3 supports) and Subsection IWD (Class 3 integral attachments) of Section XI and other bases as specified in the Ten Year ISI Plan, l
s O
1-2
0 f
,f U
V ISI WELDS AND COMPONENT SUPPORTS PROGRAMS FIRST 10-YEAR INSPECTION INTERVAL CALENDAR UNIT 2 Year 19 89 19 90 19 91 19 92 19 93 19 94 19 95 19 96 19 97 19 93 19 99 20 00 Sp l$mrl Fo5 Sp lbl Fan War l SplSerl Fa8 War l $p l 5mel Fd Werf Sp l5mel Fn5 Sp l5mrl Fd War l Sp lb s. l s=l Fd We,lsplwlF.s We,l sp l s l r.n We,lsplwlFa5 werl $p Serl Fa5 War Fna We We we, r
Period m
PERIOD 1 PERIOD 2 PERIOD 3 oce y
Outage #
l CO - Commercial Operation E01 - End of Interval XO - Estended outage from February 3,1993 to May 30,1995 PERIOD 1 Minimun 16 %
PERIOD 2 Minimun 50 %
PERIOD 1 Maximum 34 %
PERIOD 2 Maximum 67 %
l Refuelig Outare 3
4 5
Cum PERIOD 1 PERIOD 2
SUMMARY
comp.
(In Progress) comp.
-comp.
comp.
comp.
Welds Program 30 %
Welds Program to %
o%
o5 40 s Comp. Spts Program 25 %
Supports Program i 13 %
0%
o5 3a 5
~
2.0 WELD EXAMINATIONS 2.1 Introduction ISI of STPEGS-2 Class 1 and 2 welds and components within the Welds Examination Program was performed between February 17 and December 15,1993. These examinations constitute the third ISI (the first ISI of the second period) of the first inspection interval for the Welds Examination Program for STPEGS-2.
This section of the Summary Report documents the examinations performed by HL&P Quality Control (OC) nondestructive examination (NDE) personnel in accordance with the following documents:
(1)
"First 10-Year Long-Term Inservice Examination Plan for the South Texas Project Electric Generating Station, Unit 2" (LTP),
l (2)
" Examination Plan for the 1993 - 2RE03 Inservice Inspection at the South Texas Project Electric Generating Station, Unit 2" including changes made during the outage (Outage Plan).
The Long-Term Plan (LTP) provides a detailed description of the rules for exemption, i
1
(
selection, allocation, and scheduling of Class 1 and 2 welds and examination areas for ISI.
The 1993 Examination Plan is an individual Outage Plan for implementing ISI weld examinations as scheduled in the LTP. The Outage Plan references the applicable NDE procedures used for the examinations.
2.2 Scope of Examinations I
1 NDE was performed on a total of seventy-two (72) selected Class 1 and Class 2 components and examination areas as contained in the Outage Plan. Any deviations or changes were documented as Examination Plan Changes to the Outage Plan. Selection of these components and examination areas was based on the LTP allocation and scheduling requirements for the third refueling outage.
Class 1 A total of forty-eight(48) examinations were performed on the following Class 1 components and examination areas:
Vessels Reactor Vessel Steam Generator 2B (Primary Side)
O 2-1
1 Pipine Reactor Coolant System Residual Heat Removal System
\\
Class 2 2
A total of twenty-four(24) examinations were performed on the following Class 2 components and examination areas:
]
Vessels Excess Letdown Heat Exchanger 2A 1
Pipine Feedwater System Safety Injection System A complete list of the components and examination areas is contained in Appendix 2-A.
Class 1 and Class 2 weld identification figures for the above components and examination areas are contained in the LTP.
j These examinations constitute the following percentages of completion for Class 1 and N
Class 2 components during the first inspection interval:
Cumulative -
2RE03 (1st Intervan Class 1(IWB) 15 %
44 %
Class 2(IWC) 8%
38 %
2.3 Personnel, Procedures, and Equipment 2.3.1 Personnel Qualifications HL&P OC NDE personnel or contractors certified in accordance with the HL&P Procedure for qualification and certification of NDE personnel performed all examinations.
In addition, Level Il examiners performing ultrasonic examinations on austenitic piping welds have been qualified by Electric Power Research Institute in detection of intergranular stress corrosion cracking. A list of all personnel who performed examinations during 2RE03 and their NDE certification level for each applicable examination technique is contained in Appendix 2-B.
2.3.2 Examination Procedures NDE activities were performed using visual (VT), liquid penetrant (PT), magnetic particle (MT), and ultrasonic (UT) techniques in accordance with HL&P OC NDE procedures.
2-2
The NDE procedures were written to conform to the requirements of the applicable sections of the ASME Code. A list of applicable NDE procedures is provided in Appendix 2-C.
2.3.3 Equipment Various equipment was used during the ISI to perform the examinations of the selected component welds and examination areas. Major equipment consisted of the following:
Krautkramer Branson ultrasome mstruments Ultrasonic transducers AC electromagnetic yokes MT calibration block Pyrometers / Thermometers 2.3.4 Materials NDE materials utilized during 2RE03 weld examinations included penetrant and magnetic particle materials, and ultrasonic couplant. All materials contacting an austenitic examination surface were tested and certified to be within acceptable sulfur and halogen limits specified in the STPEGS Expendable Material Control Program.
O~
2.3.5 Calibration Blocks Pipe and vessel calibration blocks were utilized to calibrate the UT instruments prior to examination of the selected welds. Applicable calibration blocks are noted in the Examination Summary Tables (Appendix 2-A). Drawings for calibration blocks are included in the LTP.
2.4 Summary of Examinations 2.4.1 Examination Methods The following examination methods were conducted in accordance with HL&P OC NDE procedures:
VT Examinations VT-1 examinations were performed on bolting.
VT-3 examination was performed on the Reactor Vessel (RV) Interior PT Examinations PT examinations were performed on RV Closure Head studs, piping welds, and integrally welded attachments.
2-3
O MT Examinations MT examinations were performed on a RV Closure Head weld, RV Closure Head studs, piping welds, and integrally welded attachments.
UT Examinations UT examinations were performed on Class 1 and 2 components, including vessels, bolting, austenitic piping, and ferritic piping. Various techniques were used to perform the UT examinations, depending on classification, material type, and weld thickness.
2.4.2 Augmented Examinations In addition to the ISI requirements of Section XI for Class 1 piping and ASME Code Case N-408 for Class 2 piping, the following augmented ISI program was implemented during this outage:
Augmented ISI - Break Exclusion Zone Augmented ISI - IEB 79-17 These augmented programs are described in the LTP and the affected examination areas are noted in the " Remarks" column of the Examination Summary Tables.
2.4.3 Data Comparison In accordance with IWB-3121 of Section XI, the examination results were compared with the recorded NDE results of the preservice inspection (PSI). There were no prior inservice examinations on the areas examined during this outage.
If flaws were recorded in the selected component weld or examination area during previous examinations and dispositioned as acceptable, these flaws were verified during this ISI. All such flaws were observed and verified during this ISI.
2.4.4 Additional and Successive Examinations If examinations reveal indications that exceed allowable indications standards, additional examinations are required as prescribed in IWB-2430 and IWC-2430. No additional examinations (IWB-2430 or IWC-2430) were required during this outage.
Successive examinations are required if flaw indications are evaluated in accordance with IWB-3122.4 and the component qualifies as acceptable for continued service. No successive examinations (IWB-2420 or IWC-2420) will be scheduled as a result of examinations performed during this outage.
2-4
i O
2.5 Examination Results and Corrective Actions Examination area coverage was provided, to the extent practical, in accordance with the requirements of ASME Section XI and Code Case N-408. In those cases where physical conditions of the component restricted examination of the required area, the amount of coverage achieved was assessed. Appendix 2-D, ISI Examination Limitations, contains a detailed account of all examination limitations (UT, PT, and MT) encountered during 2RE03 weld examinations.
All UT indications determined to be recordable, regardless of signal amplitude, were investigated to determine the nature of the reflector. Indications determined to be other than geometry were evaluated to ASME Section XI criteria. The UT examinations revealed Code-allowable indications in a Reactor Vessel Closure Head, and Reactor Coolant piping weld.
No reportable indications were detected by volumetric (UT), surface (PT and MT), or visual (VT) examinations.
l 2.6 Certification of Inspections ASME Section XI NIS-1 forms, " Owner's Report for Insen' ice Inspections", have been
(
prepared to certify the STPEGS-2 weld ISI examinations described in this section of the Summary Report. The STPEGS-2 weld ISI examinations have been certified by our ANil, Factory Mutual Engineering Association, on the NIS-1 forms included in Appendix 2-E.
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APPENDIX 2-A
SUMMARY
OF EXAMINATIONS
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
1 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS REACTOR PRESSURE VESSEt N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R "CAllBRATION BLOCK" CIRCUWERENTI AL CLOSURE HEAD WELDS (FIG NO A-RPV-3A) 000600 RPV2-101-101 B-A MT NDEP 7.1 R3 X - EXAMINED 33%: FROM L=182(STUD HOLE CLOSURE HEAD TORUS TO FLANGE B1.40 UTOL UTI-024 R0
- - X 21) TO 364(STUD HOLE 35). RG 1.150 UTOW X. -
APPLICABLE. CNE LAMINAR INDICATION WAS UT45
- X - EVALUATED AND DETERMINED TO BE UT45T X - - ACCEPTABLE. THIS SAME INDICATION WAS UT60 X - - SEEN DURING PSI AND HAS NDT CHANGE 0.
- CSCL-92**
UT60T X - -
000700 RPV2-103-101 B-A UTOW UTI-024 R0 X - EXAMINED 50%: FROM L=229(STUD HOLE CLOSURE HEAD DOME TO CLOSURE B1.21 UT45
- X X
- 27) TO 458(STUD HOLE 10). RG 1.150 HEAD TORUS UT45T X - - APPLICABLE. CNE UT45 CODE ALLOWABLE UT60
- X -
INDICATION. THIS SAME INDICATION WAS
(
UT60T X - - DETECTED DURING PS! AND HAS NOT CHANGED.
i LIMITED DUE TO PROXIMITY OF LIFT. LUGS AND INSUL. SPT. RING.
"CSCL-90" l
MERIDIONAL CLOSURE HEAD WELDS (FIC ND A-RPV-3A) 002300 RPV2-101-104C B-A UTOW UTI-024 R0 X - RG 1.150 APPLICABLE.
CLOSURE HEAD MERIDIONAL WELD B1.22 U745 X - -
AT 180 DEG UT45i X - -
UT60 X - -
UT60T X - -
"CSCL-90/CSCL-91" 002400 RPV2-101-1040 B-A UTOW UTI-024 RD X - RG 1.150 APPLICABLE.
CLOSURE HEAD MERIDIONAL WELD B1.22 UT45 X - -
AT 270 DEG UT45T X - -
UT60 X - -
l UT60T X - -
"CSCL-90/CSCL-91" l
CLOSURE HEAD BOLTING (FIG NO A-RPV-3A,B)
C05402 2B B-G-1 PT NDEP 6.6 R0 X - -
CLOSURE STUD B6.30 MT NDEP 7.2 RO X - -
\\
UT45(Shee) UTI-015 R1 X - -
UT 60(550e)
X - -
UT60(Prb)
X - -
- CS-45A/CS-45B**
UTSO(Prb) UTI-010 P,0 X - -
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DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
2
['
REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS)
\\
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
I CLASS 1 COMPLETED COMPONENTS r
O ASME O G T SEC XI R E H
SUMMARY
EXAMINATION A?.EA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION B'.0CK**
CLOSURE HEAD BOLTING (FIG NO A-RDV-3A,B) 005405 SB B-G-1 PT NDEP 6.6 RO X - -
CLOSURE STUD B6.30 MT NDEP 7.2 R0 X - -
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X - -
UT60(Prb)
X - -
- CS-45A/CS-45B**
UT80(Prb) UTI-010 RO X - -
l L
005408 BB B-G-1 PT NDEP 6.6 R0 X - -
CLOSURE STUD B6.30 MT NDEP 7.2 R0 X - -
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X - -
UT60(Prb)
X - -
- CS-43A/CS-459**
js b
UT80(Prb) UTI-010 RD X - -
l {V 005411 11B B-G-1 PT NDEP 6.6 R0 X - -
CLOSURE STUD B6.30 MT NDEP 7.2 R0 X - -
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X - -
UT60(Prb)
X - -
- CS-45A/CS-458**
UT80'Prb) UTI-010 R0 X - -
005414 14B B-G-1 PT NDEP 6.6 RD X - -
CLOSURE STUD B6.30 MT NDEP 7.2 RO X. -
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X. -
UT60(Prb)
X - -
- CS-45A/CS-45B**
UT80(Prb) UTI-010 RD X - -
005417 17B B-G-1 PT NDEP 6.6 RO X - -
CLOSURE STUD B6.30 MT NDEP 7.2 R0 X - -
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X - -
UT60(Prb)
X - -
- CS*45A/CS-45B**
UT80(Prb) UTI-010 RO X - -
l DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
3 j
REVISION:
0 INSERVICE 'NSPECTION REPORT - 2RE03 (WELOS)
FIRST INTERVAL, SECOND PERIOD, FIRST CUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS REACTOR PRESSURE VESSEL N
O ASME O C T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H 2 ** CALIBRATION BLOCK **
CLOSURE HEAD BOLTING (FIC NO A-RPV-3A,B) 005420 20B B-G-1 PT NDEP 6.6 R0 X - -
CLOSURE STUD B6.30 MT NDEP 7.2 R3 X - -
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X - -
UT60(Prb)
X
- CS-45A/CS-45B**
UT80(Prb) ' UTI-010 R0 X - -
005423 238 B-G-1 PT NDEP 6.6 R0 X - -
CLOSURE STUD B6.30 MT NDEP 7.2 RO X - -
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X - -
UT60(Prb)
X - -
- CS-45A/CS-45Ba*
UT80(Prb) UTI-010 R0 X - -
005426 26B B-G-1 PT NDEP 6.6 R0 X - -
CLOSURE STUD B6.30 MT NDEP 7.2 RG X - -
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X - -
UT60(Prb)
X --
- CS-45A/CS-453**
UT80(Prb) UTI-010 RD X - -
005429 293 B-G-1 PT NDEP 6.6 R0 X - -
CLOSURE STUD B6.30 MT NDEP 7.2 R0 X
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X - -
UT60(Prb)
X - -
- CS-45A/CS-458**
UT80(Prb) UTI-010 R0 X - -
005432 32B B-G-1 PT NDEP 6.6 R0 X - -
CLOSURE STUD B6.30 MT NDEP 7.2 RO X - -
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X - -
UT60(Prb)
X
- CS-45A/CS-45B-*
UT80(Prb) UTI-010 R0 X - -
... ~..
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
4 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELOS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 1 Cot 1PLETED COMPONENTS REACTOR PRESSURE VESSEL N-0 ASME O G.T SEC. XI R E H
SUMMARY
EKAMIRATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD FROCEDURE C H R ** CAL lBRATION BLOCK **
CLOSURE HEAD BOL11NG (FIG NO A-RPV-3A,B) 005435 358 B-G-1 PT NDEP 6.6 R0 X - -
CLOSURE STUD B6.30 MT NDEP 7.2 R0 X. -
UT45(Shoe) UTI-015 R1 X - -
UT60(Shoe)
X - -
UT60(Prb)
X - -
- CJ-45A/CS-458**
UT80(Prb) UTI-010 R0 X - -
005602 2B B-G-1 VT-1 NDEP 9.3 R1 X - -
CLOSURE WASHER B6.50 i
i 005605 58 B-G-1 VT-1 NDEP 9.3 R1 X - -
CLOSURE WASHER B6.50 1
1 0056C8 83 B-G-1 VT-1 NDEP 9.3 R1 X - -
CLOSURE WASHER B6.50 005611 11E B-G-1 VT-1 NDEP 9.3 R1 X - -
CLOSURE WASHER C5.50 005614 148 B-G-1 VT-1 NDEP 9.3 R1 X - -
CLOSURE WASHER B6.50 005617 17B B-G-1 VT-1 NDEP 9.3 R1 X - -
CLOSURE WASHER B6.50 005620 203 B-G-1 VT-1 NDEP 9.3 R1 X - -
CLOSURE WASHER B6.50
_ _ _ -.. _. _ _ _ _ _ _ _... ~ _ _
DAT E: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
5 REv!SION:
-0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF) s, s
CLASS 1 COMPLETED COMPONENTS REACTOR PRESSURE VESSEL N
O j
ASME O G T.
]
SEC.'XI R E H.
SUMMARY
EXAMINATION AREA CATGY EXAM E.0 E REMARKS NUMBER IDENTIFICATION ITEM NO HETHOD PROCEDURE C H R
- CAllBRATION BLOCK **
CLOSURE HEAD BOLTING (FIG NO A-RPV 1A,B) 005623 238 B-G-1 VT-1
.NDEP 9.3 R1 X - -
CLG3URE WASHER B6.50 005626 26B
-B-G-1 VT-1 NDEP 9.3 R1 X - -
CLOSURE WASHER B6.50 005629 293 B-G-1 VT-1 NDEP 9.3 R1 X
CLO5URE WASHER B6.50 f
005632 328 B-G-1 VT-1 NDEP 9.3 R1 X - -
CLOSURE WASHER B6.50 005635 359 B-G-1 VT-1 NDEP 9.3 R1 X - -
CLOSURE WASHER B6.50 l
, VESSEL INTERIOR (FIG NO A-RPV-1, 2) 006200 VESSEL INTERIOR B-N-1 VT-3 NDEP 9.3 R1 X - - EXAMINED ACCESSIBLE SURFACES: SEALING B13 10 SURFACE AND OUTLET N022LES.
1 l
I DAT E: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
6 i
REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS) l FIRST INT ERVAL, SECOND PERIOD, FIRST OUTAGE (93RF) l CLASS 1 COMPLETED COMPONENTS STEAM GENERATOR 2B (PRIMARY SIDE) (FIGURE A-SG-2)
N O
ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
HEAD WELOS 016000 SG-28-SR1 B-B UTOW UTI-004 R1 X - NO UT FROM THE SUPPORT RING SIDE CHANNEL HEAD CAP TO SUPPORT B2.31 UT45 UTI-017 R1 X - - DUE TO SUPPORT RING CONFIGURATION.
WING UT45T X - -
UT60 X - -
- CSCL-89**
UT60T X - -
l 016100 SG-23-SR2 B-B UTOW UTI-004 R1 X - LIMITED UT FROM THE TUBE PLATE SIDE SUPPORT RING TO TUBE PLATE B2.40 UT45 UTI-017 R1
- 'X
- DUE TO PROXIMITY OF WELDED PLATES. NO UT45T X - - UT FROM THE SUPPORT RING SIDE DUE TO OT60
- X - SUPPORT RING CONFIGURATION.
UT60T X - -
- CSCL-89**
N0ZZLE TO VESSEL 10WER HEAD WELDS i
j 016200 SG-23-IN B-D UTOW UTI-004 R1 X - LIMITED UT FRCM THE N0ZZLE SIDE DUE INLET N0ZZLE TO CHANNEL HEAD B3.130 UT45 UTI-017 R1 X - - TO N0ZZLE CONFIGURATION AND FR0r. THE CAP UT45T X - - HEAD DUE TO PROXIMITY OF VIBRATION UT60 X - -
SENSCR INSTRUMENTATION BOX.
UT60T X - -
- CSCL-69**
016300 SG-23-ON B-D UTOW UTI-004 R1 X - LIMITED UT FROM THE N0ZZLE $1DE DUE l
CHANNEL HEAD CAP TO CUTLET B3.130 UT45 UTI-017 R1 X - -
TO N0ZZLE CONFIGURATIGN AND FROM THE I
N0ZZLE UT45T X - - HEAD DUE TO PROXIMITY OF VIBRATION UT60 X - -
SENSOR INSTRUMENTATION BOX.
UT60T X - -
- CSCL-89a*
I N0ZZLE INSIDE RADIUS SECTION l
I 016400 SG-28-IN-IR B-D UT2B UTI-016 RO X - -
i INLET N0ZZLE INSIDE RADIUS B3.140 SECTICN
- CSCL-41**
l l.
l
)
i DATE: 05/1T/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
7 l p REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELOS)
FIRST INTERVAL, SECOND PERIOD, FIRST GUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS STEAM GENERATOR 2B (ARIMARY SIDE) (FIGURE A-SG-2)
N O
ASME O G T
.l l
SEC. XI R E H
)
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
j J
N0ZZlE INSIDE RADIU3 SECTION 016500 SG-29-ON-IR B-D UT28 UTI-016 RO
-X j
OUTLET N0ZZLE INSIDE RADIUS B3.140
]
I l
SECTION l
i
- CSCL-41**
I MANWAY BOLTING 016800 SG-2B-IMS B-G-2 VT-1 NDEP 9.3 R1 X - -
INLET MANWAY BOLTING B7.30 r-br 016900 SG-29-0MB B-G-2 VT-1 NOEP 9.3 R1 X - -
OUTLET MANWAY BOLTING B7.30 l
?
tN
m DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
8 O REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF) i CLASS 1 COMPLETED COMPONENTS REACTOR COOLANT SYSTEM N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
I
)
31-RC-2202-NSS - LOOP 2 (FIG NO A-RC-2) 100180 1 B-F PT NDEP 6.2 R4 X - -
93 - UT45(RL) FROM THE ELBOW AND N0ZZLE SG OUTLET N0ZZLE TO ELBOW B5.130 UT45 UTI-018 RO
- X - SIDES: CSS-80. UT45T(RL) ON THE ELBOW UT45T X - - SIDE: CSS-80. UT45T (R*,) ON THE WELD AND UT60 UTI-005 R1 X - - N0ZZLE SIDE: 55-79. dT60(RS) FROM THE UT45T X - - N0ZZLE SIDE: CS-78.
LIMITED UT DUE TO VELD AND N0ZZLE CONFIGURATION.
- CS-78/SS-79/ CSS-80**
20-RC-2201-NSS - 1000 2 (FIC NO A-RC-2) 100900 5 B-F PT NDEP 6.2 R4 X - UT45(RL) FROM THE ELBOW AND N0ZZLE ELBOW TO SG INLET N0ZZLE B5.130 UT45 UTI-018 R0 X - -
SIDES: CSS-80. UT45T(RL) ON THE ELBOW UT45T X
- - SIDE: CSS-80. UT45T(RS) ON THE WELD AND UT60 UTI-005 R1 X - -
N0ZZLE SIDE: 55-79. UT60(RS) FROM THE UT45T X - - N0ZZLE SIDE: CS-78.
LIMITED UT DUE TO WELD AND N0ZZLE CONFIGURATION.
- CS-78/SS-79/ CSS-80**
16-RC-2412-NSS (FIG NO A-RC-5) 101910 5 B-J PT NDEP 6.2 R4 X - -
ELB3W TO PIPE B9.11 UT45 UTI-001 R2
- X -
UT45T X - -
- *SS.16" 101920 6 B-J PT NDEP 6.2 R4 X - -
P!PE TO BENT PIPE B9.11 UT45 UTI-001 R2
- X -
UT45T X - -
- SS-16**
101930 7 B-J PT NOEP 6.2 R4 X - -
BENT PIPE TO BENT PIPE B9.11 UT45 UTI-001 R2
- X -
j
\\
UT45T X - -
- SS-16**
(
l CATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
9 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELOS) g'~'
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS REACTOR COOLANT SYSTEM N
O ASME O C T I
SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM No METHOD PROCEDURE C M R ** CALIBRATION BLOCK'*
16-RC-2412-NSS (FIG NO A-RC-5) 101940 8 B-J PT NDEP 6.2 R4 X - -
I PIPE TO BRANCH CONNECTION B9.11 UT45 UTI-001 R2
- X -
l UT45T X - -
f
- SS-16**
l 8-RC-2214-BB1 (FIG NO A-RC-12) l 103340 1 B-J PT NDEP 6.2 R4 X - USED UT60 REFRACTED SHEAR FOR I
VALVE TO PIPE B9.11 UT45 UTI-001 R2
- X -
ADDITIONAL COVERAGE.
UT45T v -
UT60 UTI-005 R1
- X -
- SS-11**
k 103350 3 B-J PT NDEP 6.2 R4 X - -
ELB3W TO PIPE B9.11 UT45 UTI-001 R2
- X -
UT45T X - -
- SS-11**
4-RC-2123-831 (FIC NO A-RC-14) 104990 3 B-J PT NDEP 6.2 R4 X - ONE UTDW CODE ALLOWABLE INDICATION.
ELBDW TO PIPE B9.11 UTDW UTI-004 R1
- - X UT45 UTI-005 R1
- X -
UT45T X - -
- SS-7**
105040 9 B-J PT NOEP 6.2 x4 X - -
PIPE TO PIPE B9.11 UT45 UTI-005 R1
- X -
UT45T X - -
e.S$_7.*
105050 10 B-J PT NOEP 6,2 R4 X - -
PIPE TO ELBDW B9.11 UT45 UTI-005 R1
- X -
UT45T X - -
(
- SS-7**
I 4
i i
DAT E: 05/17/94 SOUTH TEXAS PROJECT E'.tCTRIC GENERATING STATION UNIT 2 PAGE:
10 1
REVISION:
0 INSERVICE INSPr..; TION REPORT - 2RE03 (WELOS)
}
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS REACTOR COOLANT $YSTEM
]
N O
ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS e
J NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
-ij 4-RC-2320-BB1 (FIG _NO A-RC-10) 105450 6 B-J PT NDEP 6.2 R4 X - -
PIPE TO REDUCING TEE B9.11 UT45 UTI-005 R1
- X -
1 UT45T X - -
- *SS-7" l
i 4
105460 7 B-J PT NDEP 6.2 R4 X - -
RED'JCING TEE TO PIPE B9.11 UT45 UTI-005 R1 X - -
UT45T X - -
i
- *S S-7" 4-RC-2422-BB1 (FIG NO A-RC-13)
I 105940 2 B-J PT NDEP 6.2 R4 X - -
PIPE TO ELBDW 89.11 UT45 UTI-005 R1
- X -
UTt.5T X - -
- SS -7" 1
i 105990 7 B-J PT NDEP 6.2 R4 X - -
ELB7.1 TO PIPE B9.11 UT45 UTI-005 R1
- X -
UT45T X - -
t "SS-7" 106020 10 B-J PT NDEP 6.2 R4 X - -
PIPE TO PIPE B9.11 UT45 UTI-005 R1
. X -
UT45T X
- SS-7" 3-RC-2015-NSS (FIG NO A-RC-7) 106270 3 B-J PT NDEP 6.2 R4 X - -
ELBDW TO PIPE B9.21 1
..... ~.
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC CENERATING STATION UNIT 2 PAGE:
11 O
REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS REACTOR COOLANT SYSTEM N
O ASME D G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BL00.K**
3-RC.?O15-NSS (FIG NO A-RC-7) 106310 7 B-J PT NDEP 6.2 R4 X - -
ELBOW TO PIPE B9.21 i
1 0
i l
I I
I DAT E: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
12
/'*%
REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELOS) k/
FIRST INTERVAL, SECOND PERIOD, FIRST CUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS RESIDUAL HEAT REMOVAL SYSTEM N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLOCK"*
i i
12-RH-2201-BB1 (FIC NO A-RH-21 l
200760 13 B-J PT NDEP 6.2 R4 X
P!PE TO PIPE B9.11 UT45 LTI-001 R2
- X -
UT45T X - -
- SS-21**
10-RH-2208-881 (Fic_NO A-RH-2).
201820 4 B-J PT NDEP 6.2 R4 X - -
93 - USED UT45 REFRACTED SHEAR FOR PIPE TO ELBOW B9.11 UT45 UTI-001 R2
- X - ADDITIONAL COVERAGE.
UT45T X
UT45 UTI-005 R1
- X -
. ss.58**
f
%~./
201880 7 B-J PT NDEP 6.2 R4 X - -
ELB3W TO PIPE B9.11 UT45 UTI-001 R2 X -
UT45T X -.
- SS-5S**
201920 9 B-J PT NDEP 6.2 R4 X -.
PIPE TO ELBOW 89.11 UT45 UTI-001 R2
- X -
UT45T X - -
. 55 58**
t 1
l 8-RM-2208-B31 (FIG _NO A-RH-2) 202920 1 B-J PT NDEP 6.2 R4 X - -
VALVE TO PIPE 89.11 UT45 UTI-001 R2
- X -
UT45T X - -
- SS-10**
{
i I
'V
k i
1 i
DATE: 05/17/94 Sousa TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
13
. (~'s REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS) lt f
FIRST INTERVAL, SECOND PERIOD, FIRST CUTACE (93RF)
CLASS 1 COMPLETED COMPONENTS REACTOR COOLANT PUMP 2A
- 4 0
l ASME O O T l
SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS l
NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLOCK **
I FLvwHEEL (FIG _NO A-RCP-3) 2$0170 RCP-2A-RJ RG UTO Ln!-003 R0 X - EXAMINED BORE, KETWAYS, AND BOLT I
FLYWHEEL 1.14 HOLES IN PLACE, 3
i d
- CS-74**
I
~,
e 3
1 1
i 1
5 I
t t
6 e
i 1
5 1
i i
)
i i
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4 L
1 t.
1 1
1 i
I 1
4 d
b 1
1 1
1 4
I i
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j DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
14
]
REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELOS)
]
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS REACTOR COOLANT PUMP 28 N
O ASME O G T j
SEC. XI R E H i
SUMMARY
EXAMINATION AREA CATGY EXAM
~E O-E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD Pn0CEDURE C H R ** CALIBRATION BLOCK **
260270 RCP-2B-nJ RG UTO UTI-003 R0 X - EXAMINED BORE, KEYWAYS, AND BOLT j
FLn4 HEEL 1.14 HOLES IN PLACE.
f
- CS-76**
j i
)
4
)
i
.i T
W I
l d
I i
s
, _ _ _. _ _ _ _ _.. - _. _ _ _ _ _ _ _ _.. _ _ _. _ _ _. _ _ - _ _ _ _. _ _ _ _ _ _ _ ~.
l l
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
15 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELOS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS REA$CTgR COOLANT PUMP 2C T
N O
ASME O G T SEC. XI R E H
SUMMARY
EXAMihATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R
- CALICttATION BLOCK **
l l
FtVWHEEL (FIG NO A-RCP-3) 260370 RCP-2C-FW RG UTO UTI-003 RO-x - EXAMINED BORE, KEYWAYS, AND BOLT FLYWHEEL 1.14 HOLES IN PLACE.
- CS-76" l
Q l
)
I 1
l i
l l
l i
i i
OATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
16
['
REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELOS)
FIRST INTERVAL, SECOND PERIOD, f!RST OUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS REACTOR COOLANT DUMP 20 N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
FLVWHEEL (FIO NO A-RCP-2) 260470 RCP-2D-RJ RG UTO UTI-003 R0 X - EXAMINED BORE, KEYWAYS, AND BOLT FLYWHEEL 1.14 HOLES IN PLACE.
- CS-76**
n I
t
(
l 1
l l
l
1 l
i l
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC CENERATING STATION UNIT 2 PAGE:
17 l
CI REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELOS)
FIRST INTERVAL, SECOND PERIOD, FIRST DUTAGE (93RF)
CLASS 2 COMPLETED COMPONENTS EXCESS LETDOWN HEAT EXCHANGER (FIGURE B-ELOX-1)
N O
ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
.-..---------.--...--...------ ------- ---------- --------------- - - - --~~------------------------------------
CIRCUMFERENTIAL VELOS 308300 CSAHEL-2A-51 C-A UTDW UTI-004 R1 X - - USED UT35 SEARCH UNIT FOR SECOND ANGLE (HEAD) SHELL TO FLANGE C1.20 UT45 UTI-022 R1 X - - 0F THE TRANSVERSE SCAN TO ENSURE SOUND UT60 X - - BEAM IMPINGEMENT ON THE INSIDE SURFACE.
UT45T X - - LIMITED UT DUE 70 HEAD CONFIGURATION AND
- UT35T X - - FLANGE BOLTING.
- SS-67**
I J
l
l l
CATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
18 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELOS) l FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF) l CLASS 2 COMPLETED COMPONENTS FFE0 WATER SYSTEM N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS f
NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BL'JCK**
1 18-N-2014-CA2 (FIG NO B-N-3, 4) l 500860 1 C-F-2 MT NOEP 7.1 R3 X - SUPPORT FW2014-HL5010 REMOVED FOR VALVE TO PIPE C5.51 UT45 UTI-002 R2
- X - ACCESS PER WR# FW161566.
I
- CS-3**
i 500830 2 C-F-2 MT NDEP 7.1 R3 X - - AUGMENTED ISI - BEZ.
PIPE TO VALVE C5.51 UT45 UTI-002 R2 X - -
l
- CS-3 "
i 500900 3 C-F-2 MT NOEP 7.1 R3 X - - '93 - AUGMENTED ISI - BEZ.
{
VALVE To PIPE C5.51 UT45 UTI-002 R2 X - -
l i
- CS-3**
l 500920 4 C-F-2 MT NDEP 7.1 R3 X - AUCMENTED ISI - BEZ.
l PIPE TO PIDE C5.51 UT45 UTI-002 R2 X - -
f
- CS-3"*
500940 5 C-F-2 MT NDEP 7.1 R3 X - AUGPENTED ISI - BEZ. LIMITED MT PENETRATICN TO PIPE C5.51 PT NDEP 6.2 R4 X - - DUE TO PR0tIMITY OF FIRE PROTECTION UT45 UTI-002 R2 X - -
LINE..",UJMENTED WITH PT EXAMINTION FOR COMPLETE COVERAGE.
i "CS-3 *
- 1 l
i j
500960 6 C-F-2 MT NDEP 7.1 R3 X - -
PIPE TO ELBOW C5.51 UT45 UTI-002 R2
- X -
)
- CS-3**
]
18-N-2018-CA2 (FIG NO B-N-7, 8) i 502700 3 C-r-2 MT NOEP 7.1 R3 X - -
k VALVE TO PIPE C5.51 UT45 UTI-002 R2 X - -
g 4
f'
- CS-3" i
--..m
--.o.,
. - = -.,,.,., - - - -,.
m--.-m,--.
.,,---4.
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
19
[
REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS)
FIRST INTERVAL, SECOND PERIOD, FIRST CUTAGE (93RF)
CLASS 2 COMPLETED COMPONENTS FEEDWATER SYSTEM N
O ASME D G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION
! TEM NO METH00 PROCEDURE C M R ** CALIBRATION BLOCK **
18-FW-2018-CA2 (FIG NO B-FW-7, 8) 503120 22 C-F-2 MT NDEP 7.1 R3 X - -
PIPE TO ELBOW C5.51 UT45 UTI-002 R2
- X -
- CS-3**
18-RJ-?030- AA2 (FIC NO B-FW-3) 504220 1 C-F-2 MT NDEP 7.1 R3 X - AUGMENTED ISI - BEZ.
ELBOW TO PIPE C5.51 UT45 UTI-002 R2 X - -
- CS-4**
SD4230 1PL1-1PLS C-C MT NDEP 7.1 R3 X - -
PIPE LUGS C3.20
- CS-33**
504240 2 C-F-2 MT NDEP 7.1 R3 X - AUGMENTED ISI - BEZ.
PIPE TO PIPE C5.51 UT45 UTI-002 R2
- X -
- CS-4**
504260 3 C-F-2 MT NDEP 7.1 R3 X - AUOMENTED ISI - BEZ.
PIPE TO PIPE C5.51 UT45 UTI-002 R2 X - -
..cs.4..
504280 4 C-F-2 MT NDEP 7.1 R3 X - AUGMENTED ISI - BEZ.
PIPE TO VALVE C5.51 UT45 UTI-002 R2
- X -
- CS-4**
l
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
20 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS)
FIRST INTERVAL, SECONO PERIOD, FIRST OUTAGE (93RF)
CLASS 2 COMPLETED COMPONENTS SArETY INJECTION SYSTEM N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE-C M R ** CALIBRATION BLOCK **
-------------------------~~--- ------- ---------- --------------- - - - ----------------------------------------
16-SI-2201-UB2 (FIG NO B-SI-4) 705560 12LU C-F-1 PT NDEP 6.2 R4 X - EXAMINED 2.5T AT THE INTERSECTING LONGITUDINAL WELD C5.12 UT45 UTI-012 R1 X - -
UT45T X - -
- SS-3 0" 705580 12 C-F-1 PT NDEP 6.2 R4 X - -
PIPE TO ELBOW C5.11 UT45 UTI-012 R1
- X UT45T X - -
- SS-30**
705600 12LDI C-r-1 PT NDEP 6.2 R4 X - EXAMINED 2.5T AT THE INTERSECTING g
LONGITUDINAL WELD C5.12 UT45 UTI-012 R1 X - -
CIRC. WEtD.
UT45T X - -
- ss.3g**
70562D 12LDO C-F-1 PT NDEP 6.2 R4 X - EXAMINED 2.5T AT THE INTERSECTING LONOITUDINAL WELD C5.12 UT45 UTI-012 R1 X - -
UT45T X - -
" S5-30 "
705740 14tul C-F-1 PT NDEP 6.2 R4 X - EXAMINED 2.57 AT THE INTERSECTING LONGITUDINAL WELD C5.12 UT45 UTI-012 R1 X - -
LU45T X - -
"SS-30" i
705760 14LUO C-F-1 PT NDEP 6.2 R4 X - EXAMINED 2.5T AT THE INTERSECTING LON0!TUDINAL WELD C5.12 UT45 UTI-012 R1 X - -
UT45T X - -
- SS-3 0" 705780 14 C-F-1 PT NDEP 6.2 R4 X - -
ELBOW TO PIPE C5.11 UT45 UTI-012 R1
- X -
1 D
UT457 X - -
"SS-30"
t i
i DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC CENERATING STATION UNIT 2 PAGE:
21 R EVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 2 COMPLETED COMPONENTS SAFETY INJECTION SYSTEM N
O ASME D G T I
SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E oE REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLOCK **
i l
16-$1-2201-UB2 (FIG NO B-SI-4) 705800 14LD C-F-1 PT NDEP 6.2 R4 X - EXAMINED 2.5T AT THE INTERSECTING LONGITUDINAL WELD C5.12 UT45 UTI-012 R1
- X -
UT45T X - -
- SS-30**
l 705810 14PL1-14PLS C-C PT NDEP 6.2 R4 X - -
PIPE LUGS C3.20 l
1 l
12-51-??01-U92 (FIG NO 9-S!-4)
I 1
712040 6LU C-F-1 PT NDEP 6.2 R4 X - EXAMINED 2.5T AT THE INTERSECTING l
LONGITUDINAL WELD C5.12 UT45 UTI-012 R1 X - -
UT45T X - -
- SS-12**
712060 6 C-F-1 PT NDEP 6.2 R4 X - -
PIPE TO ELSDW C5.11 UT45 UTI-012 R1 X - -
UT45T X - -
- SS-12**
i 712080 6LD C-F-1 PT NDEP 6.2 R4 X - EXAMINED 2.5T AT THE INTERSECTING LCNGITUDINAL WELD C5.12 UT45 UTI-012 R1 X - -
I UT45T X - -
- 35 12**
10-St-2201-UB2 (FIG NO B-51-4' 718140 6tU C-F-1 PT NDEP 6.2 R4 X - AUGMENTED ISI - IES 79-17.
LONGITUDINAL WELD UTOL UTI-004 R1 X - -
EXAMINED 2.5T AT THE INTERSECTING CIRC.
UT45 UTI-012 R1 X - -
WELD.
UT45T X - -
- SS-87**
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
22 l
l [\\ REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS) l \\
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF) l CLASS 2 COMPLETED COMPONENTS SAFETY INJECTION SYSTEM N
O ASME D G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUNBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLOCK **
10-SI-2201-U92 (FIG _NO B-SI-4)
I 718160 6 C-F-1 PT NDEP 6.2 R4 X - AUGMENTED ISI - IEB 79-17.
PIPE TO ELBOW UTOL UTI-004 R1 X - -
UT45 UTI-012 R1 X - -
UT45T X - -
- SS-87a*
1 718160 6LD C-F-1 PT NDEP 6.2 R4 X - AUGMENTED IS! - IES 79-17.
LONGITUDINAL WELD UTOL UTI-004 R1 X - - EXAMINED 2.5T AT THE INTERSECTING CIRC.
UT45 UTI-012 R1 X - -
WELD.
UT457 X - --
LONGITUDINAL WELD UTOL UTI-004 R1 X - -
EXAMINED 2.5T AT THE INTERSECTING CIRC.
UT45 UTI-012 R1 X - -
WELD.
]
UT457 X - -
"SS-87" 718260 7 C-F-1 PT NDEP 6.2 R4 X - AUGMENTED 151 - IES 79-17.
ELBOW TO PIPE UTOL UT!-004 R1 X - -
UT45 UTI-012 R1 X - -
i UT45T X - -
"SS-87" 718230 7LD C-F-1 PT NOEP 6.2 R4 X - AUGMENTED ISI - IEB 79-17.
LONGITUDINAL WELD UTOL UTI-004 R1 X - - EXAMINED 2.5T AT THE INTERSECTING CIRC.
UT45 UTI-012 R1 X - -
WELD.
UT45T X
. * $ $. 37 u 2-$1-2206-092 (FIG NO B-SI-20) 746440 5 C-F-1 PT NDEP 6.2 R4 X - LIM 11ED UT DUE TO FLANGE FLANGE TO PIPE C5.21 UT45 UTI-012 R1 X - -
CONFIGURATION.
UT45T X - -
"SS-22" I
J 1
1 I
OATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
23 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (WELDS) l(
FIRST INTERVAL, SECON3 PERIOD, FIRST CUTAGE (93RF)
CLASS 2 COMPLETED COMPONENTS SAFETY INJECTION SYSTEM N
O ASME O G T l
SEC. XI R E H
[
SUMMARY
EXAMINATION AREA CATGY EXAH E O E REMARKS l
NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLOCK **
(
4 f
2-S1-2206-092 (FIG NO B-SI-20) t i
I 746450 6 C-F-1 PT NDEP 6.2 R4 X - -
4 PIPE TO REDUCER C5.21 UT45 UTI-012 R1
- X -
g l
UT45T X - -
l
- SS-22**
I, 2-S1-2232-032 (FIG _NO B-S]-22) 746775 16 C-F-1 PT ADEP 6.2 R4 X - -
PIPE TO ELBOW C5.30 i
I 746785 18 C-F-1 PT NOEP 6.2 R4 X - -
PIPE TO ELBOW C5.30 t
/
k v
t.
i 1
1 1
1 1
d 3
i e
i e
!j l
I i
4 4
4; 4
s J
(
i a
i i
J e
1 4
i 1
i APPENDIX 2-B PERSONNEL 4
i d
j l
s l,
T i
t i
ll e
n.
a n,
l i
O APPENDIX 2-B a
PERSONNEL Name Company UT MT PT VT Jolly, G.
GTS II Sadler, E. W.
GTS II II Scoates, J. E.
GTS ll II II Wolf, R. A.
GTS II II II II Busby, R. S.
HL&P Hubbard, S. K.
HL&P III III III III Spiess, L D.
HL&P III II II II Stuhler, D. A.
HL&P II II II II Suhler, C. D.
HL&P II II II II Company GTS
- GTS Duratek HL&P - Houston Lighting & Power Company O
4 This NDE method not performed for ISI by these personnel during this refueling outage.
O
APPENDIX 2-C HL&P PROCEDURES 4
I T
O
--w.,-.
=. --.., _ - - - - _ <
i APPENDIX 2-C l
HIAP PROCEDURES l
Procedure No.
Title NDEP 4.0 Rev. 3 Ultrasonic Examination I
l NDEP 6.2 Rev. 4 Color Contrast Solvent Removable Liquid Penetrant Examination of i
ASME XI PSI /ISI NDEP 6.6 Rev. 0 Fluorescent Water-Washable Liquid Penetrant Examination of Roto-Lok Studs NDEP 7.1 Rev. 3 Dry Powder Magnetic Particle Examination for ASME XI PSI /ISI NDEP 7.2 Rev. 0 Wet Fluorescent Magnetic Particle Examination for ASME XI PSI /ISI NDEP 9.3 Rev.1 ASME XI Examination for VT-1 and VT-3 l
UTI-001 Rev.2 Manual Ultrasonic Examination of Austenitic and Dissimilar Metal Pressure Piping Welds Using Refracted Longitudinal Technique l
l UTI-002 Rev.2 Manual Ultrasonic Examination of Ferritic Pressure Piping Welds UTI-003 Rev.O Manual Ultrasonic Examination of Reactor Coolant Pump Flywheels from the Access Holes UTI-004 Rev.1 Manual Ultrasonic Examination Using Longitudinal Wave Straight-Beam Technique UTI-005 Rev.1 Manual Ultrasonic Examination of Austenitic Pressure Piping Welds l
UTI-006 Rev.1 Manual Ultrasonic Indication Sizing '
]
l 1
l UTI-007 Rev.O Recording Indications During Ultrasonic Examinations q
l t
l UTI-008 Rev.0 Weld Joint Identification Marking i
UTI-010 - Rev. O Manual Ultrasonic Examination of the Center-Drilled Hole Surface in Pressure Retaining Studs Greater Than 2 Inches in Diameter O
2-C-1
5 O
UTI-012 Rev.1 Manual Ultrasonic Examination of Thin Wall Piping Welds V
UTI-015 Rev.1 Manual Ultrasonic Examination of Reactor Pressure Vessel Studs UTI-016 Rev.O Manual Ultrasonic Examination of Vessel-to-Nozzle Inner Radius i
Sections UTI-017 Rev.1 Manual Ultrasonic Examination of Ferritic Pressure Vessel Welds (Greater Than 2 to 12 Inches in Thickness)
UTI-018 Rev.O Manual Ultrasonic Examination of Centrifugally Cast and Static Cast Stainless Steel Piping Welds UTI-022 Rev.O Manual Ultrasonic Examination of Pressure Vessel Welds (0.4 to Less Than 2.0 Inches in Thickness)
UTI-024 Rev.O Manual Ultrasonic Examination of Reactor Vessel Welds in Accordance with Regulatory Guide 1.150 i
l I
O O
2-C-2
2_,,,
s
_m s-a-ma ah m
.m..,a.
...h u
,c.--a
~,._.
+ss_--
' O APPENDIX 2-D ISI EXAMINATION LIMITATIONS t
O
/
APPENDIX 2-D ISI EXAMINATION LIMITATIONS Table of Contents STPEGS-2 Summary of Inservice Examination Limitation Class 1 Components ASME Category B-A Reactor Pressure Vessel ASME Categog B-B Steam Generator ASME Category B-D Steam Generator ASME Category B-F Piping Reactor Coolant System Class 2 Components ASME Category C-A Excess Letdown Heat Exchanger ASME Categog C-F-1 j
Safety Injection r
k 2-D-1
O SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION, UNIT 2
SUMMARY
OF INSERVICE EXAMINATION LIMITATIONS The following tables provide details on the limitations which were encountered during the inservice examinations (ISI) at the South Texas Project Electric Generating Station, Unit 2 (STPEGS-2). Each table of this summary provides the following information as described:
Class / Category / Item No./ Examination Requirement Column 1 Identifies the ASME Section XI Code Class, Category, Item Number, and Examination Requirement (volumetric or surface) for the specific examination area listed in Column 2. This information is derived from Tables IWB-2500-1 and IWC-2500-1 of the 1983 Edition of ASME Section XI (with Addenda through Summer 1983), and Tables 1 and 2 of Code Case N-408.
Line No./ Subassembly Column 2 Weld Identification Weld ID Figure
{
Weld Configuration Examination Method Provides information for each examination area by line number (piping) or subassembly number (vessel), unique weld identification number, weld ID figure reference, weld configuration (pipe-to-tee, head-to-shell, etc.), and examination method (UT, UT/PT, or UT/MT).
Column 3 -
Exam Type Lists the Methods of Examinations used for each area by specific angles for UT (0,45, 45T,60,60T) and surface technique (MT or PT), if required.
Column 4 -
% Coverage The extent of coverage for each exam type is expressed in percentages based on the examination volume / area required in Section XI. Depending on method, the percentage coverage may be represented in more than one way.
Surface methods are the simplest and are expressed as a percentage of the required surface area receiving no coverage and the remaining balance from 100% as the total coverage.
O v
2-D-2
1 l
Od i
Ultrasonic coverage is first expressed for each exam type as a percentage of the volume receiving no coverage, angle-beam coverage in one direction only, and angle-beam coverage in two directions. These percentages are then used to compute the effective coverage for that exam type. In the case of 0 degree, the effective coverage i
is equal to the balance of 100% minus the percentage receiving no coverage. The effective coverage for angle beam is calculated from the following formula:
c = " +2 *h ( ffective coverage formula, angle beam) where a = one direction only percentage i
b = two direction percentage Examples:
(1) none 1 dir 2 dir 0%
0%
100 %
c=0+2
= 100% effective coverage 2
(2) none 1 dir 2 dir 1
0%
100 % 0 %
c = 100 + ')*0
= 50% effective coverage 2
(3) none 1 dir 2 dir 50 % 50 % 0%
c = 50 + 2*0
= 25% effective coverage The total UT coverage is then expressed as the average of the effective coverage percentages for each UT exam type. Each UT exam type is considered as equal weight in the calculation of the average.
J 2-D-3
\\
i l
5 I
l 1
}
d Column 5 -
Limitation j
A description of the type of limitation and primary reason for why the coverage was limited is provided in this section.
1 j
l l
)
4 i
2-D-4
O
^8"""""'
1993 2RE03 ISI SOUTH T EXAS PROJECT ELECTRIC OENERATINO STATION, UNIT 2 ASME CATPOORY B-A SYSTEM: REACTOR PRESSURE VESSEL (CLASS I)
- LINE NOJSUBASSEMBLY-i CLASS
- WELD IDENTIFICATION
% COVERAGE CATOY
- WELD ID FIOURE j
ITEM NO.
EXAM I DIR 2
- EPP, EXM RQT
- EXAMINATION METHOD TYPE NONE ONLY DIR COV.
TOTAL LIMITATION
)
1 RPV2 UTO 30 70 LIMITED UT DUE TO PROXIMITY OF B-A 103-101 UT45 3
0 97 97 LIFTING LUGS AND INSULATION B2.31 FlOURE NO. A-RPV-3 UT45T 30 0
70 70 SUPPORT RINO. (50% OFTHEWELD VOL (Clossure Head)
UT60 1
0 99 99 LD40TH WAS EXAMINED FOR PERIOD 2)
I DOME-TO-TORUS UT60T 30 0
70 70 81 UT 1
O c
ASME SECTION XI CODE COVERAGE LIMITATIONS 1993 2RE03 ISI SOUTH TEXAS PROJECT ELECTRIC OENERATING STATION, UNIT 2 ASME CATFOORY B-B SYSTEM: STEAM OENERATOR (CLASS I)
- LINE NO./ SUBASSEMBLY CLASS
- WELD IDENTIFICATION
% COVERAGE CATOY
- WELD ID FIOURE.
ITEM NO.
EXAM I DIR 2
EFF.
EXM RQT
- EX AMINATION METHOD TYPE-NONEONLY DIR COV.
TOTAL LIMfrATION
==
I SG-2B UTD 20 80 NO UT FROM THE St'PPORT RINO SIDE DUE B-B SRI UT45/60 2
98 0
49 TO SUPPORT RINO CONFIGURATION, i
B2.31 FIGURE NO. A-SO-2 UT45T 20 0
80 80 LIMITED UT FPGM HEAD SIDE DUE TO I
VOL UT60T 20 0
80 so inevrMW of INLET / OUTLET NOZZLE HEAD-TO-SUPPORT RING WELDS.
72 UT I
SO-2B UTV 28 72 NO UT FROM THE SUPPORT RING SIDE DUE D-B SR2 UT45/60 4
0 48 TO SUPPORT RINO CONF 10URATION.
B2.40 FIGURE NO. A-SO-2 UT45T 28 0
72 72 LIMITED UT FROM THE TUBE PLATE SIDE VOL UT60T 28 0
72 72 DUE TO PROXIMITY OF WELDED PLATES.
SPPT RING-TO-TUBE PLATE UT i
i l
l
1 i
4 ASME SECTION XI CODE COVERAGE LIMITATIONS i
1993 2RE03 ISI l
SOUTH TEX AS PROJECT ELECTRIC OENERATING STATION. UNIT 2 s
i ASME CATBOORY B-D i
1 i
SYSTEM: STEAM OENERATOR (CLASS !)
- LINE NO.! SUBASSEMBLY i
C1 ASS.
- WELD IDENTIFICATION
~% COVERAGE j
4 CATUY '
- WELD ID FIOURE -
ITEM NO.
EXAM '
i DIR 2~
EPP.
i EXM RQT
- EXAMINATION METHOD TYPE NONEONLY DIR COV.
TOTAL LIMITATION 68 LIMITED UT FROM THE HEAD SIDE DUE l
1 S0-2B U1D 32 B-D IN UT45/60 7
93 0
47 TO PROXIMITY OF VIBRATION SENSOR l
B3.130 FIOURE NO. A-SO-2 UT457
- 32 0
65 68 INSTRUMENTATION BOX. LIMITED UT VOL UT60T.
32 0
68 68 FROM THE NOZZLE SIDE DUE TO NOZZLE 4
- NOZZLE-TO-SHELL CONFIOURATION.
j 63 UT l
1 SG-2B UTO 30 70 LIMITED UT FROM THE HEAD $1DE DUE i
B-D ON UT45 7
93 0
' 47 TO PROXIMITY OF VIBRATION SENSOR l
B3.130 FIGURE NO. A-SO-?
UT45T 30 0
70 70 INSTRUMENTATION BOX. LIMITED UT VOL UTeo 30 0
70 70 FROM THE NOZZLE SIDE DUE TO NOZZLE j
SHELL-TO-NOZZLE UT60T CONFIGURATION 64 UT 1
J j
1 l
,,. _..,,,,.,. - ~. -
-.,,i
O ASME SECTION XI CODE COVERAGE LIMITATIONS 1993 2RE03 ISI SOUTH TEXAS FROJECT ELECTRIC OENERATING STATION, UNIT 2 ASME CATICORY B-P SYSTEM: REACTOR COOLANT - M AIN LOOPS (CLASS 1 FIPINO)
- LINE NOJSUBASSEMBLY CLASS
- WELD IDENTIFICATION
% COVERAGE CA10Y
- WELD ID FIGURE ITEM NO.
EXAM I DIR 2
EFF.
EXM RQT
- EXAMINATION METHOD TYPE NONEONLY DIR COV.
TOTAL LMITATION I
31-RC-22a2 UT4Sie0 0
100 0
50 LIMITED UT FROM BOTal SIDES AND ON B-F 1
UT45T 10 0
90 90 THE WELD DUE TO WELD CONFIOURATION B5.130 FIGURE NO. A-RC-2 AND SIZE OF THE SEARCl{ UNIT.
YOUSURF 70 NOZZLE-10-ELBOW UT/PT PT 0
100 1
29-RC-2208 UT45/60 1
99 0
30 LIMITED UT FROM BOTH $1 DES AND ON B-F 5
UT45T 9
0 91 91 THE WELD DUE TO WELD CONFIGURATION B5.130 FIGURE NO. A-RC-2 AND SIZE OF THE SEARCH UNIT.
VO!JSURF 70 ELBOW-TO-NOZZLE UT/PT PT 0
100 i (
l O
l l
. ~.
~a.~.
l
)
l ASME SECTION XI CODE COVERAGE LIMITATIONS 1993 2RE03 ISI SOUTH TEXAS PROJECT ELECTRIC OENERATING STATsON. UNIT 2
?
ASME CA1TOORY C-A J
SYSTEM: ' SAFETY INJECTION (CLASS 2) l
- LINE NO./ SUBASSEMBLY j
CLASS
+ WELD IDENTIFICATION.
5 COVERAGE-CA10Y
- WELD ID NURE :
j ITEM NO.
EXAM i DIR 2' EFF.
EXM RQT
- EXAMINATION METHOD.
TYPE'.
NONEONLY DIR -
COV.
TOTAL LIMITATION -
2 CSAHEL-2A UTOW D
- 100 LIMITED UT45 AND UT60 PROM THE HEAD 1
C-A S1 UT45/60 12 48 40 64 SIDE DUE TO HEAD CONFIOURATION.
Cl.20 FIOURE NO. B-ELDX-1 UT45T/35 28 0
72 72 NO UT45/UT60/UT45T/UT35T ON THE VOL FLANOE SIDE DUE TO PROXIMrIY OF (HEAD)SHELL-TO-FLANGE 79 FLANCE BOLTINO.
(
i
)
- l L
1 1-p
,-. + ~
r,
f I
ASME SECTION XI CODE COVERAGE LIMITATIONS
\\
1993 2RE03 ISI SOUTH TEXAS PROJECT ELFCTRIC OENERATINO STATION, UNIT 2
+
ASME CATICORY C-P-1 SYSTEM: SAFETY INJECTION (CLASS 2)
- LINE NO./ SUBASSEMBLY CLASS
- WELD IDENTIFICATION
% COVERAGE CATOY
- WELD ID FIOURE
~
ITDI NO.
EXAM i DIR 2
- EFP, EXM RQT
- EXAMINATION METHOD TYPE NONEONLY D!R COV.
TOTAL LIMTTATION 2
2-51-2206 UT45 0
0 100 100 LIMITED UT ON THE FLANGE SIDE C-P-1 5
UT45T 27 0
73 73 DUE TO FLANGE CONFIGURATION.
C5.21 F10URE NO B-SI-20 YOUSURP 87 FLANOE-TO-PIPt!
UT/PT PT 0
100
%.)
\\
a.h a
m, m
s a
g:a O
APPENDIX 2-E O
OWNER'S REPORT FOR INSERVICE INSPECTIONS NIS-1 FORMS O
l l
f 1993/4 ISI - 2RE03 - Welds (Class 1)
Page 1 of 3 i
I FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECI' IONS As required by the Provisions of the ASME Code Rules O-L
- 1. Owner Houston Lichtine & Power Company: Electric Tower: P.O. Box 1700: Houston. Texas 77001 (Name and Address of Owner)
- 2. Plant South Texas Proicct Electric Generatine Station: P.O. Box 289: Wadsworth. Texas 77483 (Name and Address of Plant)
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89.,,, 6. National Board Number for Unit N.A.
- 7. Components Inspected ASME Code Class 1 (IWB) Items - Welds Program (See Page 3 of 3 for Identification Numbers)
Manufacturer Component or Manufacturer or Installer National i
Appurtenance or Installer Serial No.
Board No.
Reactor Pressure Combustion Engineering /
Vessel Westinchouse (M) 12173 22391 Steam l
Generator 2B Westinghouse (M) 2152 30 Class 1 Pinine Ebasco (1)
N.A.
N.A.
l i
lO t
HL&P by P Date f/h/4 Factory Mutual by
__ s4v Date 8V8 W S. Timmaraju Engineering Assoc.
B. R. Russell, ANII
1993/4 ISI - 2RE03 - Welds (Class 1)
Page 2 of 3 FORM NIS-1 (Back)
- 8. Examination Dates 03/10/93 to 05/18/93
- 9. Inspection Interval from 06/19/89 to 10/195)0 O
- 10. Abstract of Examinations. Include a list of examinations and a statement concerning status of work required for current interval. (ASME Code Cass 1 (IWB) Items - Welds Program)
See Section 2.4 and Appendix 2-A of 2RE03 Summary Report for list of examinations performed.
The examinations performed this outage constitute 15% of the required examinations for the current interval The cumulative percentage completed for the interval is 44%
- 11. Abstract of Conditions Noted.
None.
- 12. Abstract of Corrective Measures Recommended and Taken.
None.
)
We certify that the statements made in this report are correct and the examinations and corrective measures taken conform to the rules of ASME Code,Section XI.
Certificate of Authorization No.(if applicable)
N.A.
Expiration Date N.A.
Date 9/M 19 CIIP Signed Houston Lichtinc & Power Co. By
%6 Owner S. Timmaraju' 1
CERTIFICATE OF INSERVICE INSPECTION I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure
\\~/
Vessel Inspectors and the State or Province of Texas and employed by Arkwricht Mutual Insurance Ca of Norwood. Mass have inspected the components described in this Owner's Report during the period
_ 3 -/O - 93 to f,W43
. and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owner's Report in accordance with the inspection plan and as required by the ASME Code.Section XI.
By signing this certificate neither the Inspector nor his employer makes any warranty, express or implied, concerning the examinations 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 with this inspection.
/
Factory Mutual Engineering Association 1
.. md// -
Commissions Tex 826 l
Inspector's Signature National Board, State, Province, and Endorsements B. R. Russell i
Date A -2 3 - 19 94
l 1993/4 ISI - 2RE03 - Wclds (Class 1)
Page 3 of 3 SUPPLEMENT TO FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS ASME Code Class 1 (IWB) Items - Welds Program
- 1. Owner Houston Lichtinc & Power Company: Electric Tower: P.O. Box 1700: Houston Texas 77001 (Name and Address of Owner)
- 2. Plant South Texas Project Electric Generatine Station: P.O. Box 289: Wadsworth. Texas 77483 (Name and Address of Plant)
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89
- 6. National Board Number for Unit N.A.
I ASME ASME COMPONENT EXAM l
CAM Y TIEM or SYFIEM IDFNPIF1 CATION NO.
MImIOD RI! MARKS B-A Bl.40 RPV RPV2101101 UT,MT CLOSURE IIEAD TORUS-ILANGE B-A Bl.21 RPV RPV2103-101 UT CLOSURE IIEAD DOME-TORUS l
B-A Bl.22 RPV RPV2-101 104C UT CLOSURE IIEAD MER. WELD-180' B-A Bl.22 RPV RPV2101-104D UT CLOSURE 11EAD MER. WELD-270*
!!EAD TO SUPPORT RIN3 BB B2.40 SO SG 2B SR2 UT SUPPORT RING TO 'I1]T,E PLATE B-D B3.130 SG SG-2B-IN UT INLET NO7ZLE TO CifNL 11D CAP l
BD B3.130 SG SG-2B ON UT ClINL llD CAP TO OUTLET NOZ BD B3.140 SG SG-2B-IN-IR UT INLET NOZZLE INSIDE RADIUS l
BD B3.140 SG SG-2D-ON-IR UT OUTLET NOZZLE INSIDE RADIUS B-F B5.130 RC 31-RC-2202-NSS-1 UT,PT SO OUTLET NOZZLE TO ELBOW l
B-F B5.130 RC 29-RC-2201-NSS-5 UT,PT ELBOW TO SG INLET NOZZLE B-G 1 B6.30 RPV 2.5,8,11,14,17,20,23,26,29,32,35 UT,PT.MT CLOSURE STUDS BG1 B6.50 RPV 2.5,8,11,14,17,20,23,26,29,32,35 VT-1 CLOSURE WASIIER B-G 2 B7.30 SG SG 2B 1MB VP-1 INLET MANWAY BOLTING B-G-2 B7.30 SG SG-2B OMB VP1 OUTLET MANWAY BOLTING B-J B9.11 RC 16-RC-2412-NSS 5 UT,PT ELBOW TO PIPE l (
BJ B9.11 RC 16-RC-2412-NSS-6 UT,PT PIPE TO BENT PIPE
(
BJ B9.11 RC 16-RC-2412-NSS-7 UT,PT BENT PIPE TO BENT PIPE BJ B9.11 RC 16-RC-2412-NSS4 UT,PT PIPE TO BRANCll CONNECTION BJ B9.11 RC 8-RC-2214-BB1 1 UT,PT VALVE TO PIPE B.J B9.11 RC 8-RC-2214 BB13 UT,PT ELBOW TO PIPE B-J B9.11 RC 4-RC-2123-BB1-3 UT,PT ELBOW TO PIPE BJ B9.11 RC 4 RC-2123-BB19 UT,PT PIPE TO PIPE BJ B9.11 RC 4-RC-2123-BB1 10 UT,PT PIPE TO ELBOW BJ B9.11 RC 4 RC-2320-BB16 UT,PT PIPE TO REDUCING TEE B.J B9.11 RC 4-R C-2320-BB1 -7 UT,PT REDUCING TEE TO PIPE BJ B9.11 RC 4-RC-2422-BB12 UT,PT PIPE m ELBOW BJ B9.11 RC 4-RC-2422-BBI-7 UT,PT ELBOW TO PIPE BJ B9.11 RC 4-RC-2422-BB1 10 UT,PT PIPE TO PIPE BJ B9.21 RC 3-RC-2015-NSS 3 PT ELBOW TO PIPE B-J B9.21 RC 3-RC 2015-NSS-7 PT ELBOW TO PIPE BJ B9.11 Rif 12-Ril-2201-BB1-13 UT,PT PIPE TO PIPE BJ B9.11 Ril 10-RII-2208-BB1-4 UT,PT PIPE TO ELBOW BJ B9.11 R}i 10-Ril-2208-BB17 UT,PT ELBOW TO PIPE BJ B9.11 RII 10-Ri1-2208-B81-9 UT,PT PIPE TO ELBOW B-J B9.11 Ril 8-Ril 2208-BB1-1 UT.PT VALVE TO PIPE B-N-1 B13.10 RPV VESSEL INTERIOR VP3 l
l HL&P by "W Date f % Factory Mutual by a mDate 8&TA-e S. Timmaraju Engineering Assoc.
B. R. Russell, ANil
i 1993/4 ISI - 2RE03 - Welds (Class 2)
Page 1 of 3 1
j FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS As required by the Provisions of the ASME Code Rules I
I i
- 1. Owner Houston Lichtine & Power Company: Electric Tower: P.O. Box 1700: Houston. Texas 77001
)
(Name and Address of Owner)
)
- 2. Plant South Texas Project Electric Generatine Station: P.O. Box 2R9: Wadsworth. Texas 77483 (Name and Address of Plant)
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89
- 6. National Board Number for Unit N.A.
- 7. Components Inspected ASME Code Class 2 (IWC) Items - Welds Program (See Page 3 of 3 for Identification Numbers)
Manufacturer i
Component or Manufacturer or Installer National Appurtenance or Installer Serial No.
Board No.
Excess Letdown Heat Exchancer Joseph Oat Coro (M) 2312-3B 989 Class 2 Pipine Ebasco (I)
N.A.
N.A.
O
\\
\\
\\
l Date A-2 3 M HL&P by w'
Date f/4f+
Factory Mutual by S. Timmaraju Engineering Assoc.
B. R. Russell, ANil
1993/4 ISI - 2RE03 - Welds (Class 2)
Page 2 of 3 I
l
~
FORM NIS-1 (Back) p
- 8. Examination Dates 02/17B3 to 12/1583
- 9. Inspection Interval from 06/19/89 to 10/19/00 (J
- 10. Abstract of Examinations. Include a list of examinations and a statement concerning status of work required for current interval. (ASME Code Class 2 (IWC) Items - Welds Program)
See Section 2.4 and Appendix 2-A of 2RE03 Summary Report for list of examinations performed.
'Ibc examinations performed this outage constitute 8% of the required examinations for the current interval. The cumulative percx:ntage completed for the interval is 38%.
- 11. Abstract of Conditions Noted.
None.
f
- 12. Abstract of Corrective Measures Recommended and Taken.
None.
We certify that the statements made in this report are correct and the examinations and corrective measures taken conform to the rules of ASME Code,Section XI.
Certificate of Authorization No.(if applicable)
N.A.
Expiration Date N.A.
Date f/21 19 9 4-Signed Houston I.ichtine & Power Co. By rWh-
/
Owner S. Timmaraju '
CERTIFICATE OF INSERVICE INSPECTION O
Q 1, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State or Province of Texas and employed by Arkwricht Mutual Insurance Co.
of Norwood. Mass have inspected the components described in this Owner's Report during the period 3-/7-43 to 4 /T-e?3'
. and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owner's Report in accordance with the inspection plan and as required by the ASME Code,Section XI.
By signing this certificate neither the Inspector nor his employer makes any warranty, express or i
implied, concerning the examinations and corrective measures described in this Owner's Report.
l 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 c(mnected with this inspection.
f Factory Mutual Engineering Association Mu Commissions Tex 826 l
Inspector's Signature National Board, State, Province, and Endorsements B. R. Russell Date d'-2 5 - 19 94 i
l l
l l
l 1993/4 ISI - 2RE03 - Welds (Class 2)
Page 3 of 3 l
SUPPLEMENT TO FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECIlONS i
ASME Code Class 2 (IWC) Items - Welds Program i
)
- 1. Owner Houston Lichtine & Power Company: Electric Tower: P.O. Box 1700: Houston. Texas 77001 j
(Name and Address of Owner) r
(Name and Address of Plant)
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89
- 6. National Board Number for Unit N.A.
ASME ASME COMPONENP EXAM CA" ICY rI11M or SYSTT'M IDFNITISCA'llON NO.
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C-F-1 C5.11.
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C-F-1 SI 10-SI-2201-UB24/6LU/D UT,PT PIPE TO ELBOW j
i C-F-1 SI 10-SI 2201-UB2-7,7LU/D UT,PT ELBOW TO PIPE j
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C-F-2 C5.51 FW 18 FW-2014-GA2-5 UT,MT PENETRATION TO PIPE j
C-F-2 C5.51 FW 18 FW-2014-GA24 UT,MT PIPE TO ELBOW l
C-F-2 C5.51 FW 18-FW-2018-GA2 3 UT,MT VALVE TO PIPE J
C-F-2 C5.51 FW 18-fM-2018-GA2-22 UT.MT
' PIPE TO ELBOW C-F 2 C5.51 FW 18-I'W 2030-AA2-1 UT,MT ELBOW TO PIPE C-F-2 C5 51 IM 18-FW-2030-AA2-2 UT MT PIPE TO PIPE C-F-2 C5 51 FW 18-FW 2030-AA2-3 UT,MT PIPE TO PIPE C-F-2 C5.51 IN 18-IV 2030-AA2-4 UT,MT PIPE TO VALVE 1
4 HL&P by
~- d Date $h]qp Factory Mutual by MU Date 8- 3-'IA S. Timmaraju '
I Engineering Assoc.
B. R. Russell, ANIl
,y,w y,
1 3.0 STEAM GENERATOR TUBE EXAMINATIONS 1)
- s 4
3.1 Introduction l
This section of the summary report addresses the eddy current testing (ET) ISI of selected l
tubing in Steam Generators A, B, C and D conducted during 2RE03. It is intended to I'
respond to the reporting requirements of ASME Code Section XI, IWA-6000 and 4.4.5.5 (b) i of the STPEGS Technical Specification.
The STPEGS-2 plant design contains four (4) steam generators. Each of the steam generators is a model E2 recirculating design generator, designed and fabricated by Westinghouse Electric Corporation of Tampa, Florida. The design of each generator has 4851 tubes in service. The tubing is ASTM SB-163 Inconel material having a nominal outer
]
diameter (OD) of 0.75 inches and nominal wall thickness of 0.043 inches.
The examination agency for the 2RE03 ET of steam generator tubes was B&W Nuclear Technologies (BWNT). They acquired the first ET data on August 21,1993. The last ET data analysis was performed on September 4,1993.
J 3.2 Scope of Examinations A
The STPEGS-2 ten year ISI plan, previously filed with the NRC, describes the ISI program 4
V for examination of steam generator tubing. Additionally, a supplemental ISI plan (ISI Outage 4
Plan) entitled," 1993 Outage Plan for the Inservice Inspection of Steam Generator Tubing at
,1 the South Texas Project Electric Generating Station, Unit 2" was prepared by BWNT and approved by HL&P. The ISI Outage Plan identified the steam generator tube areas expected j
to be examined and the ET procedures expected to be used during this ISI. Prior to the beginning of the ISI, tubes were selected and assigned to the scope cf Jun ?n each of the four (4) steam generators to be examined. These scopes were list <:d in the ISi Outage Plan.
2 The initial scope consisted of the following planned examinations:
Bobbin coil probe ET of the full length of all inservice tubes.
1 Motorized Rotating Probe Coil (MRPC) ET of three (3) areas in 1022 tubes in each steam generator. The areas of tube to be examined extend one (1) inch above and below the edges of the first baffle plate and the first support plate (plates O1H and 02H) and two (2) inches above to one (1) inch below the secondary face of the tubesheet on the hot leg side (TSH).
MRPC ET of 200 selected tube areas in the total plant. Approximately eighty (80) of these areas would be tight radiused U-bends examined between the bend transitions, inclusively. Approximately eighty (80) of these areas would be tube expansions at 3-1
preheater baffle plates. The remaining areas were selected where experience Os indicated a higher potential for degradation and would be examined over an approximate length of three (3) inches.
This scope exceeded the requirements for the first ISI sample of tubes specified in 4.4.5.2 of the STPEGS technical specification (NUREG - 1346). Because the results of the initial examinations identified by the ISI Outage Plan could have identified a situation where addi ional examinations of other tube areas or the same tube areas (with different t
nondestructive examination techniques or methods) would be required or advisable, the ISI Outage Plan established a method for quickly changing the plan scope or other details during the outage. Changes were made by issuing an Outage Plan Change Form. Four (4) changes were made to the ISI Outage Plan during the outage. The change forms are included as Appendix 3-A. The ISI Outage Plan and plan changes are consistent with the requirements of the ten year ISI plan.
3.3 Personnel, Procedures, and Equipment i
3.3.1 Personnel Qualifications The personnel who performed ET and data analysis were employeed by BWNT, Conam Nuclear, or Allen Nuclear Associates (ANA). They were certified in accordance with the requirements of IWA-2300 of ASME Code Section XI and the certification practices of their j
f respective employers. In addition, all data analysts were required to have satisfactorily j
completed (1) specific training in ET data analysis and (2) site specific training. The site specific training lecture addressed the specific design and operating history, previous ET results, and the data acquisition procedure and analysis guideline to be used for the STPEGS Unit I and 2 steam generators. The site specific training also included hands on review of 1
indications of flaw types which have been experienced at plants of similar design to that of the STPEGS. Successful completion of the site specific course required the passing of a written and practical (hands on) test. The BWNT, Conam Nuclear, and ANA personnel who performed examinations and/or data analysis, their certification levels, and identification numbers are listed in Appendix 3-B. The identification numbers of the persons that acquired or analyzed the data for a specific eddy current examination are recorded on the data.
3.3.2 Examination and Analysis Procedures j
Bobbin coil probe ET was performed in accordance with the BWNT procedure ISI-424 Revision 20 entitled, "Multifrequency Eddy Current Examination of.750" OD x.043" Wall
)
RSG Tubing for ASME Exam. and Wear at Tube Support Plates" with Change Authorization i
No. HL&P-93-001. This procedure, with the change authorization, is STPEGS document no. 400999-00018-AZU. This technique was used in each tube examined to record 550, 300,130, and 10 kIIz frequency data using both differential and absolute bobbin probe coil configurations. The BWNT bobbin coil probe procedure is an alternative to the technique described in ASME Code Section V, Article 8, I-42, which requires that the probe pull speed O
3-2
O not exceed 14 inches per second. Instead, a maximum pull speed of 24 inches per second with a digital signal sampling rate of 800 samples per second was used. Procedure ISI-424 paragraph 8.2 permitted the higher pull speed with the approval of a BWNT ET Ixvel III and a STPEGS representative. The approval was granted on a signed fann entitled "ET EXAMINATION DATA SilEET" This procedure, using the faster probe pull speed, was demonstrated to the satisfaction of the Authorized Nuclear Inservice Inspection (ANII) in accordance with IWA-2240 of Section XI.
MRPC probe ET was performed in accordance with the BWNT procedure ISI-510 Revision 13 entitled, "RPC System Operating Procedure". This procedure is STPEGS document no.
400999-00022-AZU. This technique was used in each area examined to record 300,200, 100, and 10 kHz frequency data.
The ET data analysts worked to HL&P Engineering Instruction El-8.01," Steam Generator Eddy Current Data Analysis Guidelines", Revision 1 including the Analysis Guideline Exception Fonns entitled " Bobbin Eddy Current Guidelines #1", " Bobbin Eddy Current Guidelines #2", " Bobbin Eddy Current Guidelines #3", and " Data Quality - Change # 4".
The data for each steam generator tube was subjected to two (2) separate independent analyses in accordance with IIL&P Engineering Instruction El-8.02," Steam Generator Eddy Current Data Control", Revision 1. The bobbin coil probe ET data was analyzed once by a technician using Zetec, Inc. Eddy Net software and once automatically by the computers using Zetec, Inc. Computer Data Screen software. The MRPC ET data was analyzed manually by two independent technicians using Eddy Net software.
The data sheets for each examination are stored as records.
Each system calibration, with the associated calibration verifications, has a unique " calibration group number" The raw ET signal for each examination is recorded on a digital rewritable optical disk which posses a unique number. The raw signals for every system calibration and calibration verification are also included, with the calibration group number, on a digital rewritable optical disk.
The unique number of the digital rewritable optical disk, the calibration group number, and the dates and times of system calibrations and calibration verifications have been recorded on the data sheets and optical disks. Therefore, the system calibration and calibration verification raw signals for each tube examination can be easily recalled.
3.3.3 Equipment BWNT used MIZ-18A ET instruments. BWNT also used the Eddynet computer software, Version 21, to acquire and analyze the ET data. The MIZ-18A instruments and Eddynet software are manufactured and produced by Zetec, Inc.. The MIZ-18A uses digital equipment and software which have a significantly improved dynamic range and signal-to-noise ratio as compared to analog systems. The MI718A is capable of being operated at locations remote from the steam generators (e.g., in low radiation areas). For conducting bobbin coil ET, BWNT used 0.610 inch diameter magnetic biased probes. IIowever, 0.590 inch diameter bobbin probes were used in order to pass the small radiowd U-bends in Rows 3-3
1, 2, and 3. For conducting motorized rotating pancake coil (MRPC) ET in the straight sections of tubing, BWNT used 0.610 inch diameter three (3) coil MRPC probes. Ilowever, in three tubes, where 0.610 inch probes had difficulty rotating, a 0.590 inch diameter probe was used instead. Seven (7) tubes, where MRPC ET indicated permiability variation signals, were also investigated using a 0.610 inch diameter magnetic biased MRPC probe. For conducting MRPC ET in the U-bend section of tubes, BWNT used 0.580 inch diameter one (1) coil MRPC probes. ASME Boiler and Pressure Vessel Code, Nuclear Components Code Case N-401," Eddy Current Examination - Section XI, Division 1", was used after the digital equipment and the ET technique used were demonstrated to the ANII in accordance with Case N-401.
3.3.4 Calibration Standards The U-bend areas of the Row I and 2 tubes in each steam generator have received an in situ heat treatment to improve their resistance to stress corrosion cracking. The ET calibration standards used were not subjected to that heat treatment. ASME Boiler and Pressure Vessel Code, Nuclear Components Code Case N-402, " Eddy Current Calibration Standard Material.
Section XI, Division 1" was used. It had been demonstrated to the satisfaction of the ANII that calibration standards with and without this heat treatment result in equivalent examinations. Otherwise, the design and material of the ET calibration standards used meet the requirements of the ASME Code Section XI.
3.4 Summary of Examinations Bobbin coil ET examinations were conducted in all in-service tubes in each of Steam Generators A, B, C, and D. All of these tubes were examined over their full length (from j
tube end to tube end). The following numbers of tubes were examined by the bobbin coil ET method:
Steam Generator Number Examined A
4848 B
4851 C
4842 D
4848 Distorted, ambiguous or non-quantifiable bobbin coil ET indications at tube support or baffle plates were examined by MRPC ET. Bobbin coil ET free span indications (e.g., anomalous indications, dings, manufacturing burnishing marks, permeability variations, etc.) which were not clearly due to flaws were either examined by MRPC ET or compared to the data or analysis results of previous examinations. The comparison was performed, discounting the effects of frequency and set up difference between outages, to identify whether indications were newly formed or changed as a result of degradation. In the majority of cases, their O
3-4
locations, amplitudes, and phase angles (as applicable) were compared to the results of the analysis of the data obtained during previous ET programs as recorded on the computer data i
s base management system, reports, or data sheets. If the comparison to recorded analysis results was not conclusive, comparison was done to the past digitized signals as displayed by the digital data analysis system. When the results were judged to be similar to the past data no action other than recording the indication was required. IIowever, when the results were significantly different or the indication did not exist in the past, then the location was tested by a MRPC probe.
j MRPC ET examinations were conducted in the 0111, 021I, and/or TSII tube areas depicted by the plots included as Appendix 3-C. MRPC ET was also conducted at the various other tube locations listed in Appendix 3-C.
1 3.5 Examination Results and Corrective Actions The location of the indications were recorded relative to the adjacent tube support and bafDe plates and anti-vibration bars. The tube support plates and baf0e plates were numbered consecutively from 0111 to 1011 (on the hot leg) and from 11C to 23C (on the cold leg) starting on the hot leg side, over the U-bends, and down the cold leg side of the steam generator. The anti-vibration bars were numbered AV1, AV2, AV3, and AV4 from the hot leg to the cold leg side, respectively. Indications in the tubesheet area were recorded relative O
to TEll or TSIl (hot leg) or TEC or TSC (cold leg) depending on whether the indications were at the tube end (E) or secondary face (S). In addition, the vertical distances from these 4
landmarks to flaws were recorded.
Lists, including the locations and depths, of all flaw indications which are characterized as reductions in the tube wall thickness are included in Appendix 3-D.
Lists of all dents and dings detected in each steam generator are included in Appendix 3-E.
The numbers of degraded and defective tubes detected are as follows:
3.5.1 Steam Generator A Five (5) areas of tube degradation, as defined by the Technical Specifications in 4.4.5.4, were detected in two (2) tubes. Of these indications of degradation, two (2) areas in one (1) tube are defective, as defined by the Technical Specification 4.4.5.4.
3.5.2 Steam Generator B Two (2) areas of tube degradation were detected in two (2) tubes. Of these indications of degradation, none are defects.
3-5
3.5.3 Steam Generator C No area of tube degradation was detected in any tube. Therefore, there are no defects.
l 1
3.5.4 Steam Generator D q
Two (2) areas of tube degradation were detected in two (2) tubes. Of these indications of degradation, none are defects.
The minimum required size of the initial ISI sample is defined in Technical Specification 3/4.4.5 Table 4.4-2. It requires that the minimum initial sample for inspecting four (4) steam generators be three (3) percent of the total tubes installed in each generator. ' All of the tubes in service were examined by the bobbin coil method of eddy current testing. So, the initial sample requirements were met.
Steam Generator C had no defective or degraded tubes detected. Steam Generators B and D each had no defective and two (2) degraded tubes detected. Therefore, the portions of defective and degraded tubes in each steam generator were less than one (1) tube and five (5) percent of the total tubes inspected, respectively. Consequently, the results of the Steam Generator B, C, and D inspections should be categorized as Category C-1, as defined by the Technical Specification. No additional tube inspections are required when the prior inspection results are categorized as C-1.
Steam Generator A had one (1) defective and two (2) degraded tubes detected. Therefore, the portions of defective and degraded tubes were less than five (5) and ten (10) percent of the total tubes inspected, respectively. The results of the Steam Generator A inspection should be categorized as Category C-2.
The consequence of the initial and subsequent examination results being categorized as C-2 is, according to Table 4.4-2, the addition of eighteen (18) percent additional tubes to be inspected. The maximum number of tubes required to be examined when the results are consistently categorized as C-2 are twenty-one (21) percent. All of the Steam Generator A i
degradation and defects are caused by anti-vibration bar (AVB) wear. The bobbin coil eddy current inspection method is very effective for detecting and measure AVB wear. Since all of the tubes were tested by the bobbin coil method full length, the requirement to test twenty-one (21) percent of the tubes was met. The defective tube in Steam Generator A was remove from service by plugging.
l O
3-6
Tl e tubes which were removed from service by plugging prior to this ISI are as follows:
B C
D 3-20 3-20 3-20 3-20 21-20 21-20 21-20 21-20 31-20 31-20 31-20 31-20 34-20 21-34 31-21 48-27 35-20 31-34 3-24 21-34 21-34 340 21-34 31-34 31-34 3-60 31-34 3-40 3-40 3-81 3-40 46-59 3-61 21-87 40-40 3-60 9-66 31-87 3-49 3-81 3-81 3-101 4-49 21-87 21-87 21-101 5-49 31-87 O
31-87 31-101 3-50 2-95 3-101 4-50 3-101 21-101 5-50 21-101 31-101 3-61 31-101 3-81 21-87 31-87 3-101 21-101 31-101 O
3-7
The tubes that were removed from service by plugging as a result of the eddy current ISI
-)
s
(.
performed during this outage are as follows:
j Steam Generator A
B C
D l
44-62 48-27 46-62 45 59 No corrective actions were performed as a result of dings or dents detected during this ISI.
3.6 Certification of Inspections A Section XI NIS-1 form, " Owner's Report for Inservice Inspections," has been prepared to-certify the STPEGS Unit 2 ISI examinations described in this Summary Report. The STPEGS Unit 2 ISI examinations have been certified by our ANII, Factory Mutual Engineering Association, on the NIS-1 form included in Appendix 3-F.
l l
1 i
o l
O 3-8 i
1 0
j l
APPENDIX 3-A O
CIIANGES TO TIIE ISI OUTAGE PLAN l
)
O
O i
OUTAGE PIAN CIIANGE FORM
. Number 1 1
DESCRIPTION OF CITANGE (ADDITION OR DELIMON): Add to the STPEGS Unit 2 examination plan the attached scope expansion criteria.
REASON FOR CIIANGE: The change benefits the station by obtaining information necessary to determine the overall condition of the steam generators in an efficient manor.
i O
TECIINICAL BASIS: The change benefits the station by obtaining information necessary to determine the overall condition of the steam generators in an efficient manor.
SCITEDULE IMPACT: Six to fifteen days, depending on the number and types of flaws detected.
AUTIIORIZATIONS: fAws$./!
j
)Nr -
Date _f-K43 AU Vendor:
IIL&P: 4L/l /VM/M Date f-st-U OYf O
v
Scope Expansion Criteria for the Steam Generator Tube hispection Program All eddy current testing (ET) results will be acted upon in accordance with the requirements of the Technical Specifications. No part of any of the following rules for scope expansion shall preclude full compliance with the requirements of the Technical Specifications.
Free span indications (indications between support / baffle plates or tubesheet) detected by bobbin coil probe ET which are clearly the result of flaws require no further actions other Other bobbin coil ET free span than those required by the Technical Specifications.
indications (e.g., anomalous indications, dings, manufacturing burnishing marks, permeability variations, etc.) which are not clearly due to flaws will be compared to the data or analysis results of previous examinations. The comparison will be performed, discounting the effects of frequency and set up difference between outages, to identify whether indications are newly formed or have changed as a result of degradation. Their location, amplitude, and phase angle (as applicable) may be compared to the results of the analysis of the data obtained during previous ET programs as recorded on the computer data base management system, reports, or data sheets. If comparison to recorded analysis results is not conclusive, comparison will be done to the past digitized signals as displayed by the digital data analysis If the results are judged to be similar to the past data no action other than system.
recording the indication is required. However,if the results are significardy different or the indication did not exist in the past, then the location will be tested by a motorized rotating pancake coil (MRPC) probe. If considering the MRPC probe test results (possibly with other augmenting techniques) it is concluded that the location is cracked the tube will be 4
removed from service.
If MRPC testing detects a circumferential linear indication and it is concluded (possibly considering the data from other augmenting processes or techniques) that the location is cracked at the top of the tubesheet on the hot leg side, then the MRPC sample will be expanded to include all of the tubes in that steam generator at the top of the tubesheet on the hot leg side. All circumferential cracks of any depth detected will be stabilized and the tube removed from service.
Distorted, ambiguous or non-quantifiable bobbin coil indications at tube support or baffle plates will be examined by MRPC. The MRPC probe will typically detect auter diameter stress corrosion cracking (ODSCC) at support structures when the flaws reach a depth near or above the 40 percent through. wall plugging limit. Consequently, if the indication is confirmed by MRPC to be crack-like or intergrannular attack (IGA) the tube will be removed from service.
If MRPC detects an ODSCC type indication which is not detectible by the bobbin coil probe ET at the 1st or 2nd support / baffle plate (01H and 02H), then the MRPC sample will be p
expanded to include all of the tubes in that steam generator at the elevation of the Q
If, through the use of other augmenting tests or processes, the indication is indication.
Prior proven not to be crack-like or IG A, then the sample is not required to be expanded.
to plugging tubes, elevations 01H. 02H, and 03!! which had not been emmined will be examined by MRPC.
--~
OUTAGE PLAN CHANGE FORM i
l DESCRIPTION OF CHANGE #2 (ADDITION OR DELETION):
i f
l 1.
Mark existing Section 4.0 with " Superceded".
Insert attached'page j
-in front of previous Section 4.0.
2.
Insert the attached illustrations of half moon area in Subsections A3, B3, C3 and D3.
3.
Replace headings of tube lists in Subsections A3, B3, C3 and D3 with " List of 21% Random Sample MRPC Tubes to be Examined".
I REASON FOR CHANGE:
Several tubes in a half moon area do not-have a hot Aeg ist support plate (01H).
These tubes will only be examined at the hot' leg 1
tubesheet (TSH) and the hot leg second support plate (02H).
TECHNICAL BASIS:
To identify the tubes not having an O1H support l
plate.
l SCHEDULE IMPACT:
Not Affected j
1 AUTHORIZATIONS:
Lead Analyst t b [.
DATE:
F / #5 / PS
/
CTO Engineer c%,g DATE:
/3 / E3 / f.3 C.
g o
a
~
OU]
OUTAGE PLAN CHANGE FORM DESCRIPTION OF CHANGE #3 (ADDITION OR DELETION):
Delete tube number 23-5 from Bobbin scope and plots in all steam 1.
generators.
Delete tube number 23-5 from 21% Random MRPC Sample for steam 2.
generator "A" and add tube number 23-6.
REASON FOR CHANGE:
Tube number 23-5 does not exist in the steam generator design.
OLJ In order to maintain the 21% Random MRPC Sample TECHNICAL BASIS:
total number of tubes to be examined at 1022.
SCHEDULE IMPACT:
Not Affected AUTHORIZATIONS:
Lead Analyst I wf
/jn DATE:
[ / /J / f3 DATE:
6 / 2 3_/93
,q CTO Engineer S
<W es o
s
_ _ _. =
0 i
I I
OUTAGE PLAN CIIANGE FORM Number 4 l
.I DESCRIITION OF CIIANGE (ADDITION 'OR DELETION):
Delete th'e MRPC probe examination of tube 6-69 in Steam Generator A from the STPEGS Unit 2 examination plan.
]
i i
REASON FOR CIIANGE: The base of the probe manipulator is covering the tube opening.
This is the only tube area which remains to be examined. It would be necessary to move the probe manipulator to test this tube area. The value of this one examination does not appear to warrant the dose expected to be acquired to move the manipulator.
O TECIINICAL BASIS: Examination of this tube area is not required by any site commitments.
The area was selected for examination because the tube is expanded to a point about 0.3 inches below the upper edge of the tubesheet. All of the other seventeen similar areas in this Steam
' Generator were examined. They revealed no flaws. Consequently,it is not possible to substitute a similar tube area for 6-69. The person-dose expected to result from moving the probe i
manipulator to test this one tube is about 150 mR.
SCIIEDULE IM PACT: Eliminating the requirement to move the probe manipulator to examine this tube area reduced the work duration for Steam Generator A by about 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
AUTIIORIZATIONS:
Vendor:
t[b [//Inu Daie 9-/-f5 IIL&P:
41.McM Date -1 : L 1-t-T3 h
0 N-o -9s O
O APPENI)IX 3-B LIST OF EXAMINATION AND DATA ANALYSIS PERSONNEL O
l I/
APPENDIX 3-B LIST OF EXAMINATION AND DATA ANALYSIS PERSONNEL i
EDDY CURRENT TESTING DATA ACQUISITION PERSONNEL I
NAME COMPANY ET CERT. LEVEL ID NO.
Anderson, D. A.
ANA I
A3502 Blankinship, M. B.
BWNT II B6768 l
Bryant, D. N.
BWNT II B2224 Burch, K. W.
BWNT II B3905 Cauvan, M. D.
ANA II C1950 Cecil, W.R.
BWNT II C3697 Childers, J. E.
ANA IIA C4330 Close, D. R.
BWNT I
C1407 l
Collier, R. R.
BWNT IT C6253 l
Digorgio, P. J.
ANA IIA D9866 Duffield, T. S.
BWNT I
D6502 Eagan, F. J.
BWNT II E7518 Galloway, G. V.
BWNT IT G5307 Gordon, V. M.
BWNT IT G5008 Griffith, T. E.
ANA II G6920 l
Guill, R. L.
BWNT II G9134 l
Hollis, D. R.
BWNT I
H5331 Hooker, M. A.
BWNT IT H1497 Hufford, C. A.
ANA II H9833 Hyland, D. P.
ANA I
H3071 Kellar, J. L.
ANA IIA K9208 Kithcart, B. R.
BWNT II K1731 Knox, B. L.
BWNT II K6388 Kovalesky, T. L.
BWNT II K2858 Lawson, J. P.
ANA II L8876 Lawyer, D. G.
ANA II L3093 Lloyd, M. K.
BWNT II L5290 i
Martin, A. C.
BWNT IIA M2421 Mason, J. R.
BWNT II M8048 McMillan, W. P.
BWNT 11 M9460 McMillon, B. A.
ANA II M2141 Mezzano, D. M.
BWNT I
M9693 Miller, D. C.
BWNT IT M4021 l
Miller, K. W.
BWNT IT M4817 l
Mitchell, T. L.
BWNT II M5765 l/
Morgan, B. K.
ANA IIA M3442 l
Munsterman, T. H.
BWNT Il M8912 i
('N]
APPENDIX 3-B L,
LIST OF EXAMINATION AND DATA ANALYSIS PERSONNEL f
EDDY CURRENT TESTING DATA ACQUISITION PERSONNEL (Cont'd)
NAME COMPANY ET CERT. LEVEL ID NO.
Nolan, C. D.
BWNT I
N3559 Pavia, F. B.
BWNT I
P2472 Petty, D. R.
BWNT II P2272 Rutledge, J. K.
BWNT IT R4847 Wieber, J. A, ANA II W2155 Williamson, L. R.
ANA II W5710 O
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APPENDIX 3-B LIST OF EXAMINATION AND DATA ANALYSIS PERSONNEL EDDY CURRENT TESTING DATA ANALYSIS PERSONNEL NAME COMPANY ET CERT. LEVEla ID NO.
Barnes, R. M.
BWNT IIA B0690 Bowler, S. R.
ANA IIA B7702 Caperello, M. M.
Conam IIA C1115 Cooper, L. R.
,BWNT IIA C9813 de la Pintiere, L.
ANA III P5006 Dugas, K. D.
Conam IIA D4503 Gardner, C. L.
ANA IIA G4841 Hako, E. J.
ANA IIA H4495 Himmelspach, R. J.
BWNT IIA H8259 Holden, T. A.
ANA III H1748 Korkowski, E. M.
BWNT IIA K7060 Loer, M. S.
BWNT IIA L7871 Lofgren, R. H.
Conam IIA LO211 Matheson, M. J.
Conam IIA M0554 L
Moon, B. C.
BWNT IIA M0155 Morgan, D. E.
ANA IIA M1908 Neff, A. S.
ANA III N6550 Parrish, J. M.
BWNT IIA P5436 Pendergrass, R. A.
BWNT IIA P2201 Raper, L. J.
ANA IIA R6878 Ribaric, T. A.
BWNT IIA R6452 Schlicht, W. R.
BWNT IIA S6369 Schwenn, J. S.
BWNT IIA S1848 Shibley, D. E.
Conam IIA S7752 Smith, H. L.
BWNT III S2680 Whatley, C. H.
ANA IIA W9213 O
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>=
STEAM GENERATOR A Tube Areas Examined by MRPC at Locations Other Than O1H, 02H, or TSH j
ROW COL LEG EXTENT 1 EXTENT 2 PROBE 1
1 TEH 11C 10H 580 i
1 14 TEH 11C 10H 580 1
28 TEH llc 10H 580 1
35 TEH 11C 10H 580 1
45 TEH llc 10H 580 1
71 TEH llc 10H 580 1
94 TEH llc 10H 580 1
100 TEH 11C 10H 580 1
102 TEH llc 10H 580 1
114 TEH 11C 10H 580 2
18 TEH 11C 10H 580 2
22 TEH llc 10H 580 2
28 TEH llc 10H 580 2
41 TEH llc 10H 580 2
45 TEH llc 10H 580 2
53 TEH llc 10H 580 2
55 TEH llc 10H 580 2
71 TEH llc 10H 580 2
81 TEH 11C 10H 580 2
103 TEH llc 10H 580 2
106 TEH llc 10H 580 3
9 TEC 17C 18C 610 4
90 TEH 11C 10H 580 5
18 TEH 08H 07H 610 i
6 86 TEH 06H 06H 610 8
83 TEd 09H 09H 610 9
32 TEC 23C 23C 610 TEC TSC TSC 610 10 29 TEC 20C 21C 610 10 99 TEC TSC TSC 610 0
17 59 TEH 05H 05H 610 r
18 79 TEC 17C 17C 610 19 32 TEC 17C 17C 610 20 80 TEH 07H 07H 610 23 40 TEC 19C 20C 610 l
24 77 TEH 03H 03H 610 24 91 TEH 10H 10H 610 28 102 TEC 12C 12C 610 30 111 TEH 05H 05H 610 35 21 TEC TSC TSC 610 36 66 TEC 21C 21C 610 TEC 22C 22C 610 38 59 TEC 21C 21C 610 TEC 22C 22C 610 40 67 TEH 03H 03H 610 I
44 22 TEC 21C 21C 610 1
44 26 TEC 22C 22C 610 44 40 TEC 21C 21C 610 44 84 TEC TSC TSC 610 45 39 TEC 22C 22C 610 l
45 83 TEC 21C 21C 610 i
I O
i
I STEAM GENERATOR A Tube Areas Examined by MRPC at Locations Other Than O1H, 02H, or TSH O
ROW COL LEG EXTENT 1 EXTENT 2 PROBE 1
46 95 TEC 21C 21C 610 TEC 22C 22C 610 47 30 TEC 22C 22C 610 l
47 59 TEC 21C 21C 610 TEC 22C 22C 610 48 32 TEC 22C 22C 610 48 35 TEC 21C 21C 610 i
TEC 22C 22C 610 48 56 TEC 21C 21C 610 TEC 22C 22C 610 48 70 TEC 22C 22C 610 48 73 TEC 21C.
21C 610 TEC 22C 22C 610 TEC TSC TSC 610 48 78 TEC 21C 21C 610 I
(I i
O
i STEAM GENERATOR-B Tube Areas Examined by MRPC at Locations Other Than 01H, 02H, or TSH O
ROW COL LEG EXTENT 1 EXTENT 2 PROBE 1
9 TEH llc 10H 580 1
34 TEH llc 10H 580 1
37 TEH llc 10H 580
(
1 43 TEH 11C 10H 580 i
1 50 TEH llc 10H 580 1
56 TEH 11C 10H 580 1
59 TEH 11C 10H 580 1
62 TEH llc 10H 580 1
72 TEH 11C 10H 580 1
75 TEH 08H.
08H 610 1
89 TEH 11C 10H 580 1
106 TEH llc 10H 580 1
107 TEH 11C 10H 580 2
24 TEH 11C 10H 580 2
28 TEH llc 10H 580 2
43 TEH 04H 04H 610 2
54 TEH llc 10H 580 2
58 TEH 11C 10H 580 i
2 66 TEH llc 10H 580 2
70 TEH llc 10H 580 t
2 96 TEH llc 10H 580 2
100 TEH llc 10H 580 2
101 TEH llc 10H 580 2
106 TEH 11C 10H 580 3
44 TEH 03H 03H 610 3
61 TEH 11C 10H 580 5
14 TEC TSC TSC 610 5
32 TEC 12C 12C 610 5
40 TEH OSH 05H 610 l
5 54 TEC 15C 15C 610 l
7 78 TEC 13C 13C 610 7
102 TEC 20C 20C 610 TEC 21C 21C 610 8
34 TEC 14C 14C 610 8
115 TEC TSC TSC 610 9
26 TEC 17C 17C 610 9
87 TEH 05H 05H 610 9
111 TEC 11C 11C 610 TEH 07H 07H 610 TEH 08H 08H 610 10 68 TEC 18C 18C 610 11 11 TEC 16C 16C 610 11 63 TEC 18C 19C 610 TEC 19C 19C 610 11 65 TEC 17C 17C 610 13 80 TEC 15C 15C 610 15 7 TEC 21C 21C 610 TEC 22C 22C 610 15 9 TEC 23C 23C 610 16 42 TEH 04H 04H 610 17 18 TEC 16C 17C 610 TEC 21C 22C 610 I
O
STEAM GENERATOR B i
Tube Areas Examined by MRPC at-Locations Other Than 01H, 02H, or TSH O
ROW COL LEG EXTENT 1 EXTENT 2 PROBE 17 68 TEH 04H 04H 610 17 108 TEC 19C 19C 610 18 15 TEC 16C 16C 610 20 6 TEC 20C 20C 610 20 115 TEC 16C 16C 610 22 22 TEH 04H 04H 610 22 26 TEH 04H 04H 610 26 37 TEH 03H 03H 610 27 42 TEH 02H 02H 610 27 47 TEH 02H 02H 610 29 16 TEC 20C 20C 610 29 36 TEH 03H 03H 610 29 42 TEH 02H 02H 610 31 10 TEH 03H 03H 610 31 70 TEH 02H 02H 610 31 74 TEC 12C 12C 610 31 82 TEC TSC TSC 610 32 47 TEH 04H 04H 610 33 37 TEH 04H 04H 610 33 72 TEC 18C 18C 610 34 33 TEH 10H 10H 610 34 44 TEH 10H 10H 610 35 24 TEC 19C 19C 610 TEH 02H 02H 610 35 57 TEH 03H 03H 610 37 39 TEH 03H 03H 610 37 69 TEH 08H 08H 610 37 82 TEH 03H 03H 610 38 38 TEH 03H 03H 610 38 39 TEH 03H 03H 610
()
38 44 TEC 17C 17C 610 s
TEH 06H 06H 610 40 36 TEH 03H 03H 610 40 74 TEH 10H 10H 610 43 35 TEH 04H 04H 610 43 99 TEC 21C 21C 610 TEC 22C 22C 610 i
43 100 TEC 21C 21C 610 TEC 22C 22C 610 46 24 TEC 16C 16C 610 46 29 TEC 22C 22C 610 46 66 TEC 21C 21C 610 46 68 TEC 21C 21C 610 TEC 22C 22C 610 46 97 TEC 21C 21C 610 TEC 22C 22C 610 47 45 TEC 22C 22C 610 47 56 TEC 22C 22C 610 47 72 TEC 21C 21C 610 47 74 TEC 21C 21C 610 TEC 22C 22C 610 47 84 TEC 22C 22C 610 O
i i
I STEAM GENERATOR B i
i Tube Areas Examined by MRPC at Locations Other Than O1H, 02H, or TSH e
l /
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ROW COL LEG EXTENT 1 EXTENT 2 PROBE 48 82 TEC 21C 21C 610 48 94 TEC 22C 22C 610 i
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STEAM GENERATOR C Tube Areas Examined by MRPC at Locations Other Than 01H, 02H, or TSH O
ROW COL LEG EXTENT 1 EXTENT 2 PROBE 1
4 TEH 11C 10H 580 1
21 TEH 11C 10H 580 1
34 TEH llc 10H 580 1
67 TEH 11C 10H 580 1
71 TEH 11C 10H 580 1
76 TEH 11C 10H 580 1
87 TEH llc 10H 580 1
113 TEH 11C 10H 580 1
116 TEH llc 10H 580 2
1 TEH llc 10H 580 2
4 TEH 11C 10H 580 2
6 TEH 11C 10H 580 2
28 TEH 11C 10H 580 2
32 TEH 11C 10H 580 2
43 TEH 11C 10H 580 2
46 TEH 11C 10H 580 2
47 TEH 11C 10H 580 2
49 TEH llc 10H 580 2
50 TEC TSC TSC 610 2
53 TEH 11C 10H 580 2
70 TEH llc 10H 580 2
77 TEH 11C 10H 580 2
100 TEH llc 10H 580 3
67 TEH 06H 06H 610 4
64 TEH 06H 06H 610 5
66 TEH 11C 10H 580 6
6 TEC 13C 13C 610 6
66 TEH 09H 09H 610 7
88 TEH TSH TSH 610 8
54 TEH llc 10H 580 0
10 99 TEC llc 12C 610 10 117 TEH 07H 07H 610 TEH 08H 07H 610 11 17 TEC 13C 13C 610 11 47 TEH 08H 08H 610 11 98 TEH 08H 08H 610 16 54 TEH 04H 04H 610 18 39 TEH 07H 07H 610 18 76 TEH 09H 09H 610 18 90 TEH 05H 05H 610 19 11 TEC llc 12C 610 22 13 TEH 05H 05H 610 23 77 TEH 03H 03H 610 24 9 TEC TSC TSC 610 25 75 TEC TSC TSC 610 25 105 TEH 06H 06H 610 30 22 TEC 21C 21C 610 32 93 TEC TSC TSC 610 32 94 TEC TSC TSC 610 34 27 TEC 14C 14C 610 34 101 TEC 20C 20C 610 40 63 TEH 08H 07H 610 OV
STEAM GENERATOR C Tube Areas Examined by MRPC at Locations Other Than 01H, 02H, or TSH j
'~h b
ROW COL LEG EXTENT 1 EXTENT 2 PROBE 41 27 TEC 11C 11C 610 1
42 73 TEC 14C 14C 610 TEC 15C 15C 610 43 21 TEC 21C 21C 610 TEC 22C 22C 610 44 63 TEC 21C 21C 610 TEC 22C 22C 610 44 98 TEC 21C 21C 610 TEC 22C 22C 610 44 99 TEC 21C 21C 610 TEC 22C 22C 610 45 62 TEC 17C 17C 610 46 46 TEC 19C 19C 610 46 51 TEC 21C 21C 610 TEC 22C 22C 610 46 67 TEC 21C 21C 610 TEC 22C 22C 610 47 29 TEC 21C 21C 610 47 45 TEC 23C TSC 610 TEC TSC TSC 610 48 34 TEC 21C 21C 610 TEC 22C 22C 610 48 36 TEC 21C 21C 610 TEC 22C 22C 610 48 70 TEC 22C 22C 610 l
48 91 TEC 21C 21C 610 TEC 22C 22C 610 1
48 94 TEC 22C 22C 610
("~)
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STEAM GENERATOh D l
Tube Areas Examined by MRPC at Locations Other Than O1H, 02H, or TSH C'\\
ROW COL LEG EXTENT 1 EXTENT 2 PROBE 1
1 TEC 19C 19C 610 1
4 TEC 21C 21C 610 1
6 TEH llc 10H 580 i
1 10 TEH 11C 10H 580 1
24 TEC 20C 20C 610 1
49 TEC 13C 13C 610 1
97 TEC 15C 15C 610 TEC 17C 17C 610 1
107 TEH 11C 10H 580 3
58 TEH TSC TSC 610 3
94 TEC 15C 15C 610 3
107 TEH 04H 04H 610 3
114 TEC 12C 12C 610 4
64 TEC 21C 21C 610 5
20 TEH 08H 07H 610 5
34 TEH llc 10H 580 7
7 TEC TSC TSC 610 7
29 TEC TSC TSC 610 7
108 TEC 15C 15C 610 8
94 TEC 22C 22C 610 8
117 TEH 11C 10H 580 9
9 TEH llc 10H 580 9
104 TEH llc 10H 580 10 9 TEC 20C 20C 610 10 24 TEC 19C 19C 610 11 20 TEC 23C 23C 610 11 34 TEH 11C 10H 580 11 47 TEH 09H 09H 610 11 86 TEH 11C 10H 580 12 74 TEC 20C 20C 610 C
12 94 TEH TSC TSC 610 13 3 TEC 22C 22C 610 14 59 TEH 06H 06H 610 14 102 TEH 11C 10H 580 15 5 TEH 11C 10H 580 15 84 TEH 11C 10H 580 15 94 TEH O1H O1H 610 16 94 TEC 18C 18C 610 16 110 TEH 11C 10H 580 17 5 TEH 11C 10H 580 19 11 TEC TSC TSC 610 21 36 TEH 11C 10H 580 22 98 TEH 09H 09H 610 23 82 TEC 20C 20C 610 24 14 TEC 20C 20C 610 25 25 TEH llc 10H 580 26 8 TEC 11C 11C 610 26 11 TEH 05H 04H 610 28 11 TEH 11C 10H 580 28 46 TEH 03H 03H 610 28 81 TEC 16C 16C 610 29 18 TEC 11C llc 610
)
f STEAM GENERATOR D Tube Areas Examined by MRPC at Locations Other Than O1H, 02H, or TSH O
ROW COL LEG EXTENT 1 EXTENT 2 PROBE 29 81 TEC 20C 20C 610 29 89 TEH 11C 10H 580 31 78 TEH 11C 10H 580 32 64 TEH llc 10H 580 32 73 TEH 11C 10H 580 32 82 TEH 04H 04H 610 33 19 TEC 21C 21C 610 33 67 TEH TSC TSC 610 34 81 TEC 12C 12C 610 35 24 TEC 15C 15C 610 36 15 TEC 16C 16C 610 TEC 19C 20C 610 36 54 TEH 11C 10H 580 36 55 TEH 11C 10H 580 37 46 TEH TSC TSC 610 37 93 TEC 16C 16C 610 38 62 TEH 21C 21C 610 TEH 22C 22C 610 38 82 TEH 04H 04H 610 39 59 TEH 21C 21C 610 TEH 22C 22C 610 39 62 TEH 21C 21C 610 TEH 22C 22C 610 39 83 TEH 11C 10H 580 40 25 TEC 18C 18C 610 40 30 TEC 17C 17C 610 41 81 TEC 17C 17C 610 42 75 TEC 23C 23C 610 43 21 TEC llc llc 610 43 99 TEH 21C 21C 610
.s TEH 22C 22C 610 43 100 TEH 21C 21C 610 4
TEH 22C 22C 610 l
44 22 TEC 21C 21C 610-TEC 22C 22C 610 46 69 TEH 21C 21C 610 TEH 22C 22C 610 46 70 TEH 21C 21C 610 TEH 22C 22C 610 46 87 TEH TSH TSH 610 47 54 TEH 21C 21C 610 TEH 22C 22C 610 47 69 TEH 21C 21C 610 TEH 22C 22C 610 47 82 TEC 19C 19C 610 48 69 TEH 21C 21C 610 48 70 TEH 21C 21C 610 TEH 22C 22C 610 48 73 TEH 21C 21C 610 TEH 22C 22C 610 48 81 TEC 12C 12C 610 TEH 06H 06H 610 0
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APPENDIX 3-D 3
FLAWS WITII tulle WALL TIIICKNESS REDUCTION i
t i
i i
4 l
l BWNS TUSAN 11 (Version 1.0) 08/11/1994 14:29:48 South Texas Project - Unit 2 S/G A,S/G B,S/G C,S/G D
- ?t****
08/93 RF0 Bobbin, MAG-BIAS 1-Coll RPC,MRPC - 21% Random, Selected Tube MRPC g
b Page 1 l
%TWD GENERATOR ROW COL %TW IND LOCATION TAPE #
S/G A 3 9 7 ODI 18C
+14.65 18 I
S/G A 5 18 29 001 07H
+18.51 16
(
3/G A 6 50 14 001 02H
+17.11 96 S/G A 23 001 02H
+16.94 69 l
S/G A 8 52 8 001 06H
+23.24 69 l
S/G A 9 2 12 001 TSC
+2.55
- 14 l
S/G A 10 29 15 001 21C
+10.91 14 S/G A 14 10 15 001 02H
+12.11 12 S/G A 18 25 12 001 13C
+10.10 10 S/G A 23 40 10 ODI 20C
+9.51 32 S/G A 28 50 8 001 04H
+36.52 30 S/G A 28 107 7 001 01H
+25.78 79 S/G A 31 95 7 ODI 14C
+37.76 49 S/G A 44 62 36 ODI AV4
+0.00 62 S/G A 41 001 AV3
+0.00 62 S/G A 45 ODI AV2
+0.00 62 S/G A 46 62 23 001 AV4
+0.00 60 S/G A 31 001 AV3
+0.00 60 S/G B 5 40 20 001 05H
+12.71 54 S/G B 6 85 11 001 OTH
+21.23 92 S/G B 6 115 24 001 16C
+24.44 79 S/G B 8 15 20 001 16C
+17.94 18 S/G B 8 34 14 001 15C
+35.82 54 S/G B 17 ODI 14C
+9.47 54 S/G B 17 001 14C
+25.19 54 S/G B 21 001 14C
+12.62 54 S/G B 24 001 15C
+31.46 54
\\
S/G B 9 66 9 001 08H
+10.68 76 S/G B 9 87 24 ODI 05H
+28.72 90 S/G B 14 89 9 ODI 22C
+8.90 90 S/G B 20 74 18 ODI 14C
+33.00 88 S/G B 20 115 9 ODI 16C
+13.26 69 S/G B 24 85 10 001 07H
+26.49 86 l
S/G B 29 16 30 ODI 21C
+14.15 8
l S/G B 32 12 13 001 02H
+28.13 6
S/G B 33 72 14 001 18C
+4.92 80 S/G B 35 50 13 001 19C
+6.02 34 S/G B 37 92 9 ODI 19C
+2.17 99 S/G B 39 31 9 001 OSH
+3.99 32 S/G B 40 55 18 ODI AV3
-0.11 30 S/G B 42 34 16 001 18C
+6.11 28
$/G B 42 55 18 001 AV3
+0.00 30 S/G B 27 ODI AV2
+0.00 30 S/G B 42 69 8 ODI 16C
+40.11 58 S/G B 44 42 10 001 09H
+2.35 28 S/G B 19 001 06H
+0.71 28 S/G B 44 59 24 001 AV3
+0.00 28 S/G B 46 46 4 001 TSC
+8.54 26 S/G B 8 ODI iSC
+8.48 26 S/G B 47 62 14 ODI AV1
+0.00 56 S/G B 25 ODI AV2
+0.00 56 S/G B 27 001 AV3
+0.00 56 S/G B 48 31 17 001 13C
+19.99 22 S/G C 4 75 9 001 13C
+27.12 62 S/G C 11 17 21 001 13C
+23.44 20 S/G C 14 73 13 001 16C
+32.35 58 S/G C 17 001 16C
+41.55 58 S/G C 18 39 25 001 06H
+38.60 34 S/G C 18 65 11 0D1 01H
+23.66 36 S/G C 18 76 19 ODI 08H
+30.38 36 S/G C 20 001 02H
+29.99 36 S/C C 20 001 08H
+23.04 36 S/G C 23 001 OSH
+38.06 36 S/G C 19 11 23 ODI 12C
+27.83 16 S/G C 22 79 13 ODI 17C
+9.16 36 S/G C 23 77 18 ODI 03H
+9.74 36 i
BWNS TUBAN !! (Version 1.0) 08/11/1994 14:29:48 South Texas Project - Unit 2 S/G A,S/G B,S/G C,S/G D 08/93 RF0 x
Bobbin, MAG-BIAS 1 C0!L RPC,MRPC - 21% Random, Selected Tube MRPC l
Page 2
)
%TWD GENERATOR ROW COL %TW IND LOCATION TAPE #
S/G C 23 101 16 ODI 02H
+24.97 47 S/G C 25 99 11 001 04H
+2.18 61 S/G C 25 105 24 001 06H
-0.57 59 S/G C 27 ODI 06H
-0.71 61 i
S/G C 27 83 11 001 12C
+6.92 78 I
S/G C 28 22 11 ODI 07H
+10.88 8
S/G C 30 22 24 ODI 21C
+10.45 8
S/G C 31 10 18 001 02H
+25.02 8
S/G C 33 100 13 001 13C
+29.17 53 S/G C 34 27 33 001 14C
+5.18 6
S/G C 35 16 5 001 08H
+9.82 6
S/G C 39 105 12 001 23C
+3.78 53 S/G C 44 89 15 001 07H
+8.98 70 l
S/G C 45 62 19 ODI 17C
+17.40 70 S/G C 47 29 14 ODI 21C
-0.32 28 SiG C 47 45 20 DDI TSC
+6.16 54 S/G D 5 20 13 001 06H
+1.74 16 S/G D 15 001 06H
+4.11 16 S/G D 28 ODI 07H
+19.56 16 S/G D 5 26 7 001 14C
+23.81 16 S/G D 5 62 17 ODI 13C
+20.04 48 S/G D 6 19 15 001 13C
+32.63 16 S/G D 16 001 13C
+1.27 16 S/G D 7 25 19 ODI 04H
+3.97 16 S/G D 10 6 9 ODI 02H
+18.43 16 S/G D 11 5 4 001 TSC
+0.96 14
['-'s S/G D 12 7 4 001 20C
+2.10 12 S/G D 12 41 11 DDI OBH
+25.61 22 S/G D 17 32 15 ODI 08H
+15.67 26 S/G D 22 31 8 001 05H
+25.92 24 S/G D 26 11 21 001 04H
+23.91 10 S/G D 26 108 11 001 12C
+16.85 63 S/G D 44 59 26 001 AV3
+0.00 42 S/G D 45 59 37 001 AV2
+0.00 42 Total Indications Found = 100 Total Tubes Found = 78 l
l
O i
1 APPENDIX 3-E DINGS AND DENTS i
O
- ~ - - - - - - -
BWNS TUBAN ll (Version 1.0) 08/11/1994 12:30:58 South Texas Project - Unit 2 S/G A,S/G B,5/G C S/G D
- t******
08/93 RF0
[**
Bobbin, MAG-BIAS 1-C0!L RPC,MRPC - 21% Random, Selected Tube MRPC Page 1 Dents and Dings QRY: 08/11/1994 11:07:59 GENERATOR ROW COL ]ND LOCATION TAPE #
S/G A 1 98 DNG 21C
+13.71 116 S/G A DNG 22C
+13.42 116 S/G A 1 107 DNG 17C
+8.42 114 S/G A DNG 18C
+7.81 114 S/G A 1 114 DNG 08H
+37.68 43 S/G A 2 84 DNG 02H
+17.99 35 S/G A 2 114 DNG 10H
+10.95 104 S/G A 3 115 DNG 10H
+5.71 98
$/G A 4 90 DNG TSC
+2.29 86 S/G A 4 113 DNT 10H
+9.90 77 S/G A 5 14 DNG 09H
+23.26 16 S/G A 6 114 DNG 08H
+13.00 100 S/G A 9 12 DNG 02H
+7.79 14 S/G A 9 26 DNG AV1
+1.23 14 S/G A 9 27 DNG AV1
+1.23 14 S/G A 9 28 DNG AV1
+1.12 14 S/G A 9 29 DNG AV1
+0.90 14 S/G A 9 64 DNG 22C
+9.60 54
$/G A 9 85 DNG 04H
+15.07 88 S/G A 11 57 DNG 10H
+ 2. 74 96 S/G A DNG 10H
+5.86 96 S/G A 13 37 DNG 17C
+8.03 38 S/G A DNG 17C
+20.17 38 S/G A DNG 17C
+32.45 38 S/G A DNG 17C
+44.82 38 ea-f
(
S/G A DNG 18C
+1.32 38 S/G A DNG 18C
+13.67 38 S/G A DNG 22C
+6.06 38 S/G A DNG 23C
+3.98 38 S/G A DNG TSC
+1.03 38 S/G A 15 54 DNG AV1
+9.51 94
$/G A 16 29 DNG 10H
+7.93 12 S/G A DNG 10H
+19.20 12 S/G A DNG 10H
+39.24 12 S/G A 16 30 DNG 10H
+ 7. 68 12 S/G A 16 65 DNG TSC
+6.38 86 S/G A 16 70 DNT 17C
+0.03 86 S/G A DNT 18C
-0.12 86 S/G A 16 88 DNG 10H
+10.72 86 S/G A DNG AV1
+2.93 86 S/G A 17 69 DNG AV1
+8.96 86 S/G A DNG AV1
+20.79 86 S/G A 17 76 DNT 14C
+15.64 86
$/G A 17 86 DNG 10H
+5.87 84 S/G A DNG 10H
+13.02 84 S/G A DWG AV1
+13.18 B4 S/G A DNG AV4
+10.15 84 S/G A 18 8 DNT 10H
+0.00 10 S/G A 19 32 DNG 08H
+35.21 34 S/G A DNG 12C
+39.87 34 S/G A DNG 13C
+36.24 34 S/G A DNG 14C
+4.67 34 S/G A DNG 14C
+32.74 34 S/G A DNG 15C
+1.19 34 S/G A DNG 16C
+25.51 34 S/G A DNG 17C
+21.90 34 S/G A DNG 18C
+11.72 34 S/G A DNG 19C
+8.69 34 S/G A DNG 21C
+16.97 34 i
S/G A DNG 22C
+13.77 34 S/G A DNG 23C
+2.77 34 S/G A 20 5 DNG 10H
+22.87 10 S/G A 20 62 DNT 09H
+0.00 84 i
S/G A DNT 10H 0.52 84 S/G A 22 87 DNT 13C
+44.06 92
BWNS TUBAN II (Version 1.0) 08/11/1994 12:30:58 South Texas Project - Unit 2 S/G A,S/G B,S/G C,S/G D
- t****
D8/93 RF0
[
D**
Bobbin, MAG B! AS 1 C0!L RPC,MRPC - 21% Random, Selected Tube MRPC
\\s v!
Page 2 Dents and Dings GRY: 08/11/1994 11.07:59 GENERATOR ROW COL IND LOCATION TAPE #
S/G A 23 64 DNG 14C
+2.91 B4 S/G A 23 94 DNT 11C
+0.47 53 S/G A 24 98 DNG 14C
+29.74 53 j
S/G A 24 101 DNG 22C
+8.05 53 S/G A 26 8 DNG 09H
+42.75-6 S/G A 26 33 DNG 18C
+0.87 30 S/G A 27 111 DNG 21C
+7.60 51 S/G A 28 13 DNG 08H
+24.02 6
S/G A DNG 19C
+1.18 6
S/G A 29 28 DNG 19C
+10.94 4
S/G A 29 94 DNG 15C
+6.B8 49 S/G A 31 40 DNG 19C
+9.26 30 S/G A 33 107 DNG 01H
+ 7.32 79 S/G A 35 21 DNG 08H
+38.28 2
S/G A DNT TSC
-0.19 122 S/G A 35 69 DNG 12C
+20.20 68
$/G A DNG 12C
+29.06 68 S/G A 35 71 DNG 09H
+20.72 68 S/G A 35 89 DNG 19C
+9.12 68 3
S/G A 39 16 DNG TSC
+0.90 2
$/G A 39 33 DNG 19C
+12.58 24
$/G A 39 96 DNT 17C
+0.00 53 S/G A 40 28 DNG TSH
+5.95 2
i S/G A 46 93 DNT 20C
+0.00 45 S/G A 46 95 DNT 21C
+0.00 45 S/G A 48 34 DNG 32H
+16.27 46 S/G A 48 56 DNG 10H
+169.47 46 S/G A DNT 22C
-0.02 120 S/G B 1 75 DNG 08H
+18.04 107 S/G B 2 43 DNG 04H
+24.98 107 S/G B 2 70 DNG 10H
+12.37 68 S/G B 5 32 DNG 12C
+14.55 54 S/G B 6 98 DNG 17C
+30.32 79 S/G B DNG 17C
+36.44 79 S/G B 7 24 DNG AV2
+4.72 20 S/G B DNG AV3
+2.25 20 S/G B 7 54 DNG 02H
+29.91 116 S/G B DNG 02H
+30.02 57 S/G B 7 72 DNG 04H
+16.53 78 S/G B 7 95 DNG 08H
+14.61 77 S/G B 7 119 DNG 01H
+10.53 77 S/G B 8 4 DNG 10H
+3.14 18 S/G B DNG 12C
+29.06 18
$/G B DNG AV2
+3.55 18 S/G B B 10 DNG 10H
+2.99 18 S/G B DNG 10H
+5.55 18
$/G B DNG 10H
+11.99 18 S/G B DNG AV1
+0.78 18 S/G B DNG Av2
+1.87 18 I
S/G B DNG AV2
+14.23 18 S/G B 8 15 DNG 10H
+3.14 18 S/G B 8 68 DNG 04H
+28.31 76 S/G B 8 92 DNT 20C
+0.00 102 S/G B 8 97 DNG 03H
+11.64 102 S/G B 9 26 DNG 10H
+2.66 18 S/G B DNG 17C
+17.65 18 S/G B DNG 17C
+17.65 108 S/G B 10 31 DNG 19C
+ 2.55 52 S/G B DNG 200
+5.99 52 S/G B 10 101 DNT TSC
+0.86 100 S/G B 11 11 DNG 14C
+9.05 14 S/G B DNG 14C
+32.88 14 S/G B DNG 16C
+27.17 14 S/G B DNG 16C
+ 2 7.17 108 S/G B DNT 13C
-0.26 14
)
BWNs TUBAN 11 (Version 1.0) 08/11/1994 12:30:58 South Texas Project - Unit 2 S/G A,S/G B,S/G C,S/G D
- +++**
08/93 RF0
(
f**
Bobbin, MAG-BI AS 1-C0!L RPC,MRPC - 21% Random, Selected Tube MRPC Page 3 Dents and Dings CRY: 08/11/1994 11:07:59 J
GENERATOR ROW COL IND LOCATION TAPE #
S/G B 11 63 DNG 19C
+7.69 108 S/G B 11 65 DNG 17C
+35.69 108 S/G B 12 22 DNG 09H
+22.71 14 S/G B DNG 09H
+26.34 14 S/G B DNG 09H
+27.87 14 S/G B 12 66 DNG 08N
+34.59 62 S/G B 13 2 DNG 04H
+3.18 14 S/G B DNC 12C
+44.06 14 l
S/G B 13 3 DNG 04H
+3.06 14 l
S/G B DNG 12C
+44.07 14 i
l S/G B DNT 12C
+44.85 14 S/G B 13 39 DNG 06H
+32.48 50 S/G B 14 38 DNT 11C
-0.08 50 S/G B 15 9 DNG 23C
+6.28 14 l
S/G B DNG TSC
+3.33 14 S/G B 15 43 DNG 08H
+37.85 50 S/G B 15 74 DNG 02H
+22.56 62 S/G B DNG 22C
+2.23 62 S/G B 16 5 DNG 12C
+42.53 14 S/G B 16 28 DNG 03H
+30.41 14 i
S/G B 16 33 DNT 12C
+43.66 50 S/G B 16 42 DNG 04H
+23.47 50 S/G B 17 18 DNG 22C
+6.36 12 S/G B DNG 22C
+12.15 12 S/G B DNG 22C
+12.41 12 S/G B DNT 21C
-0.22 12 S/G B 18 9 DNG 12C
+14.66 12 S/G B 18 15 DNG 16C
-0.89 112 S/G B DNG 17C
+44.63 12 S/G B 18 37 DNT 11C
+0.33 50 S/G B L4T 12C
+44.77 50 S/G B 19 56 DNG 09H
+39.70 46 S/G B DN3 09H
+40.50 46 S/G B 20 6 DNG 20C
+9.90 12 S/G B DNG 20C
+9.90 108
$/G B 20 11 DNG 02H
+22.81 12 i
S/G B 21 12 DNG 09H
+43.03 12 S/G B DNT 11C
+0.42 12 S/G B 23 16 DNG 09H
+20.95 10 S/G B DNG 10H
+4.70 10 S/G B 23 75 DNG 16C
+18.26 42 S/G B 24 49 DNG 02H
+17.32 46 S/G B 26 57 DNG 06H
+30.40 40 S/G B 27 40 DNG 15C
+12.26 40 S/G B 27 63 DNG 04H
+ 25. 73 42 S/G B 28 37 DNG 04H
+1.88 38 S/C B 29 39 DNG 03H
+33.51 38 S/G B DNG 04H
+2.98 38 S/G B 30 93 DNT 11C
+0.44 99 S/G B 30102 DNG 19C
+13.38 99 S/G B DNT 10H
+0.80 99 S/G B 34 33 DNG 09H
+43.74 34 S/G B 34 44 DNG 09H
+43.50 34 S/G B 34 109 DNG TSC
+1.52 55 S/G B 35 31 DNG 12C
+41.99 34 S/G B 35 34 DNG 10H
+12.08 34 S/G B 35 66 DNG 12C
+41.90 80 S/G B 35 72 DNG 09H
+42.81 80
$/G B 35100 DNT 10H
-0.79 53 S/G B 36 73 DNG 11C
+1.09 80 S/G B DNT 10H
+ 0.2 7 80 S/G B 36 91 DNT 11C
+0.41 53 S/G B DNT 11C
-0.65 53 S/G B 37 56 DNG AV1
+9.43 34 S/G B 38 21 DNT 11C
+0.00 2
BWNS TUBAN !! (Version 1.0) 08/11/1994 12:30:58 South Texas Project - Unit 2 S/G A,S/G B,S/G C.S/G D 08/93 RF0 Bobbin, MAG-B! AS 1-C0ll RPC,MRPC - 21% Random, Selected T ube MRPC Page 4 Dents and Dings QRY: 08/11/1994 11:07:59 GENERATOR RDW COL IND LOCATION TAPE #
S/G B 38 35 DNG 09H
+41.65 34 S/G B DNG 09H
+42.06 34 S/G B 38 36 DNG 12C
+23.88 34 S/G B DNG 12C
+24.86 34 S/G B 38 66 DNG 09H
+38.42 60 S/G B 39 19 DNG 09H
+36.01 2
S/G B 39 28 DNG AV3
+ 23. 73 2
S/G B 39 49 DNG 09H
+40.71 30 S/G B 40 17 DNG 04H
+31.90 2
S/G B 40 32 DNG 10H
+12.00 30 S/G B DNG 10H
+12.43 30 S/G B 40 62 DNG OSH
+11.83 60 S/G B DNG 06H
+6.02 60 S/G B DNG 17C
+5.14 60 S/G B 40 66 DNG 09H
+38.64 60 S/G B 40 71 DNG 05H
+15.67 60 S/G B 42 37 DNT 11C
+0.37 28 S/G B 42 47 DNT 11C
+0.40 28 S/G B 42 50 DNG 02H
+ 7. 58 28 S/G B 42 64 DNG TSH
+7.45 58 S/G B 42 69 DNG 22C
+13.29 58 S/G B 43 52 DNG 13C
+19.24 28 S/G B 43 53 DNG 14C
+42.51 28 S/G B 43 59 DNG 09H
+27.26 2B
( )
S/G B 43 63 DNG 12C
+42.93 58 S/G B 43 69 DNT 10H
+0.48 58 Ns/
S/G B 43 90 DNG 03H
+ 7.0 2 58 S/G B 44 43 DNG 05H
+31.70 28 S/G B 44 48 DNG 17C
+24.65 28 S/G B 44 58 DNG 15C
+1.25 28 S/G B DNG 16C
+22.48 28 S/G B 44 69 DNT 09H
+43.74 58 S/G B DNT 10H
+0.47 58 S/G B 44 74 CNT 10H
+0.47 58 S/G B 45 85 DNT 11C
+0.32 56 S/G B 46 26 DNG 03H
+18.30 22 S/G B 46 42 DNG 13C
+ 3 7.35 26 S/C B 46 69 DNT 09H
+43.41 56 S/G B 46 71 DNT 09H
+43.24 56 S/G B 47 48 DNG 23C
+4.34 26 S/G B DNG TSC
+7.72 26 S/G B 48 42 DNT 11C
+0.28 22 S/G B 48 69 DNG 01H
+14.34 56 S/G B DNG 02H
+14.63 56 S/G C 1 18 DNT 16C
+0.00 64 S/G C 2 21 DNT 20C
-0.42 26 S/G C 2 70 DNG TSH
+ 7.71 95 S/G C 2 107 DNG 05H 0.90 37 S/G C 3 1 DNT 22C
-0.41 26 S/G C 3 51 DNG iSC
+1.29 102 S/G C DNT 13C
+0.44 102 S/G C 3 58 DNG 16C
+41.16 102 S/G C 4 1 DNT 22C
-0.42 26 S/G C 4 63 DNG 03H
+21.04 62 S/G C DNG 03H
+31.47 62 S/G C 4 95 DNG 16C 1.12 88 S/G C 5
1 DNT 22C
-0.46 26 S/G C 5 52 DNG 03H
+29.17 57
/'^'T S/G C 5 71 DNT 20C
-0.56 60
(
)
S/G C 5 72 DNG 10H
+4.53 62
's S/G C DNG 10H
+24.34 62 S/G C 6 1 DNT 22C
-0.44 24 S/G C 6 6 DNG 13C
+18.25 24 S/G C 6 50 DNG 23C
+4.74 102 S/G C 6 55 DNG 11C
+1.02 102
BWNS TUBAN II (Version 1.0) 08/11/1994 12:30:58 South Texas Project - Unit 2 S/G A,S/G B,S/G C,S/G D e -'M***
08/93 RF0
(
f**
Bobbin, MAG-BIAS 1-C0!L RPC,MRPC - 21% Random, Selected Tube MRPC
%)
Page 5 Dents and Dings QRY: 08/11/1994 11:07:59 GENERATOR ROW COL IND LOCATION TAPE #
S/G C 6 66 DNG 09H
+16.30 60 S/G C DNG 09H
+17.67 60 S/G C DNG 09H
+18.32 125 S/G C DNG 09H
+18.46 60 S/G C DNG 09H
+19.58 125 S/G C DNG 09H
+19.74 60 S/G C DNG 09H
+21.78 60 S/G C DNG 09H
+22.41 60 S/G C DNG 09H
+23.55 60 S/G C DNG 09H
+24.65 60 S/G C 6 72 DNT 10H
+4.20 60 S/G C DNT 10H
+27.92 60
$/G C 7 1 DNT 22C
-0.21 24 S/G C 7 8 DNG 10H
+38.43 24 S/G C 7 13 DNG 10H
+32.16 24 S/G C 7 16 DNG 10H
+39.46 24 S/G C 7 56 DNG 10H
-5.88 102
.S/G C 7 79 DNG 10H
+3.17 110 S/G C 7 97 DNG 10N
+2.98 110 S/G C 8 46 DNG 08H
+30.73 57 S/G C DNG AV1
+5.62 102 S/G C 8 56 DNG 07H
+36.66 57 S/G C DNG 12C
+2.04 102 S/G C 8 69 DNG 07H
+19.67 60 S/G C 8 72 DNG 10H
+3.96 60
(
S/G C DNG 10H
+33.69 60 S/G C 8 94 DNG 19C
+13.16 86 S/G C 10 69 DNG 01H
+20.18 119 S/G C 10 72 DNG 10H
+4.03 119 S/G C 11 53 DNG 06H
+43.10 100 S/G C DNG 06H
+43.41 57 S/G C 11 91 DNG 21C
+14.01 119 S/G C 12 102 DNG 13C
+39.29 88 S/G C 12113 DNG 07H
+35.79 87 S/G C 16 5 DNG 10H
+32.52 18 S/G C 16 17 DNG 06H
+30.19 18 S/G C 18 14 DNG 22C
+10.43 16 S/G C 18 42 DNT 22C
+0.34 34 S/G C 18 58 DNG 03H
+18.08 34 S/G C DNG 03H
+24.02 34 S/G C DNT 04H
+0.00 34 S/G C 21 15 DNT 06H
+40.27 14 S/G C 21 27 DNG 10H
+3.97 14 S/G C 21 40 DNG 07H
+26.73 42 S/G C 21 90 DNG 03H
+32.64 82 S/G C 21 106 DNG AV4
+20.95 51 S/G C DNG TSC
+3.63 51 S/G C DNT 11C
+0.50 51 S/G C DNT 23C
+0.00 51 S/G C 22 13 DNT 05H
+0.49 14 S/G C 22 25 DNT 05H
+0.00 14 S/G C 22 36 DNG OBH
-0.86 42 S/G C 23 8 DNT 10H
+0.49 14 ~
S/G C 23 92 DNT 11C
+0.34 47 S/G C 24 58 DNG 04H
+4.10 44 S/G C 25 90 DNG 04H
+16.97 78 S/G C 26 14 DNT 10H
+0.00 10
$/G C 26 32 DNG 12C
+8.85 44 j
S/G C 26 91 DNT 11C
+0.58 43
(
S/G C 26 105 DNT 10H
+0.31 59 S/G C DNT 10H
+0.38 63 S/G C 26107 DNT 11C
+0.29 43 S/G C 27 25 DNT 04H
+5.18 10 S/G C 29 81 DNG 15C
+1.33 112
$/G C 29 93 DNT 11C
+0.51 43 j
BWNS TUBAN !! (Version 1.0) 08/11/1994 12:30:58 South Texas Project - Unit 2 S/G A,S/G B,S/G C,S/G D j
e " ****
08/93 RfD Bobbin, MAG BIAS 1-Coll RPC,MRPC - 21% Random, Selected Tube MRPC Page 6 Dents and Dings QRY: 08/11/1994 11:07:59 GENERATOR ROW COL IND LOCATION TAPE #
j S/G C 29 96 DNT 10H
+0.38 43 S/G C 30 33 DNG 22C
+2.63 110 S/G C 30 43 DNG 06H
+36.77 46 S/G C
.30 48 DNT 05H
+0.29 46 S/G C 30 77 DNG 20C
+5.28 114 S/G C 31 83 DNG 03H
+6.83 114 S/G C 33 27 DNG 19C
+2.31 6
S/G C 34 12 DNT 10H-
+0.48 6
)
S/G C 34 18 DNT 10H
+0.53 6
S/G C
. 34 42 DNG 06H
+35.40 46 S/G C 34 97 DNG 03H
+13.36 53 S/G C 34 101 DNT 10H
+0.52 53 S/G C DNT 11C
+0.51 53 S/G C 34107 DNT 10H
+0.55 53 S/G C 35107 DNG TSH
+2.54 39 S/G C 37 79 DNG 20C
+1.14 74 S/G C 37 86 DNT 11C
+0.00 72 S/G C 38 19 DNY TSH
-0.06 2
l S/G C 39 18 DNT TSH
+0.20 2
S/G C 39 19 DNT TSH
+0.15 2
l S/G C 39 44 DNT AV4
-1.01 50 l
S/G C 39 45 DNT AV4
-0.64 50 -
S/G C 39 46 DNT AV4
-0.67 50 S/G C 39 47 DNT AV4
-0.72 50 S/G C 39 82 DNT 11C
+0.39 72 S/G C DNT 11C 0.36 -
72 S/G C 40 37 DNT 07H
+18.94 52 S/G C 40 48 DNT 11C
+0.34 52 S/G C 40 68 DNG 16C
+30.59 72 S/G C DNG 16C
+32.28 72 S/G C DNG 16C
+33.33 72
$/G C DNG 16C
+34.41 72 S/G C 41 27 DNT 10H
+0.00 91 S/G C DNT 10H
+0.09 2
S/G C DNT 11C
+0.00 91 S/G C DNT 11C
+0.53 122 S/G C DNT 11C 0.29 122 S/G C DNT 11C
-0.41 2
S/G C 42 33 DNG 19C
-1.29 52 S/G C 42 86 DNG 21C
+1.04 70 S/G C 43 31 DNG 15C
+7.98 52 S/G C 45 23 DNT 10H
+0.28 28 S/G C 45 27 DNG 12C
+44.12 28 l
S/G C 45 29 DNG 10H
+1.08 28 S/G C DNT 10H
+0.40 28 S/G C 45 72 DNG 02H
+10.22 56 S/G C DNG 02H
+16.04 56 S/G C 45 73 DNG 19C
+2.86 56 S/G C 45 88 DNG 03H
+17.88 56 S/G C 46 72 DNG 02H
+20.36 56 S/G C 46 80 DNG 10H
+9.62 56 l
S/G C 46 87 DNT 10H
+0.61 56 l
S/G C 48 28 DNG 06H
+39.51 28 S/G C 48 30 DNG 07H
+14.85 28 S/G C 48 37 DNT AV4
+0.00 56 S/G C 48 88 DNT 10H
+0.40 56 S/G D 1 3 DNG 16C
+3.75 60 S/G D 1 4 DNG 21C
+1.68 86
- Q S/G D DNG 21C
+2.13 60 S/G D DNG 21C 48.51 60 S/G D 1 6 DNG 16C
+1.11 60 S/G D 1 10 DNG 10H
+11.74 62 S/G D 1 58 DNT 10H
+0.53 37 S/G D DNT 10H
+0.68 98 S/G D 2 17 DNG 16C
+3.57 58
BWNS TUBAN !! (Version 1.0) 08/11/1994 12:30:58 South Texas Petject - Unit 2 S/G A,5/G 8,S/G C,S/G D 08/93 RTO f
Bobbin, MAG BIAS 1-C0!L RPC,MRPC - 21% Random, Selected Tube MRPC
\\.
Page 7 Dents and Dings QRY: 08/11/1994 11:07:59 GENERATOR RDW COL IND LOCATION TAPE #
S/G D 2 19 DNT TSH
+3.82 95 S/G D 2 21 JN* 12C
+17.14 58 S/G D 2 B4 Dt., 10H
+6.97 64 S/G D 3107 DNG 10H
+1.23 37 S/G D 5 34 DNT 11C
+0.43 20 S/G D 6 10 ONG 16C
+2.50 16 S/G D 7 52 DNG 08H
+27.85 96 S/G D DNG 08H
+27.99 49 S/G D DNG 08H
+33.79 96 S/G D DNG 086.
+33.89 49 S/G D DNG 08H
+35.97 96 S/G D DhG 08H
+36.09 49 S/G D 7100 DNG 190
+2.93 104 S/G D 8 8 DNG 02H
+25.35 16 S/G D 3 64 DNG O5H
+22.92 48 S/G D DNG 05.
+28.99 48 S/G D 8 70 DNG 01H
+6.93 50 S/G D 9 2 DNG 09H
+15.44 16 S/G D 9 8 DNG 09H
+15.51 16 S/G D 9 17 DNG 09H
+28.40 16 S/G D DNG 09H
+33.46 16 S/G D DNG 12C
+32.84 16 S/G D 9 20 DNG 05H
+4.01 16 S/G D 10 9 DNG 05H
+2.79 16 r-g S/G D DNG 16C
+3.90 16 j
\\sy)
S/G D DWG 20C
+12.56 16 S/G D 10 13 DEG 05H
+3.86 16 S/G D 10 20 DNG 05H
+2.65 16 S/G D DNG 05H
+3.47 16 S/G D DNG 19C
+10.79 16 S/G D 10 24 DNG 19C
-2.18 B8 S/G D DNG 20C
+15.89 16 S/G D 10 26 DNG 21C
+13.31 16 S/G D 10 58 DNG 10H
+2.73 96 S/G D 10 59 DNG 10H
+2.64 96 S/G D 10 60 DNG 10H
+2.86 96 S/G D 11 14 DNG 07H
+13.42 82 S/G D 11 103 DNT 20C
+0.00 75 l
S/G D 12 2 DNG 05H
+3.43 12 S/G D DNG 05H
+15.60 12 S/G D DNG 06H
+1.54 12 S/G D DNG 06H
+3.46 12 S/G D 12 5 DNG 05H
+4.08 12 S/G D 12 6 DNG 09H
+41.91 12 S/G D 12 10 DNG 16C
+2.72 12 S/G D 13 3 DNG 22C
+2.09 12 S/G D DNG 22C
+3.26 12 l
S/G D 13 9 DNG 01H
+9.12 12 l
S/G D 13 10 DNG 09H
+40.47 12 S/G D DNG 09H
+42.13 12 S/G D DNG 09H
+43.13 12 S/G D ONT 10H
+0.12 12 S/G D 13 22 DNG AV1
+2.00 12 5/G D DNG AV1
+13.41 12 S/G D DNG AV4
+1.80 12 S/G D 13 27 DNG 17C
+41.97 12 S/G D 13 51 DNG 01H
+19.93 79 S/G D DNG 01H
+20.11 49 S/C D 13 73 DNG 17C
+18.92 82 S/G D 13 92 DNG 10H
+12.74 71
\\
S/G D DNG 17C
+12.62 71 S/G D DNG AV1
+8.15 71 l
S/G D DNG AV1
+20.05 71 I
S/G D DNG AV4
+ 9.12 71 S/G D 14 4 DNG 09H
+40.74 12
BWNS TUBAN !! (Version 1.0) 08/11/1994 12:30:58 South Texas Project Unit 2 S/G A,S/G B,S/G C,$/G D ee"*****
08/93 RF0
[b
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Bobbin, MAG BIAS 1-Coll RPC,MRPC - 21% Random, Selected Tube MRPC Page 8 t
Dents and Dings QRY: 08/11/1994 11:07:59 GENERATOR ROW COL IND LOCATION 1 APE #
S/G D 14 6 DNG 11C
-1.02 12 S/G D 14 8 DNG 09H
+39.53 12 S/G D 14 9 DNT 10H
+0.06 12 S/G D 14 14 DNG 15C
+3.79 12 S/G D 14 15 DNG 06H
+3.B6 12 S/G D 14 16 DNG 12C
+12.95 12 S/G D 14 17 DNG 12C
+43.00 12 S/G D 14 19 DNG 01H
+11.02 12 S/G D 14 20 DNG 16C
+3.81 12 S/G D DNT Av1
+0.00 12 S/G D 14 81 DNG AV1
+12.72 52 S/G D 14 91 DNG TSH
+1.21 71 S/G D 15 3 DNG 06H
+3.56 12 S/G D 15 19 DNG 01H
+0.94 10 S/G D DNT 11C
-0.50 10 S/G D 15 77 DNG 03H
+10.35 54 S/G D DNG 03H
+11.66 54 S/G D DNG 03H
+22.36 54 S/G D 15 83 DNG 14C
+37.33 54 S/G D 16 3 DNT 10H
+0.47 10 S/G D 16 6 DNG 10H
+1.74 10 S/G D DNT 10H
+0.42 10 S/G D 16 10 DNG 12C
+41.57 10 S/G D DNG 12C
+42.48 10 p "'s S/G D 16 82 DNG AV1
+13.86 54 S/G D 16 117 DNT 12C
-0.36 71 S/G D 17 48 DNG 10H
+38.13 26 S/G D DNG 10H
+62.38 26 S/G D DNT AV4
+0.00 26 S/G D 17 98 DNG 14C
+B.14 71 S/G D 19 77 DNG 08H
+7.69 54 S/G D 19 90 DNG Av3
+3.66 54 S/G D 23 13 DN1 1GH 10.50 8
S/G D 23 57 DNG TSH
+2.24 125 S/G D DNG TSH
+2.46 24 S/G D 23 71 DNG TSH
+2.29 125 S/G D DNG TSH
+2.72 66 S/G D 23 /2 DNG TSH
+2.28 125 S/G D DNG TSH
+2.84 66 S/G D 25 8 DNT 10H
+0.52 10 S/G D 25 26 DNG 06H
+11.70 6
S/G D 26 8 DNG 11C
-1.50 90 S/G D DNT 11C
+0.45 10 S/G D DNT 12C
+44.77 10 S/G D 26 89 DNG 02H
+7.54 104 S/G D 27 13 DNT 10H
+0.53 6
S/G D 29 18 DNT 11C
+0.28 4
S/G D DNT 12C
+44.77 4
S/G D 30 15 DNT 10H
+0.00 4
S/G D 31 22 DNT 11C
+0.46 4
S/G D 35 17 DNT 11C
+0.39 4
S/G D 35 24 DNG 09H
+40.08 4
S/G D DNT 11C
+ 0.36 4
S/G D 35 92 DNG 22C
+17.10 53 S/G D 36 15 DNG 16C
+2.52 4
S/G D DNG 16C
+2.67 88 S/G D DNG 16C
+3.37 4
S/G D DNG 16C
+3.68 88 S/G D DNG 20C
+11.55 4
S/G D DNG 20C
+11.64 88 S/G D 38 19 DNT 11C
+0.33 2
S/G D 38 45 DNG 14C
+39.48 38 S/G D 38 48 DNG 09H
+16.20 38 S/G D 38 66 DNG 06H
+4,40 74
$/G D DNG 07H
+4.21 74
i BWNS TUBAN 11 (Version 1.0) 08/11/1994 12:30:58 i ********
South Texas Project - Unit 2 l ********
S/G A,S/G B,S/G C,S/G D l *
- t***
08/93 RF0 Bobbin, MAG BIAS 1-C0!L RPC.MRPC - 21% Random, Selected Tube MRPC f
Page 9 Dents and Dings QRY: 08/11/1994 11:07:59 l
GENERATOR ROW COL IND LOCATION TAPE #
S/G D 38 77 DNG AV2
+8.13 74 S/G D 39 24 DNT 10H
+0.60 2
S/G D 40 24 DNG 12C
+27.52 2
S/G D DNT 11C
+0.44 2
S/G D DNT 11C
-0.44 2
S/G D 40 25 DNG 18C
+6.35 2
S/G D DNG 18C
+6.62 88 S/C D 40 30 DNG 17C
+15.57 2
S/G D DNG 17C
+17.95 92 S/G D 40 44 DNG 06H
+1.46 40 l
i S/G D DNG 06H
+1.96 40 l
S/G D 41 24 DNG 12C
+34.00 95 S/G D DNG 12C
+35.79 108 i
l S/G D DNG 12C
+36.38 94 S/G D DNG 12C
+36.57 97 i
S/G D DNT 11C
-0.33 95 l
S/G D DNT lic
-0.43 97 j
S/G D DNT 11C
-0.64 94 i
S/G D 41 42 DNG 04H
+0.00 40 l
S/G D 41 102 DNG 13C
+21.18 53 l
S/G D 42 20 DNT 11C
-0.74 98 S/G D 42 21 DNT 11C
-0.74 98 S/G D 42 22 DNT 11C
-0.77 98 S/G D 42 23 DNT 11C
-0.77 98 S/G D 42 45 DNG 04H
+26.92 40 S/G D 43 21 DNT 11C
+0.35 98 S/G D DNT 11C
+0.36 72 S/G D DNT 11C
-0.57 72 i
S/G D DNT 11C
-0.77 98 S/G D 43 22 DNT 11C
-0.57 72 S/G D DNT 11C
-0.74 98 S/G D 43 23 DNT 11C
-0.54 72 S/G D DNT 11C
-0.71 98 S/G D 43 24 DNT 10H
+0.53 98 S/G D DNT 11C
-0.56 72 S/G D DNT 11C
-0.74 98 S/G D 43 25 DNT 11C
-0.54 72 l
S/G D DNT 11C
-0.80 94 S/G D 43 72 DNG 02H
+25.99 76 l
S/G D 43 74 DNT 11C
+0.45 76 S/G D 43 100 DNT AV4 0.12 53
(
S/G D 44 22 DNT 11C
+0.35 72 l
S/G D DNT 11C
+0.41 98 S/G D DNT 11C
-0.68 72 S/G D DNT 11C
-0.71 98 S/G D 44 23 DNT 10H
+0.53 98 S/G D DNT 11C
+ 0.32 98 S/G D DNT 11C
-0.68 72 S/G D DNT 11C
-0.74 98 S/G D 44 24 DNT 11C
+0.44 72 S/G D DNT 11C
+0.50 98 S/G D DNT 11C
-0.56 72 S/G D DNT 11C
-0.65 98 S/G D 44 25 DNT 11C
+0.41 72 S/G D DNT 11C
+0.44 98 S/G D DNT 11C
-0.62 72 S/G D DNT 11C
-0.71 98 S/G D 44 27 DNG TSH
+5.09 95 p
S/G D 44 71 DNT 10H
+0.62 76 S/G D 44 72 DNG 12C
+41.15 76 S/G D DNT 10H
+0.51 76 S/G D 44 99 DNT AV4
-0.06 53 S/G D 45 23 DNT 11C
+0.32 98 S/G D DNT 11C
+ 0.33 72 S/G D DNT 11C
-0.71 72 l
I BWNS TUBAN !! (Version 1.0) 08/11/1994 12:30:58 South Texas Project - Unit 2 S/G A,S/G B,S/G C,S/G D j"**
08/93 RF0
\\
Bobbin, MAG BI AS 1-Coll RPC,MRPC - 21% Random, Selected Tube MRPC Page 10 Dents and Dings CRY: 08/11/1994 11:07:59 GENERATOR ROW COL 1ND LOCAT10N 1 APE #
S/G D DNT 11C
-0.77 98 S/G D 45 24 DNT 11C
+0.35 98 S/G D DNT 11C
-0.74 98 i
S/G D 45 25 DNT 11C
+0.41 98 S/G D DNT 11C
-0.70 98
$/G D 45 44 DNG 07H
+36.05 42 S/G D 46 24 DNT 11C
+0.32 98 S/G D DNT 11C 0.76 98 S/G D 46 25 DNT 11C
+0.35 98 S/G D DNT 11C
-0.79 98 S/G D 46 26 DNT 11C
-0.74 98 S/G D 46 43 DNT 10H
+0.35 42 S/G D 46 97 DNG TSH
+0.99 47 S/G D 47 26 DNT 11C
-0.67 98 i
S/G D 47 40 DNG 10H
+0.72 42 S/G D 47 94 DNG 10H
+24.21 47 Total Indications Found = 601 Total Tubes round = 382 O
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APPENDIX 3-F 1
OWNER'S REPORT FOR INSERVICE INSPECTIONS NIS-1 FORM i
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i 1993 ISI - 2RE03 - Steam Generator Tubes Page 1 of 2 FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS As required by the Provisions of the ASME Code Rules
- 1. Owner Houston L.ichtinn & Power Company: Electric Tower: P.O. Box 1700: Ilouston. Texas 77001 (Name and Address of Owmer)
'(
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89
- 6. National Board Number for Unit N.A.
- 7. Components Inspected ASME Code Class 1 (lWB) Items - Steam Generator Tubes Manufacturer Component or Manufacture or Installer National l
Appurtenance or Installer Serial No.
Board No.
Steam Gcneratur 2A Westinchouse (M) 2151 29
{
Steam Generator 2B Westinehouse (M) 2152 30 Steam Generator 2C Westinchouse (M) 2153 31 1
Steam t
l Generator 2D Westinehouse (M) 2154 32 I
)
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IIL&P by N'
Date Y21/T'f Factory Mutual by ww#
Date 8'28M S. Timmaraju System B. R. Russell, ANil I
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1993 ISI - 2RE03 - Steam Generator Tubes Page 2 of 2 FORM NIS-1 (Back)
- 8. Examination Dates 8-21-93 to 9-4-93
- 9. Inspection Interval from 06/19/89 to 06/19/99 10.
Abstract of Examinations. Include a list of examinations and a statement concerning status of work required for current interval. (ASME Code Class 1 (lWB) Items - Steam Generator Tubes)
See Section 3.4 of the 2RE03 Summary Report.
I1.
Abstract of Conditions Noted.
See Section 3.5 of the 2RE03 Summary Report.
12.
Abstract of Corrective Measures Recommended and Taken.
See Section 3.5 of the 2RE03 Summary Report.
i We certify that the statements made in this report are correct and the examinations and corrective measures taken conform to the rules of ASME Code,Section XI.
Certificate of Authorization No.(if applicable)
N.A.
Expiration Date N.A.
Date
- 1 %
19 % Signed Houston Lichtine & Power Co. By "y '
Owner S. Timmaraju l
CERTIFICATE OFINSERVICE 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 Texas and employed by Arkwricht Mutual in urance Co. of Norwood.
Mass have inspected the components described in this Owner's Report during the period 8.:2 / -G,3 to _
(7-4-43 '. and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owner's Report in accordance with the inspection plan and as required by the ASME Code,Section XI.
By signing this certificate neither the Inspector nor his employer makes any warranty, express or implied, concerning the examinations 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 j
any kind arisi from or connected with this inspection.
Factory Mutual Engineering Association W2u Commissions Tex 826 Inspector's Signature National Board, State, Province, and Endorsements B. R. Russell Date 0 4 3 19 9 4 l
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O 4.0 COMPONENT SUPPORT EXAMINATIONS L./
4.1 Introduction ISI of Class 1,2, and 3 component supports and Class 3 integral attachments of STPEGS-2 was performed between February 16, 1993 and May 11, 1994. These examinations constitute the third ISI (the first ISI of the second period) of the first inspection interval for the Component Supports Examination Program for STPEGS-2.
This Section of the Summary Report documents the examinations of component supports performed by HL&P OC NDE personnel in accordance with the following documents:
(1)
HL&P Specification 5UO36JS004, " Inservice Inspection Examination of Component Supports of South Texas Project Electric Generating Unit 2 First Inspection Interval",
(2)
" Examination Plan for the 1993 - 2RE03 Inservice Inspection at the South Texas Project Electric Generating Station, Unit 2" including changes made during the l
outage (Outage Plan).
l The HL&P Specification provides a detailed description of the rules for exemption and lq selection of Class 1,2, and 3 component supports for ISI. The 1993 Examination Plan is
'()
an individual Outage Plan for implementing ISI component support examinations as designated in the HL&P Specification.
4.2 Scope of Examinations A total of eighty-three(83) component supports were visually examined during 2RE03.
Class 1 Eight(8) Class I piping supports and three(3) Class I equipment support were examined in the following systems:
Pipina Equipment i
Chemical & Volume Control (CV) 1 0
Reactor Coolant (RC) 5 3
Residual Heat Removal (RH) 1 0
Safety Injection (SI) 1 0
4-1
4 e
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'O Class 2
~
Twenty-seven(27) Class 2 piping supports and no Class 2 equipment supports were j
1 j
examined in the following systems:
Piping E_quinment j
Auxiliary Feedwater (AF) 2 0
Containment Spray (CS) 2 0
Main Steam (MS) 1 0
j Residual Heat Removal (RH) 6 0
Safety Injection (SI) 15 0
4
)
Class 3 Thirty-nine(39) Class 3 piping supports and six(6) Class 3 equipment supports were i
examined in the following systems:
l Pipine Eouipment Auxiliary Feedwater (AF) 7*
6 ~
l Component Cooling (CC) 25 1
Diesel Generator Jacket Water (JW) 0 2
4 p Diesel Generator Lube Oil (LU) 0 3
3i V Essential Cooling Water (EW) 7*
0
A complete list of component supports examined during 2RE03 is contained in Appendix 4-A.
These examinations constitute the following percentages of completion for Class 1,2, and 3 component supports:
Cumulative 2RE03 (1st Interval)
Class 1(IWF) 13 %
34 %
Class 2(IWF) 12 %
39 %
Class 3(IWF) 13 %
37 %
O 4-2
i 4.3 Personnel and Procedures 4.3.1 Personnel Qualifications Component supports were visually examined (VT-3 and VT-4) by HL&P QC NDE personnel certified in accordance with ASME Section XI (IWA-2300) and HL&P Nondestructive Examination Procedure NDEP 1.0 (Rev. 3), " Qualification and Certification for Examination Personnel". A listing of the personnel who performed visual examinations of component supports, including their certification level, is included in Appendix 4-B.
4.3.2 Examination Procedure Visual (VT-3 and VT-4) examinations of component supports were performed in accordance with NDEP 9.2 (Rev. 0), " Visual Examination of Component Supports for ASME XI Inservice Inspection".
4.4 Summary of Examinations Seventy-four(74) piping supports and nine(9) equipment supports were examined during 2RE03 as shown in Appendix 4-A.
4.4.1 Examination Results and Corrective Actions Two relevant conditions were found as shown in Table 3-1. In each case, the support was analyzed to substantiate its integrity for its intended service and found to be acceptable.
However, these supports were reworked to bring the spring settings back into tolerance.
Table 4-1 Summary of Component Support Visual Indication Disposition Component ID Condition SR No.
Disposition CV-2121-HS5004 Spring Hanger setting 158439 Rework (Completed) out of tolerance RH-2205-HL5013 Spring Hanger setting 178698 Rework (Completed) out of tolerance O
4-3
\\
b 4.4.2 Additional and Successive Examinations s
The results of the visual examinations of component supports performed during 2RE03 did not require that any additional examinations (IWF-2430) be performed or any successive l
examinations (IWF-2420) be scheduled.
4.5 Certification of Inspections l
Section XI NIS-1 forms, " Owner's Report for Inservice Inspections", have been prepared to j
certify the STPEGS-2 component support ISI examinations described in this section of the Summary Report. The STPEGS-2 component support ISI examinations have been certified by our ANII, Factory Mutual Engineering Association, on the NIS-1 forms included in Appendix 4-C.
O 4-4
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APPENDIX 4-A
SUMMARY
OF EXAMINATIONS O
i O
l DAT E: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
1 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS) s
(
FIRST INTERVAL, SECOND PERIOD, FIRST CUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS CHEMICAL &V0lUME CONTROL 1 N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R " CALIBRATION BLOCK **
1 2-CV-2121-BB1-A1A1
(
j 100400 CV-2121-HS5004 PIPING VT-3 NDEP 9,2 R0 X - EXAMINED VHEN FILLED. $PRING SH-V VT-4 X - -
HANGER SETTING WAS FOUND OUT OF TOLERANCE. ALTHOUGH THE SUPPORT WILL MEET ITS INTENDED FUNCTION, IT WAS BE l
REWORKED PER SR#15B439 To BRING THE SETTING BACK INTO TOLERANCE AND REEXAMINED, I
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DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
2 j
p REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS REACTOR COOLANT 1 N
O ASME O G T
)
SEC. XI R E H I
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLOCK **
12-RC-2125-881-B 103800 RC-2125-HL5004 PIPING VT-3 NDEP 9.2 R0 X - -
4 RR u
l 4-20-2123-881-B l
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107200 RC-2123-SH02 PIPING VT-3 NDEP 9.2 R0 X - EXAMINED WHEN FILLED.
SH-V VT-4 X - -
)
4-RC-2123-891-C-107300 RC-2123-HL5003 PIPING VT-3 NDEP 9.2 R0 X - -
RR 107400 RC-2123-RR16 PIPING VT-3 NDEP 9.2 RD X - -
j RR l
4-RC-2123-BB1-G l
I 108000 RC-2123-SHOS PIPING VT-3 NDEP 9.2 RO X - -
93'- EXAMINED WHEN FILLED.
j SH-V VT-4 X - -
I
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~....
l DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
3 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS MSIDUAL HEAT REMOVAL 1 N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEH NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
8-RH-2208-831-A 114500 RM-2208-ML5003 PIPING VT-3 NDEP 9.2 R0 X - -
RR b
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DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
4 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
\\
CLASS 1 COMPLETED COMPONENTS l
SAFETY INJECTION 1 I
N 0
ASME O G T SEC. XI RE H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLOCK **
6-SI-2208-BB1-A i
116300 SI-2208-RR01 PIPING VT-3 NDEP 9.2 R0 X - -
RR F
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I DATE: 05/17/94 SOL'TH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
5 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS) k FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 1 COMPLETED COMPONENTS REACTOR COOLANT 1 N
O ASME O G T j
SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTI FICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLCCK**
I j
1R112NPZ101A 116700 PRS 1 EQUIP VT-3 NDEP 9.2 R0 X - $1NGLE SUPPORT CONFIGURATION FOR RC PRES RELF THE SAFETY AND RELIEF VALVES LOCATED AT THE TOP OF THE PRESSURIZER, REF DWGS:
6 0140-00049, 0140-00050, 0140-00051, 0140-00052, 0140-00053, 0140-00054, l
0140-00055.
116800 PRU1 EQUIP VT-3 NOEP 9.2 RO X - -
93 - THE UPPER SUPPORT LOCATED NEAREST RC PRES UPPR THE REACTOR VESSEL (EAST MOST) ON THE PRESSURIZER. REF DWGS: 1C01-9-s-1532,
-1537, 0957-00010, 0130-00001.
1 1
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117100 PRU4 EQUIP VT-3 NDEP 9.2 R0 X - AS VIEWED FROM ABOVE, THE UPPER RC PRES UPPR SUPPORT IMMEDIATELY COUNTERCLOCK' WISE FROM PRU1. REF OWGS: 1C01-9-S-1532, 0957-00010, 0130-00001.
I I
)
O 1
DAT E: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
6 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 2 COMPLETED COMPONENTS AUXILIARY FEEDWATER 2 N
O ASME D G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
j 8-AF-2012-GA2-H 206200 AF-2012-HL5012 PIPING VT-3 NDEP 9.2 R0 X - -
RR 6-AF-2012-CA2-N 207300 AF-2012-HL5032 PIPING VT-3 NDEP 9.2 R0 X - EXAMINED WHEN FILLED.
SH-V VT-4 X - -
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DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC CENERATING STATION UNIT 2 PAGE:
7 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS) l FIRST INTERVAL, SECOND PERIOD, FIP.ST OUTACE (93RF)
)
CLASS 2 COMPLETED COMPONENTS CONTAINMENT SARAY 2 N
O ASME O G T
)
SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS j
NUMBER IDEN11FICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
l 8-cs-2302-PB2-0 214700 CS-2302-RH04 PIPING VT-3 NDEP 9.2 RD X - -
i RR 214800 CS-2302-RR05 PIPING VT-3 NDEP 9.2 R0 X - -
RR 1
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GEdERATING STATION UNIT 2 PAGE:
8 REVISION:
0 INSERVIr! INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL, SECOND PERIOD, FIRST CUTAGE (93RF)
CLASS 2 COMPLETED COMPONENTS J
FEED WATER 2
)
N O
ASME O-G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
j 18-rw-2016-GA2-D
]
t l
220300 FW-2016-HL5001 PIPING VT-3 NDEP 9.2 R0 X - -
RR I
1 l
I 1
l 1
1 l
. -... ~.......
~
- - - - - - -. -. -. - - -. - -. ~..... -. - -
i 1
i a
i DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
9 I
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
@ REVISION:
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (95RF)
CLASS 2 COMPLETED COMPONENTS MAIN STEAM 2 i
N O
j ASME O G T SEC, XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS i
NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLOCK **
1 i
30-MS-2003-GA2-E l
1 1
226100 MS-2003-HL5003 PIPING VT-3 NDEP 9.2 R0 X - -
i, SH-V (2)
VT-4 X - -
i e
i i
1 i
I l,
i 1
I 1
O 1
I 1
i i
i l
l 1
l-1
. _..... _,.. -. _ _. _... -.. -, _,.. -. - _ _......., _ =,,.... _
i l
DAT E: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
10 I
p
REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
(
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 2 COMPLETED COMPCNENTS RESIDUAL HEAT REMOVAL 2 N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
8-RH-2103-KB2-A 231400 RM-2103-RR11 PIPING VT-3 NDEP 9.2 R0 X - -
RR 8-RH-2103-KB2-F 232500 RM-2103-RR03 PIPING VT-3 NDEP 9.2 R0 X - -
l 1
RR l
8-Rd-2204-KB?-D 235900 RH-2204-HL5005 PIPING VT-3 NDEP 9.2 RD X - -
GUIDE t
8-Rw-2204-rB2-F r
236400 RH-2204-RR10 PIPING VT-3 NDEP 9.2 R0 X - -
RR 8-RW-2205-rB2-A 237000 RM-2205-HL5013 PIPING VT-3 NDEP 9.2 RD X - -
EXAMINED WHEN FILLED. SPRING HANGER SH-V (2)
VT-4 X - - SETTINGS WERE FOUND OUT OF TOLERANCE.
ALTHOUGH THE SUPPORT WOULD STILL PERFORM ITS INTENDED FUNCTION, THE SUPPORT WAS REWORKED PER SR#178698 TO BRING THE SETTINGS BACK INTO TOLERANCE AND REEXAMINED.
8-R4-??05-re?-B 237200 RH-2205-SH10 PIPING VT-3 NDED 9.2 R0 X - -
93 - EXAMINED WHEN FILLED.
SH-V (2)
VT-4 X - -
i j
i DATE: 05/17/94
' SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
11 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 2 COMPLETED COMPONENTS SAFETY INJECTION 2 N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
~
16-SI-2101-UB2-P 246100 SI-2101-HL5005 PIPING VT-3 NDEP 9.2 R0 X - EXAMINED WHEN FILLED.
SH-V VT-4 X - -
10-SI-2101-Ue2-v 253300 SI-2101-RR23 PIPING VT-3 NDEP 9.2 RD X - THIS SUPPORT WAS SUPPOSED TO BE RR EXAMINED AFTER INSTALLATION OF JAM NUT PER SR#311567. HOWEVER, THE BOLT j
THREADS WERE STAKED (REF #JS1002) AND JAM NUT IS NOT REQUIRED.
f 6-SI-2106-DB2-rA 265100 SI-2106-RR72 PIPING VT-3 NDEP 9.2 R0 X - -
RR 265200 SI-2106-RR73 PIPING VT-3 NDCP 9.2 R0 X - -
RR 6-SI-2106-032-L 265300 SI-2106-RR69 PIPING VT-3 NDEP 9.2 RD X - -
RR 6 SI-2106-DB2-M i
265400 SI-2106-HL5001 PIPING VT-3 NDEP 9.2 R0 X - -
l l
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
12 1
REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS) 7 am FIRST INTERVAL, SECOND PERIOD, FIRST OUTA0E (93Rr)
( j CLASS 2 COMPLETED COMPONENTS SAFETY INJECTION 2 N
O ASME O G T SEC, XI R E H SUMHARY EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
6-51-2106-032-0 266700 SI-2106-RR51 PIPING VT-3 NDEP 9.2 R0 X - -
RR 266800 SI-2106-RR52 PIPING VT-3 NDEP 9.2 RD X - -
RR 266900 SI-2106-RR74 PIPING VT-3 NDEP 9.2 R0 X - -
l RR 7
l i
I r
i i
267000 S!-2106-RR75 PIPING VT-3 NDEP 9.2 R0 X. -
RR i
267100 SI-2106-RR76 PIPING VT-3 NDEP 9.2 R0 X - -
RR 267200 $1-2106-RR77 PIPING VT-3 NDEP 9.2 R0 X - -
RR l
l 267300 SI-2106-RR78 PIP!NG VT-3 NDEP 9.2 RO x - -
l RR I
1 l
2-SI-2139-DB2-D-Al f
278700 SI-2139-HF5005 PIPING VT-3 NDEP 9.2 RD X - -
GUIDE l
t l
l
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
13 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
O FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLA$5 2 COMPLETED COMPONENTS SAFETY INJECTION 2 N
O ASME O G T SEC. XI R E H
$UMMARY EXAMINATION AREA CATGY EXAM E D E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
2-SI-2139-082-D-A1 278800 SI-2139-HF5006 PIPING VT-3 NDEP 9.2 R0 x-GUIDE I
l i
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
14 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL. SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 3 COMPLETED COMPONENTS AUXILIARY FEEDWATER 3 N
O ASME O G T SEC. XI R E H iUMMARY EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLOCK **
i 12-AF-2054-WA3-E 300000 AF-2054-HL5001 PIPING VT-3 NDEP 9.2 R0 X - EXAMINED AFTER REMOVAL AND RR REINSTALLATION OF THE STRAP PER SR#
310257.
/. AF-2011-GA3 NA 310900 AF-2011-HL5001 PIPING VT-3 NDEP 9.2 R0 X - -
RR 1.5-AF-2030-CA3-AA01 316500 AF-2030-HF5001 PIPING VT-3 NDEP 9.2 R0 X - -
GUIDE 1.5-AF-2053-CA3-CA03 316900 AF-2053-HF5003 PIPING VT-3 NDEP 9.2 RO X - -
CUIDE 317000 AF-2053-HF5004 PIPING VT-3 NDEP 9.2 R0 X - -
GUIDE 1
1 317100 AF-2053-HF5005 PIPING VT-3 NDEP 9.2 R0 X - -
GUIDE 1, 5-A F-20 56-GA 3-A A01 319000 AF-2086-HF5001 PIPING VT-3 NDEP 9.2 RD X - -
U-BOLT i
i
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
15 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 3 COMPLETED COMPONENTS COMPONENT COOLING 3 N'
O ASME D G'T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
24-CC-2102-WA3-B 320500 CC-2102-HL5001 PIPING VT-3 NDEP 9.2 RD X - EXAMINED AFTER STRUT CHANGEOUT PER RR SR# 146612, 24-CC-2102-WA3-C 320F00 CC-2102-GUO4 PIPING VT-3 NDEP 9.2 R0 X
GUIDE 24-CC-2102-WA3-E
'T
,_.s/
320900 CC-2102-GOO 2 PIPING VT-3 NDEP 9.2 R0 X - -
GUIDE 6
24-CC-2102-WA3-F 321000 CC-2102-NL5002 PIPING VT-3 NDEF 9.2 R0 X - -
GUIDE J
l 24-CC-2110-WA3-C l
l 321300 CC-2110-HL5002 PIPING VT-3 NDEP 9.2 R0 X - -
[
RR 20-CC-2106-WA3-A 326200 CC-2106-SHQ1 PIPING VT-3 NDEP 9.2 RD X - EXAMINED WHEN FILLED.
SH-V VT-4 X - -
O l'
i
1 DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION LINIT 2 PAGE:
16
(
REVISION:
0 INSERVICE INSPECTION REPORT - 2RE05 (SUPPORTS)
FIRST INTERVAL, SECONO PERIOD, FIRST OUTAGE (93RF)
CLASS 3 COMPLETED COMPONENTS COMPONENT C00t.ING 3 N
O ASME O G T SEC, XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R-
- CALIBRATION BLOCK **
20-CC-2110-WA3-E 327200 CC-2110-HL5004 PIPING VT-3 NOEP 9.2 R0 X - -
RR 16-CC-2105-WA3-B 332300 CC-2105-RR15 PIPING VT-3 NOEP 9.2 R0 X - -
RR 332400 CC-2105-RR16 PIPING VT-3 NOEP 9.2 R0 X - -
RR v
16-CC-2105-WA3-0 332700 CC-2105-RR13 PIPING VT-3 NOEP 9.2 RO X - -
RR 332800 CC-2105-RR14 PIPING VT-3 NOEP 9.2 R0 X - -
RR l
16-CC-?105-WA3-E 332900 CC-2105-HL5006 PIPING VT-3 NOEP 9.2 R0 X - -
RR 333000 CC-2105-HL5007 PIPING VT-3 NDEP 9.2 R0 X - -
RR o
l
t I
l d
i
{
DATE: 05/17/94 SOUTH TEXAC PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
17 j
i REVISION:
0 INSERVICE INSPECTION REPORT. 2RE03 (SUPPORTS) l
](
FIRST ]NTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
~
CLASS 3 COMPLETED COMPONENTS COMPONENT COOLING 3 J
N O
f ASME D G T l
SEC. XI R E M
[
SUMMARY
EXAM!dATION AREA' CATGY EXAM E O E REMARKS i
NUMBER IDENTIFICATION ITEM NO HETHOD PROCEDURE C H R ** CALIBRATION BLOCK **
1; i
16-CC-2105-WA3-E 4
l 333100 CC-2105-RR11 PIPING VT-3 NDEP 9.2 R0 X - -
RR i
i i
L l
333200 CC-2105-RR12 PIPING VT-3 NDEP 9.d R0 X - -
RR i
i I
i J
16-CC-2105-WA3-G 333400 CC-2105-HL5005 PIPING VT-3 NDEP 9.2 R0 X - -
Ef RR 4
1
+
9 t
j 333500 CC-2105-RR07 PIPING VT-3 NDEP 9.2 RD X - -
8 RR I
1 16-Cc-2105-uA3-H
}
i l
333600 CC-2105-HL5001 PIPING VT-3 NDEP 9.2 RD X - -
l 1
RR 4
l I
I f
333700 CC-2105-HL5002 PIPING VT-3 NDEP 9.2 R0 X - -
4 RR i.
i 333800 CC-2105-RM04 PIPING VT-3 NDEP 9.2 R0 X - -
j RR i
)
d
)
i E
i
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
18 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 3 COMPLETED COMPONENTS COMPONENT COOLING 3 N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METH00 PROCEDURE C M R ** CALIBRATION BLOCK **
i 16-CC-2105-WA3-H 333900 CC-2105-RR03 F..
VT-3 NDEP 9.2 R0 X - -
RR i
l l
16-CC-2105-WA3-K l
334100 CC-2105-SH01 PIPING VT-3 s(P 9.2 R0 X - EXAMINE 0 WHEN FILLEO.
SH-V VT-4 X - -
14-CC-2111-WA3-AA k
344000 CC-2111-HL5001 PIPING VT-3 NDEP 9.2 R0 X - -
RR l
14-CC-7111-WA3-B i
344100 CC-2111-GUO1 PIPING VT-3 NDEP 9.2 R0 X - -
RR 14-CC-2111.WA3-C 344300 CC-2111-SH02 PIPING VT-3 NDEP 9.2 R0 X - -
RR I
%g l
l
~ ~... _...
. - = - - _. -.. - -
DATE: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
19 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF) l CLASS 3 COMPLETED COMPONENTS l
ESSENTIAL COOLING WATER 3 N
O ASME O G T r
i SEC. XI R E H j
SUMMARY
EXAMINATION AREA CATGV EXAM E O E REMARKS l
NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
l l
30-EW-2105-VT3-8 l
l 382600 EW-2105-HL5006 PIPING VT-3 NDEP 9.2 RO X - -
l RR l
382700 EW-2105-HL5007 PIPING VT-3 NDEP 9.2 R0 X
i RR f
10-EW-2107-WT3-A3 408400 EW-2107-HL5002 PIPING VT-3 NDEP 9.2 R0 X - -
GUIDE 6-EV-2107-WT3-A 417100 EW-2107-HL5005 PIPING VT-3 NDEP 9.2 RD X - -
GUIDE 417300 EW-2107-ML5003 PIPING VT-3 NDEP 9.2 R0 X - -
GUIDE 417400 EW-2107-HL5004 PIPING VT-3 NDEP 9.2 R0 X - EXAMINED AFTER REINSTALLATION PEP RR MOD 90-076. REFERENCE SR# 103382.
6-EW-2127-WT3-A 418800 EW-2127-HL5002 PIPING VT-3 NDEP 9.2 RO X - EXAMINED AFTER REMOVAL AND GUIDE REINSTALLATION FOR REPLACING EW FLANGE IN ACCORDANCE WITH SR# 157434
.. - - ~. -. ~.........
DATE: 05/17/94 SOUTM TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
20 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 3 COMPLETED COMPONENTS COMPONENT C00llNO 3 N
O ASME D G T SEC. XI R E H
SUMMARY
EXAMIRATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R ** CALIBRATION BLOCK **
3R20?NDA101A 429500 CCPIA EQUIP VT-3 NDEP 9.2 R0 X - COMPONENT COOLING WATER PUMP 2A -
CC CLG PUMP SINGLE BASE SUPPORT. REF DWGS:
8022-01070, 3M01-9-C-4146.
1 i
DAT E: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
21 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 3 COMPLETED COMPONENTS l
DIESEL JACKET WATER 3 N
O ASME D G T I
SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C H R
- CALIBRATIDN BLOCK **
30152MHT0134
. JACKET WATER HEATER 2A - SUPPORT IS 430600 JWH1A EQUIP VT-3 NDEP 9.2 R0 X
LOCATED CLOSEST TO THE JACKET WATER JW HEATER CIRCULATION PUMP. REF DWG: 8041-01240.
j i
430700 JWH2A EQUIP VT-3 NDEP 9.2 R0 x - JACKET WATER HEATER 2A - SUPPORT IS JW HEATER LOCATED FARTHEST FROM THE JACKET WATER CIRCULATION PUMP. REF DWG: SAME AS JWH1A.
t
.-)
i r
i r.)
DAT E: 05/17/94 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
22 REVISION:
0 INSERVICE INSPECTION REPORT - 2RE03 (SUPPORTS)
(s
(
FIRST INTERVAL, SECOND PERIOD, FIRST OUTAGE (93RF)
CLASS 3 COMPLETED COMPONENTS DIESEL LUBE OIL 3 N
0 1
I ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK **
30152MSA0134 434200 LU1A EQUIP VT-3 NDEP 9.2 R0 x - LUBE OIL PIPE SUPPORT (TRAIN A) -
LU PIPE SUPT SUPPORT IS LOCATED UPSTREAM OF THE LUBE OIL HEAT EXCHANGER INLET, REF DWG:
S041-01240.
i
(
434300 LU2A EQUIP VT-3 NDEP 9.2 RO X -. LUBE OIL PIPE SUPPORT (TRAIN A) -
l LU PIPE SUPT SUPPORT IS LOCATED DOWNSTREAM OF LUBE l
OIL STRAINERS AND ADJACENT TO THE ENGINE l
CONNECTION. REF DWG: SAME AS LU1A.
l l
E l
434400 LU3A EQUIP VT-3 NCEP 9.2 R0 x - LUBE OIL PIPE SUPPORT (TRAIN A) -
I[
LU PIPE SUPT SUPPORT IS LOCATED UPSTREAM OF THE LUBE OIL STRAINER CLOSEST TO THE LUBE CIL CIRCULATION PUMP. REF DWG: SAME AS LU1A.
L
)
4
.. ~. -.. _
l l
l l
1 4
i 1
f APPENDIX 4-B i
PERSONNEL l
4 4
4 d
N Y
1 n
f d
A k
t 4
i APPENDIX 4-B PERSONNEL Name Comnany Level S. K. Hubbard HL&P III R. S. Busby HL&P II L D. Spiess HL&P II C. D. Suhler HL&P II I
4 i
l l
l O
O APPENDIX 4-C OWNER'S REPORT FOR INSERVICE INSPECTIONS NIS-1 FORMS O
i 1993/4 ISI - 2RE03 - Component Supports (Class 1)
Page 1 of 3 FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPFfI1ONS As required by the Provisions of the ASME Code Rules b
- 1. Owner Houston Lichtine & Power Company: Electric Tower: P.O. Box 1700: Houston. Texas 77001 (Name and Address of Owner)
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89
- 6. National Board Number for Unit N.A.
)
- 7. Components Inspected ASME Code Class 1 - Component Supports Progmm i
(Sec Page 3 of 3 for Identification Numbers)
Manufacturer Component or Manufacturer or Installer National Appurtenance or Installer Serial No.
Board No.
Pressurizer Westinchouse (M) 2161 19 Class 1
~
Piping Supports Ebasco (I)
N.A.
N.A.
r r.,u u Date 6-23-4 4 f7n/qy Factory Mutual by HL&P by
%w' Date S. Timmaraju '
Engineering Assoc.
D. R. Russell, ANil
l 1993/4 Ist - 2RE03 - Component Supports (Class 1)
Page 2 of 3 FORM NIS-1 (Back)
Q
- 8. Examination Dates 03/15N3 to 05/1164
- 9. Inspcetion Interval from 06/19/89 to 10/19/00 N'
- 10. Abstri.ct of Examinations. Include a list of examinations and a statement concerning status of work required for current interval. (ASME Code Class 1 Component Supports - Piping and Equipment) l See Section 4.4 and Appendix 4-A of 2RE03 Summary Report for list of examinations performed.
De examinations performed this outage constitute 13% of the required examinations for the current interval. %c cumulative percentage completed for the interval is 34%
(
- 11. Abstract of Conditions Noted.
One support, CV-2121-HS50G1, was found with the spring hanger setting out of tolerana:. His support was analyzed to substantiate its integrity for its intended service and found to be acceptable.
l See Section 4.4.1 of 2RE03 Summary Report.
- 12. Abstract of Corrective Measures Recommended and Taken, Support CV-2121-ilS5004 was reworked to bring the spring hanger setting within tolerance and reexamined. See Section 4.4.1 of 2RE03 Summary Report.
We certify that the statements made in this report are correct and the examinations and corrective measures taken conform to the rules of ASME Code,Section XI.
Certificate of Authorization No.(if applicabic)
N.A.
Expiration Date N.A.
Date friu 19 % Signed Houston Lichtine & Power Co. By
~m.-
d Owner S. Timmaraju d' '
CERTIFICATE OF INSERVICE INSPECTION I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State or Province of Texas and employed by Arkwricht Mutual Insurance Co.
of Norwood. Mass have inspected the components described in this Owner's Report during the period 3-/5-13 to 5s/- #4
. and state that to the best of my knowledge and belief, the i
Owner has performed examinations and taken corrective measures described in this Owner's Report in accordance with the inspection plan and as required by the ASME Code,Section XI.
By signing this certificate neither the inspector not his employer makes any warranty, express or implied, concerning the examinations 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 with this inspection.
Factory Mutual Engineering Association fd AxLl-Commissions Tex 826 Inspector's Signature National Board, State, Province, and Endorsements B. R. Russell Date N 3 19 N i v
1993/4 ISI - 2RE03 - Component Supports (Class 1)
Page 3 of 3 SUPPLEMENT TO FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS ASME Code Class 1 - Component Supports Program i O j
- 1. Owner Houston Lichtinc & Power Company: Electric Tower: P.O. Box 1700: Houston. Texas 77001 l
(Name and Address of Owner)
I
]
(Name and Address of Plant) l
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89
- 6. National Board Number fcr Unit N.A.
PIPING SUPPORT MARK NO.
- TYPE i
j-CV-2121-HS5004 SH-V j
RC-2125-HL5004 RR j
RC-2123-SH02 SH-V 1
RC-2123-HL5003 RR l
l RC-2123-RR16 RR 4
RC-2123-SH08 SH-V
)
RH-2208-HL5003 RR
.l j
SI-2208-RR01 RR EOUIPMENT SUPPORT MARK NO. DESCRIPTION PRS 1 RC PRES RELF i
PRU1 RC PRES UPPR PRU4 RC PRES UPPR l
O 1
HL&P by
^$
Date 17u)W Factory Mutual by wuu Date 8-2,3 N S. Timmaraju Engineering Assoc.
B. R. Russell, ANII m.
l t
1993/4 ISI - 2RE03 - Component Supports (Class 2)
Page 1 of 3 FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS As required by the Provisions of the ASME Code Rules O
- 1. Owner Houston Lichtinc & Power Company: Electric Tower: P.O. Box 1700: Houston. Texas 77001 (Name and Address of Owner)
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89
- 6. National Board Number for Unit N.A.
- 7. Components Inspected ASME Code Class 2 - Component Supports Program (Sec Page 3 of 3 for Identification Numbers)
Manufacturer Component or Manufacturer or Installer National Appurtenance or Installer Serial No.
Board No.
Pipine Supports Ebasco (I)
N.A.
N.A.
O HL&P by NM Date r/n/9Y Factory Mutual by
/o Date 8-G.ffef S. Timmaraju '
Engineering Assoc.
B. R. Russell, ANil
1993/4 ISI - 2RE03 - Component Supports (Class 2)
Page 2 of 3 FORM NIS-1 (Back)
- 8. Examination Dates 02/16/93 to 04/21/94
- 9. Inspection Interval from 06/19/89 to 10/19/00
- 10. Abstract of Examinations. Include a list of examinations and a statement concerning status of work required for current interval. (ASME Code Class 2 Component Supports - Piping and Equipment)
See Section 4.4 and Appendix 4-A of 2RE03 Summary Report for list of examinations performed.
The examinations performed this outage mastitute 12% of the required examinations for the current interval. The cumulative percentage completed for the interval is 39%.
- 11. Abstract of Conditions Noted.
One support, Ril-2205-IIL5013, was found with the spring hanger setting out of tolcrance. This support was analyzed to substantiate its lategrity for its intended service and found to be acceptable.
See Section 4.4.1 of 2RE03 Summary Report.
- 12. Abstract of Corrective Measures Recommended and Taken.
Support RII-2205-IIL5013 was reworked to bring the spring hanger setting within tolcrance and reexamined. See Section 4.4.1 of 2RE03 Summary Report.
We certify that the statements made in this report are correct and the examinations and corrective measures taken conform to the rules of ASME Code,Section XI.
Certificate of Authorization No.(if applicable)
N.A.
Expiration Date N.A, Date Pill f
19 ile Signed Houston Lichtinc & Power Co. By I
Owner S. Timmaraju '
CERTIFICATE OF INSERVICE INSPECI' ION I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State or Province of Texas and employed by Arkwricht Mutual Insurance Co, of Norwood. Mass have inspected the components described in this Owner's Report during the period 2 -/0 73 to 4 -N-14
. and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owner's Report in accordance with the inspection plan and as required by the ASME Code,Section XI.
By signing this certificate neither the Inspector nor his employer makes any warranty, express or implied, concerning the examinations 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 with this inspection.
Factory Mutual Engineering Association
/
H4s Commissions Tex 826 Inspector's Signature National Board, State, Province, and Endorsements B. R. Russell Date 8-B-19 94
1993/4 ISI - 2RE03 - Component Supports (Class 2)
Page 3 of 3 SUPPLEMENT 'ID FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS ASME Code Class 2 - Component Supports Program
- 1. Owner Houston Lichting & Power Company: Electric Tower: P.O. Box 1700: Houston. Texas 77001 (Name and Address of Owner)
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89
- 6. National Board Number for Unli N.A.
PIPING SUPPORT MARK NO.
TYPE AF-2012-HL5012 RR AF-2012-HL5032 SH-V CS-2302-RH04 RR CS-2302-RR05 RR FW-2016-HL5001 RR MS-2003-HL5003 SH-V (2)
RH-2103-RR11 RR RH-2103-RR03 RR RH-22%HL5005 GUIDE RH-2204 RR10 RR RH-2205-HL5013 SH-V (2)
RH-2205-SH10 SH-V (2)
SI-2101-HL5005 SH-V SI-2101-RR23 RR
- f. m SI-21%RR72 RR
(
i SI-2106-RR73 RR SI-2106-RR69 RR SI-2106-HL5001 RR SI-21%RR51 RR SI-21%RRS2 RR SI-2106-RR74 RR SI-2106-RR75 RR SI-2106-RR76 RR SI-2106-RR77 RR SI-2106-RR78 RR SI-2139 HF5005 GUIDE SI-2139 HF5006 GUIDE HL&P by
+%'
Date 51n/W Factory Mutual by so Date 6-23 %
S. Timmarajd Enginecting Assoc.
B. R. Russell, ANil
1993/4 ISI - 2RE03 - Component Supports (Class 3)
Page 1 of 3 FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS
{
As required by the Provisions of the ASME Code Rules i
)
- 1. Owner Houston Lichtine & Power Company: Electric Tower: P.O. Box 1700: Houston. Texas 77001 (Name and Address of Owner)
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89
- 6. National Board Number for Unit N.A.
j
- 7. Components Inspected ASME Code Class 3 - Component Supports Program
- (See Page 3 of 3 for Identification Numbers)
Manufacturer Component or Manufacturer or Installer National Appurtenance or Installer Serial No.
Board No.
Component Cooling Hayward ' Iller Jacket Water ~
Pumn Co. (M) 804101 7
Water Pumn 2A Heater E.L Wiegand (M) 9B1501 1510 DG Lube Oil Cooper Energy i
Pine Sunnort Sersices (M) 8K1705 N.A.
l DG Lutid Oil Cooper Energy
)
Pine Sunnort Services (M) 8K1707 N.A.
DG Lutid Oil Cooper Energy Pine Sunnort Services (M) 8K1709 N.A.
C1' ass 3 '~
l Piping Sunports Ebasco (I)
N.A.
N.A.
i i
l
~'-w' Date fil2/cty Factory Mutual by Date d'2M HL&P by S. Timmaraju '
Engineering Assoc.
B. R. Russell, ANil
1993/4 ISI - 2RE03 - Component Supports (Class 3)
Page 2 of 3 FORM NIS-1 (Back)
- 8. Examination Dates 02/16/93 to 03/28/94
- 9. Inspection Interval from 06/19/89 to 10/19/00 v
- 10. Abstract of Examinations. Include a list of examinations and a statement concerning status of work required for current interval. (ASME Code Class 3 Component Supports - Piping and Equipment)
See Section 4.4 and Appendix 4-A of 2RE03 Summary Report for list of cxaminations performed.
The examinations performed this outage constitute 13% of the required examinations for the current interval The cumulative percentage completed for the interval is 37%
- 11. Abstract of Conditions Noted.
None.
- 12. Abstract of Corrective Measures Recommended and Taken.
None.
We certify that the statements made in this report are correct and the examinations and corrective measures taken conform to the rules of ASME Code,Section XI.
Certificate of Authorization No.(if applicable)
N.A.
Expiration Date N.A.
- b 19 % Signed Houston Iichtine & Power Co. By
['
Date ww '~
I Ownct S. Timmaraju CERTIFICATE OF INSERVICE INSPECTION p
I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State or Province of Texas and employed by Arkwricht Mutual Insurance Co.
of Norwood. Mass have inspected the components described in this Owner's Report during the period 2 -/6 -4,3 to d'-2B 4d
. and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective measures described in this Owner's Report in accordance with the inspection plan and as required by the ASME Code,Section XI.
By signing this certificate neither the Inspector nor his employer makes any warranty, express or implied, concerning the examinations and corrective measures described in this Owner's Report.
i Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or pro crty damage or a loss of any kind arising from or connected with this inspection.
Factory Mutual Engineering Association mo-M/o Commissions Tex 826 Inspector's Signature National Board, State, Province, and Endorsements B. R. Russell Date
- 23-19 94-1
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4-J Ae h
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- + _
i 1993/4 ISI - 2RE03 - Component Supports (Class 3)
Page 3 of 3 SUPPLEMENT TO FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS I
ASME Code Class 3 - Component Supports Program V
- 1. Owner Houston Lichtinc & Power Company: Electric Tower: P.O. Box 1700. Houston. Texas 77001 (Name and Address of Owner) l
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/89
- 6. National Board Number for Unit N.A.
PIPING SUPPORT MARK NO.
TYPE AF-2054-ilL5001 RR AF-2011-1IL5001 RR AF-2030-IIF5001 GUIDE AF-2053-IIF5003 GUIDE AF-2053-IIF5004 GUIDE AF-2053-liF5005 GUIDE AF-2086-IfF5001 U-DOLT CC-2102-1IL5001 RR CC-2102 GUG4 GUIDE CC-2102-GUO2 GUIDE -
CC-2102-11tJ002 GUIDE CC-2110-IIL5002 RR CC-2106-SII01 Si!.V CC-2110-HL5004 RR CC-2105-RR15 RR l
CC-2105-RR16 RR CC-2105-RR13 RR C2-2105-RR14 RR CC-21051IL5006 RR
)
CC-2105-1IL5007 RR l
V CO 2105-RR11 RR CC-2105-RR12 RR CC-2105-liL5005 RR CC 2105-RR07 RR CC 2105-1IL5001 RR CC-2105-1IL5002 RR j
CC-2105-RH04 RR 2
CC-2105 RR03 RR CC-2105-SH01 Sil V l
CC-2111-1IL5001 RR CC-2111 GU01 RR l
CC-211151102 RR EW-2105-liL5006 RR l
EW-2105-HL5007 RR EW-2107-HL5002 GUIDE EW-21071IL5005 0UIDE EW 2107-1IL5003 GUIDE EW 2107-1113004 RR EW-2127-1IL5002 GUIDE FOUTPMENT SUPPORT MARK NO. DESCRIPTION CCPIA CC CLG PUMP JWillA JW !! EATER JWil2A JW llEATER LUIA LU PIPE SUPT LU2A LU PIPE SUPT LU3A LU PIPE SUPT Date @2koy Engineering Assoc.
Factory Mutual by
- hMo Date &M4 HL&P by
- W S. Timmaraju B. R. Russell, ANil f
i
.-