ML20070M610
| ML20070M610 | |
| Person / Time | |
|---|---|
| Site: | South Texas  |
| Issue date: | 03/04/1991 |
| From: | Haning J, Mcintyre A, Younger J HOUSTON LIGHTING & POWER CO. |
| To: | |
| Shared Package | |
| ML20070M603 | List: |
| References | |
| NUDOCS 9103210316 | |
| Download: ML20070M610 (67) | |
Text
. _ _.
o SOUTH TEXAC ' ' ECT ELECTRIC ' ' '
1NG
- STA, 2RE01 INSERVICE INSPECTION
SUMMARY
REPORT FOR WELDS, STEAM GENERATOR TUBING, AND-COMPONENT SUPPORTS of the SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION - UNIT 2 P.O. Box 289 Wadsworth, Texas 77483 Owner:
Houston Lighting and Power Company City Public Service Boord of Son Antonio Centrol Power and Light Company City of Austin i
Address:
P.O. Box 1700 Houston, Texas 77001 Commercial Operation:
JUNE 19,1989 I
l Issue Date:
MARCH 1991 STP W-0818A EAR"A886R3a888?99U G
O 2RE01 INSERVICE INSPECTION
SUMMARY
REPORT FOR WELDS, STEAM GENERATOR TUBING, AND COMPONENT SUPPORTS of the l
i SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT NO. 2 4
USNRC DOCKET NO.: 50-499 OPERATING LICENSE NO.: NPF 80 l
1 COhlh!ERCIAL OPERATION DATE: JUNE 19,1989 Prepared by:
[
7/23/91
/w J.[. Yo ger / w
' Dat'e I
l Engineer - Welds & Component Supports
.M
.-[mi Prepared by:[jL IIaning s - ts - 0 O
Date ISI Engineer - Steam Generator Tubing Reviewed by:
8-co 1/
R. L Beverly
[]
Date Supervising Yngineer ISI Group Approved by:-
/1C 7hC M M
~3 - # _ 9 i A. C. hicIntyre Date hianager - Design Engineering Depaitment l
TABLE OF CONTEN'IS O
1.0 2RE01
SUMMARY
REPORT P_agg 1.1 Introduction 11 1.2 Scope of Summary Report 11 2.0 WELD EXAMINATIONS 2.1 Introduction 21 2.2 Scope of Examinations 21 2.3 Personnel, Procedures, and Equipment 22 2.3.1 Personnel Qualifications 22 2.3.2 Examination Procedures 23 2.3.3 Equipment 23 2.3.4 Materials 24 2.3.5 Calibration Blocks 24 2.4 Summary of Examinations 2-4 2.4.1 Examination Methods 24 2.4.2 Augmented Examinations 25 2.4.3 Data Comparison 25 2.4.4 Additional and Successive Examinations 25 4
2.5 Examination Results and Corrective-Actions 25 1
2.6 Certification of Inspections 26 Appendix 2 A Summary of Examinations 27 Appendix 2 B Personnel / Equipment /Matvials 2-40 l
Appendix 2 C Procedures 2-46 i
Appendix 2 D ISI Examination Limitations 2 51 Appendix 2 E Owner's Report for Inservice Inspections - NIS 1 Form 2 66 l-i i
TABLE OF CONTENTE (cont'd)
O 3.0 STEAM GENERATOR TUBING EXAMINATIONS 3.1 Introduction 31 3.2 Scope of Examinations 31 3.3
. Personnel, Procedures, and Equipment 32 3.3a Personnel Qualifications M
3.3.2 Examination and Analysis Prect, >rc S-2
? 13 - Equipment 33 Calibration Standards 3-3.
3.
3.4 Summary of Examinations 3-4 3.4.1 Technical Specification Examinations 3 3.4.2 Augmenting Examinations 35 3.5 Examination Results and Corrective Actions 36 3.6 Certification of Inspections 3-8 Appendix 3 A Changes to the ISI Outage Plan 39 Appendix 3 B List of Examination and Data Analysis Personnel 3 18 Appendix 3-C Oscillographs and System Response Curves for Flaws Greater Than 20 Percent 3 20 Appendix 3 D Flaws with Tube. Wall Thickness Reduction 3-23 Appendix 3-E Dings and Dents 3 25 Appendix 3-F Owner's Report for Inservice Inspections - NIS-1 Form 3 27 i
ii
TABLE OF CONTENTS (cont'd) 4.0 COMPONENT SUPPORT EXAMINATIONS 4.1 Introduction 41 4.2 Scope of Examinations 4-1 4.3 Personnel and Procedures 4-2
-l l
l 4.3.1 Personnel Qualifications 42 4.3.2 Examination Procedure 43 l
4.4 Summary of Examinations 43 4.4.1 Piping and Equipment Supports 4 4.4.2 Additional and Successive Examinations 4-3 4.5 Examinativn Results and Corrective Actions 4-3 4.6 Certification of Inspections 4-4 O
Arve et 4-^
se - - erv er exe -ieetie -
4-s Appendix 4 B Personnel 4-30 Appendix 4 C --
hvner's Report for Inservice spections - NIS 1 Forms-4 32 i
l l
lO m
l
1.0 2RE01
SUMMARY
REPORT 1.1 Introduction This Summary Report describes Houston Lighting & Power Company's (HI.AP) inservice.
inspection (ISI) of selected Class 1,2, and 3 components of the South Texas Project Electric Generating Station, Unit 2 (STPEGS 2) performed from August 31,1990 to.
completion of the first refueling outage (2RE01) on December 11,1990. The ISI summarized herein constitutes the first inservice examinations performed during the first.
inspection period of the first inspection interval of STPEGS-2. The STPEGS ISI program 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 first ten year inspection interval of STPEGS-2 extends to June 19, 1993. The first inspection period, which is of three years duration beginning with commercial operation (June 19, 1989), extends to June 19, 1992. The ISI examinations performed up through 2RE01 partially satisfy the Section XI Code completion requirements for the first inspection period.
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 s
Code for welds, steam generator tubing, and component supports and those of Technical Specification 4.4.5.5 (b) with regard to steam generator tubing inspection.
1.2 Scope of Summary Report This Summary Report describes the ISI examinations performed up through 2RE01 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 I 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 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.
Subsection 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 1-1 l
m..
.=
i Class 1, 2, and _3 component supports and Cass 3 integral attachments are described in O
Section 4. These examinations were performed in accordance with Subsection IWF (Qass 1, 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.-
T Q
F 2 i
2.0 WELD EXAMINATIONS 2.1 Introduction ISI of STPEGS 2 Class 1 and 2 welds and components within the Welds Eumination -
Program was performed between August 31 and November 8,1990. - These examinations constitute the first ISI of the first inspection interval for the Welds Examination Program-for STPEGS-2.
This section of the Summary Report ' documents the examinations performed by Southwest.
i Research Institute (SwRI) and HL&P Quality Control (QC) 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),
(2)-
" Examination Plan for the 1990 - 2RE01 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, selection, allocation, and scheduling of Class 1 and 2 welds and examination areas for ISI.
O The 1990 Examination Plan is an individual Outage Plan for implementing ISI weld i
examinations as scheduled in the LTP. The Outage Plan contains the applicable 'operatmg procedures (OP) and nondestructive testing (NDT) procedures used for the examinations.
2.2 Scope of Examinations NDE was performed on a total of one-hundred and thirty'(130) selected Class ?1) and Class 2 components and examination areas as contained in the Outage Plan.' Selection of these components and examination areas was based on the LTP allocation and scheduling requirements for the first refueling outage. In addition, some selected welds and/or examination areas were either replaced with alternate selections or deferred to a later outage due to component support interference, inaccessibil_ity, or ALARA considerations.
These deviations changes were documented as Examination Plan Changes to the Outage Plan. -
These examinations constitute approximately fifteen (15) percent of the total number of' components and examination areas required to' be examined during the first inspection:
interval 2-1
j Class 1-A total of seventy nine (79) examinations were perforined on the following Class I componen's and examination areas:
.VUHhi Reactor Pressure Vessel
. Pressurizer Steam Generators (Primary Side)
Piping Reactor Coolant System -
Chemical and Volume Control System Residual Heat Removal System Pumps Reactor Coolant Pump 2A Class 2-A total of fifty-one (51) examinations were performed on the following Class 2 components and examination areas:
Vessels Regenerative Heat Exchanger Residual Heat Removal Heat Exchanger 2A Piping Auxiliary Feed. vater System -
Containment Spray System Feedwater System hiain Steam System Residual Heat-Removal 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.
2.3 Personnel, Procedures, and Equipment 2.3.1 Personnel Qualifications The examination personnel have been trained and qualified in accordance with Section XI.
22-
o 9
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 x
during 2RE01 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. SwRI personnel performed all examinations (UT, MT, PT, and VT) on the reactor pressure vessel (RPV) bolting and all other UT examinations in accordance with SwRI NDT procedures approved by HL&P. HL&P GC NDE personnel performed all MT, PT, and VT examinations (excluding those required for the RPV bolting) in accordance with HL&P QC NDT procedures.
The NDT procedures were written to conform to the requirements of the applicable sections of the ASME Code. Any deviations from ASME Code requirements are noted within the procedure. Some of the SwRI procedures were amended for specific examination purposes with interim change notices (ICN). A list of the applicable NDT procedures is provided in Appendix 2-C.
SwRI OP's were utilized to provide guidelines and controls for performance of on site activities. This included procedures for weld joint indentification marking, indication (q
recording, records control, data comparison, and resolution of indications. A list of the
/
applicable OP's 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:
Sonic FTS Mark I ultrasonic instruments Tektronix Oscilloscope Ultrasonic transducers AC electromagnetic yokes MT calibration block l
Pyrometers Black light meters Pressure gauges l
Paint thickness gauge A list of all major equipment used during the 2RE01 ISI is contained in Appendix 2-B.
O (j
2-3
i 2.3.4 Materials O
NDE materials utilized during 2RE01 weld examinations included penetrant and magnetic particle materials, ultrasonic couplant, and marking pencils. _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. A list of these material and traceability numbers is included in Appendix 2 B.
2.3.5 Calibration Blocks Pipe, vessel, and bolting 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 all calibration blocks are -
included in the LTP.
2.4 Summary of Examinations a
2.4.1 Examination Methods The following examination methods were conducted in accordance with HL&P approved SwRI NDT procedures and/or HL&P QC NDT procedures:
VT Examinations VT-1 examinations were performed on RPV closure washers, Steam Generator manway bolting (Primary Side), Reactor Coolant Pump Seal Housing bolting, Pressurizer manway bolting and integral attachments, and Class 1 flange bolting.
PT Examinations 1
PT examinations were performed on RPV closure studs, Pressurizer nozzle safe end welds, Class 1 and 2 piping welds, and Class 2 vessel nozzle and integral.
attachment welds.
MT Examinations MT examinations were performed on the RPV closure head, studs and nuts, Pressurizer support skirt weld, and Class 2 piping welds.
2-4
UT Examinations f}
V UT examinations were performed on Class 1 and 2 components, including RPV closure studs and nuts, vessels, 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 programs were implemented during this outage:
Augmented ISI - IE Bulletin 79-17 Augmented ISI - Break Exclusion Zone These augmented programs are described in the SwRI 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 73 V
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 4
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-2.5 Examination Results and Corrective Actions Examination area coverage was provided, to the extent practical, in accordance with the
)
25
t 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, a calculation was performed to estimate the amount of coverage achieved. _ Appendix 2 D, ISI Examination Limitations, contains a detailed account of all examination limitations (UT, PT, and'MT) encountered during 2RE01 weld examinations.
All UT indications determined to be recordable, regardless of signal amplitude, were investigated by SwRI to determine the nature of the reflector.
The UT examinations revealed Code allowable flaws in Reactor Vessel weld RPV2101-101 (torus to flange), Pressurizer welds PRZ 2 N3 (nozzle to shell), PRZ 2 SK (support i
skirt), and a Main Steam piping lug weld 30 MS-2001-29PL2,- These same flaws were detected during the PSI. Following evaluation, all reported flaws were accepted _"as is" by HL&P.
No reportable indications were detected by surface (PT and MT) examinations.
VT examination of CV piping line flange bolting and Pressurizer manway bolting revealed evidence of leakage (presence of baron crystals) and was reported on Request for Action (RFA) Nos. 90-1931 and 901932 respectively.
There are no acceptance standards in the 1983 Edition with Addenda Summer 1983.of O.
Section XI and Section III does not address evidence of lea continued service. However, corrective _ action was specified on the RFAs for the CV-piping flange bolting and Pressurizer manway bolting connections to be reworked in accordance with Work Requests (WR) Nos. CV-118379 and RC-107552 respectively.
These WR's were not completed during 2RE01-due to the low priority established for. this-task. No additional examinations _wcre required. :Since the visual. indications on the pressurizer manway and CV flange bolting are not considered flaws,.no successive -
examinations are required.
.2.6 Certification of Inspections ASME Section XI NIS 1_ forms, " Owner's Report for Inservice 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.- ANII,_
- Factory Mutual Systems, on the NIS-1 forms included in Appendix 2 E.
O 2-6
O APPENDIX 2-A
SUMMARY
OF EXAMINATIONS O
1 0
2-7
DATE: 02/23/91 SOLITH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 REVISION:
0 PACE:
1 INSERYlCE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST CUTAGE (1990)
CLASS i SCHEDULED COMPONENTS
0 ASME O-G T SEC. XI R E N
.SUMMART EXAMINATION AREA CATGT EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R
- CAtlBRAfl0N BLOCK **
CIRCUMFEttNTIAL Cl0SURE HEAD WELDS (FIC NO A RPV 3) 000600 RPV2 101+101 8A MT NDEP 7.1 R1 X
EXAMINED CLOCKWISE FROM L=0 TO L=182 AS CLOSURE HEAD TORUS TO FLANGE 31.40 UTOW STP UT150 R0,CO X VIEWED FROM THE T0J. SPOT INDICATION UTOL ICut X WITH NO MEASURABLE DIMENSIW S. LIMITED U145 X
UT FROM THE FLANGE $1DE DUE TO FLANGE UT45T X
CONFIGURAfl0N.
UT60 X
- CSCL 92" MMT X
000700 RPV2 103 101 BA UTOW STP UT150 R0,C0 X EXAMINED CLOCKWISE FROM Leo 10 Ls229 AS CLOSURE HEAD DOME TO CLOSURE B1.21UT45-ICN1 X
VIEWED FROM THE TOP. LIMITED UT DUE TO HEAD TORUS UT45T X
PROXIMITY OF LIFilNG LUCS AND INSULATION UT60 X
SUPPORT RING.
UT601 X
- CSCL 90" a
O MERIDIONAL CLOSURE HEAD WELDS (FIC NO A RPV-3) 002100 RPV2 101 104A BA UTOW STP UT150 RO,C0 X SPOT INDICATION !$ THE SAME AS THAT CLOSURE HEAD MERIDIONAL WELD B1.22UTOL ICN1 X RECORDED FOR WELD RPY2 101 101.
AT 0 DEC UT45 X
UT451 X-UT60 -
X
- CSCL 90/CSCL 91" UT60T X
002200 RF'.9 101 1048 BA UTOW STP UT150 R0,CO X
CLOSURE HEAD MERIDIONAL WELD B1.22UT45 ICN1 X
AT 90 DEG UT45T X
UT60 X
UT60T X
.X EXAMINED 12 NUTS (NOS.18, 48, 7B,106, B6.10 UTO STP UT19 R0.C0 X
136, 168, 198, 228, 258, 288, 318, AND UT43 X
340). LIMITED UT FROM THE 00 SURFACE DUE TO SPANNER WRENCH SLOTS.
- CS 46" v
2-8
. ~.
DATE: 02/23/91 SOUTH TEXAS PROJECT ELF.CTRIC GENERAi:NG STAfl0N UNIT 2 PAGE:
-2 REVill0N:
0 IN51Rvir". INSPECTION PLAN FIRST INTERVAL, f1RST PER!CD, FIR $f OUTAGE (1990)
REACTOR PRES $URE VERSEL N
0 ASME O G-T SEC. XI R E N
SUMMARY
EXAMINAfl0N AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION.
ITEM No METHOD PROCEDURE C M R **CALIBRAfl0N BLOCK **
CLOSURE HEAD BOLTlWC UIG NO A RPV 1. 31 005400 CLOSURE STUDS BG1 PT STP Pf6 R0,C0
.X EXAMlWED 12 STUDS (N08.1B, ; B, 78,105, 36.30 MT STP MT2 R0,C0 X
135, 165, 195, 228, 250, 288, 318, AND UT45
.STP UT22 R0,C0 X
343). LIMITED UT OF THE ROTO LOK LUCS UT60 ICN1,1CN2 X
DUE 70 STUD CONFIGURATION, UT88 STP UT17 R0,C0 X
- CS 45A/CS 455**
005600 CLOSURE HEAD M SHERS BG1 VT 1 STP VTT R0,C0 X
EXAMINED 12 WASHERS (WOS. 18, 48, 7B, 36.50 105, 133. 163, 198, 220, 250, 285, 318 AND 345).
M lNTERIOR UIC N0 A RPV i. 2) 006200 VESSEL INTERIOR B N 1-VT 3 STP VT7 R0,CD X
EXAMINED SPACE AB0VE AND BELOW THE B13.10 I
REACTOR CORE MADE ACCES$1BLE FOR EXAMINATION SY REMOVAL OF UPPER VISSEL INTERNALS. AMONG THE AREAS EXAMINED WERE THE FLANGE SEAL SURFACE / CORE BARREL LEDGE, UPPER PLATE CUIDES, AND THE CORE' BARREL.
O 29-
~...
~.....
I DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC OENERATING STATION UNIT l' PAGE:
3
{
REVISION:
-0 INSEPVICE INSPECTION PLAN-FIRST INTERVAli FIRST PERIOD, FIRST CUTAGE (1990)-
PRESSURl2ER (FIGURE A PR2 1)
W-0 A3ME 0 4 T SEC. XI R E - N --
SUMMARY
EKAMINAtl04 AREA CATGT-EXAM E0 E REMARKS NUMBER IDENTIFICAfl04 ITEM NO METNCO PROCEDURE C M R **CAlltRAfl0N BLOCK **
N022tt To SHELL AND SHELL TO NO22LE W LDS 010700 PR2 2*N5 BD UT0W STP UT49 R0,C0 X
CODE ALLOWASLE WELD INCLUSION. NO UT SAFETY N022LE B3.110-.UT45 STP UT15 R0,C0 X FROM THE N022LE SIDE DUE TO N022LE UT45T X
CONFIGURAfl0N.
I mg-X-.
UT60T X
- CSCL 56**
D10800 PR2 2 W44 80 UTOW STP UT49,R0,C0 X
NO UT FROM THE N022LE SIDE DUE TO N0ZZLE RELIEF NO22LE 33.110 UT45 STP UT15'RO C0 X*
CONFIGURATION.
UT45T X
WM X
UT607 X
- CSCL 56**
N022LE INSIDE RADIUS SECTION U
011300 PR2 2=N3 1R BD UT20 STP UT11 R0,C0 X
SAFETY N022LE S3.120
- CSCL 42**
D11400 PR2 2*N4A IR E.D
.UT20 STP*UT11 R0,C0 X
RELIEF N022LE 83.120
- CSCL 42**
j-NO22LE TO SAFE END AND SAFE END TO NO22LE W LDS l
D11900 PR2 2 N3 SE BF PT NDEP 6.2 R3
'X LIMITED UT45 FROM THE SAFE END SIDE DUE l
SAFETY N0ZZLE s5.40 UT45 STP UT52 R0,C0 X
TO SAFE END CONFIGURAfl0N.
UT457 x-UT45 STP UT31 R0,C0 X-l UT45T-X
- CSCL 69/SS 70**
l 012000 PR2 2 N4A SE.
BF PT NDEP 6.2 R3 X
.lMITED UT45 FROM THE SAFE END SIDE DUE
- ' =
RELIEF N022LE B5.40 UT45 STP UT52 R0,C0 X'*
TO SAFE END CONFIGURATION.
UT45T X
O UT45 STP UT31 R0,CO X
UT45T X
- CSCL 69/SS 70**
2-10 1
-/
DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC GENERATING STAil0N UNIT 2 PAGE 4
REVIS]QN 0
INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST DUTAGE (1990)
CLASS 1 SCHEDULED COMPONENTS
(
PRESSURIZER (FlGURE A.PR2 1)
N 0
ASME O G T SEC XI R E H
SUMMARY
EXAMINATION AREA CATGT EXAM E O E REMARKS NUMBER IDEWilflCATION ITEM NO METHOD PROCEDURE C M R **CAllBRATION BLOCK **
MANWAY SOLt1gpg 012300 90L11NG 502 VT.1 NCEP f.3 R1 X EXAMINED BOLT NOS. 1 THROUON 16.
57.20 EVIDENCE OF C00LANT LEAKAGE WAS DETECTED. RFA 901932 WAS ISSUED FOR TH18 CONDITION WklCH WAS EVALUATED AND ACCEPTED FOR CONTIN'JED SERVICE.
INTEGRAL ATTACMMENTS 012400 in 5.H VT.1 NDEP 9.3 R1 X
VT*1 PERFORMED As A SUPPLEMENTAL SUPPORT BRACKET 88.20 PT NDEP 6.2 R3 X
EXAMINAfl0N. LIMITED PT ON TOP OF BRACKET DUE TO PROXIMITY OF PERMANENT SUPPORT FRAME.
0~ 012410 it 8.H VT.1 NDEP 9.3 R1 X
VT*1 PERFORMED AS A RUPPLEMENTAL SUPPORT BRACKET 88.20 PT NDEP 6.2 R3 X
EXAMINATION. LIMITED PT ON TOP OF BRACKET DUE TO PR0XIMITY OF PERMANENT SUPPORT FRAME.
012420 2A 5.H VT*1 NDEP 9.3 R1 X
VT.) PE**0RMED AS A SUPPLEMENTAL SUPPORT BRACKET 88.20 PT NOEP 6.2 R3 X
EXAMINATION. LIMii;C t*J ON TOP OF BRACKET DUE To PR0XIM11Y OF PERMANENT SUPPORT FRAME.
012430 2a B.H VT.1 NDEP 9.3 R1 X
VT.1 PERFORMED AS A SUPPLEVENTAL SUPPORT 8 RACKET 88.20 PT WDEP 6.2 R3 X *.
EXAMINATION. LIMITED PT ON TOP 0F BRACKET DUE TO PROXIMITY OF PERMANENT SUPPORT FRAME.-
012600 PR2 2.SK 9.H MT NDEP 7.1 R1 X
CODE ALLOWABLE LOW AMPLITUDE REFLECTORS.
SUPPORT SKJRT 88.20 UT35 STP.UT21 RO,CO X X PERFORMED UT FROM OUTSIDE SURFACE IN UT60 X
LIEU OF MT ON INSIDE SURFACE (REF. HL&P UT60T X
RELIEF REQUEST RR.ENG.09).
- CS 55/CSCL 36**
&L 11
~
.-. _ = -
DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
5 REVISION:
0 INSERVICE INSPECTIM PLAN
-FitST thfERVAL, FIRST PERIOD, FIRST CUTAGE (1990)
CLASS 1 SCHEDULED COMPONENTS g'
STEAM GENERATOR 2A (PRIMARY SIDE) UlGURE A SG 1)
N O
ASME O G T SEC. XI R E N
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICAfl0N ITEM N0 METHOD PROCEDURE C N R **CALIBRAfl0N BLOCL' MANWAY BOLTING 015800 SG'2AalMS 5G2 VTal NCEP 9.3 R1 X
BASELIWE EKAMINAfl0N ON REPLACEMENT INLET PANWAY BOLTING B7.30 WASHERS 001 THRJ 128, NUTS 001 THRU 126, AND STUDS 001 THRU 128 PKl0A TO INSTALLATION.
015900 SG 2A 0Ms e02 VTai NCEP 9.3 R1 F
BASELINE EXAMINATION ON RCPLACEMENT-CUTLET MANWAY BOLTING 87.30 WASHERS 001 THRU 128i NUTS 001 TWRU 128, AND STUDS 001 THRU 128 PRIOR TO
+
INSTALLAflDN.
(
1 i
O y
2 12
.w
-, w
+-
,,,-s
,ew.,
y y
DATE: 02/23/91 SOUTN TEXAS PROJECT ELECTRIC GENERATING STAfl0N UNIT 2 PAGE:
6 REVISION:.
O INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST DUTAGE (1990) b CLASS 1 SCHEDULED COMP 0NENTS 1, TEAM CENERATOR 28 (PRIMARY SIDE) (FIGURE A SG 21 N
O ASME O G T
' SEC. XI R E N
SUMMARY
EXAMINATION AREA CATGY EXAM E 0 E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R **CAllBRATION BLOCK **
MANWAY BOLTING 0 % 800 SG 28 !MB B02 VT*1 NDEP 9.3 R1 X
BASELINE EXAMINAfl0N ON REPLACEMENT INLET MANWAY 80LTING-87.M WASNERS 001 THRU 128, NUTS 001 THRU 128,'
AND SitDS 001 THRU 128 PRIOR TO INSTALLATION.
016900 SG 29 0MB B*G 2 VT 1 WDEP 9.3 R1 X
BASEllWE EXAMINAfl0N ON REPLACEMENT DUTLET MANWAY BOLTING
- 57.30 WASHERS 001 THRU 128, NUTS 001 THRU 128, AND STUDS 001 THRU 128 PRIOR TO INSTALLATION.
bU l
p%.)
i l
2-13
e
- DATE: 02/23/91 SOUTH TEKAS PROJECT ELECTRIC GENERATING STATION UNIT 2 REVISION:
0 PAGE:
7 INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, F'78T CUTAGE (1990)
CLASS 1 SCHEDULED COMPONENTS ETEAM CfWEPATOR PC (PRIMARY $1DE) (FIGURE A*SG*i)
N
-0 ASME-0 0T SEC. XI R E-H SumARY EXAMINAfl0N AREA CATGY EKM E O E REMARKS NUMBER IDENTIFICAfl0N ITEM NO METHOD PROCEDURE C M R **CAlldRAfl0N BLOCK'*
j NANWAY BOLTING l
017800 SG 2C+1MB B a'l* 2 VT 1 NOEP 9.3 R1 X
SASELINE'EXAMINATl0W ON R' PLACEMENT INLET MAanAY SOLTING 87.30 WASHERS 001 THRU 128, NUTS 001 THRU 128, AND STUDS 001 THRU 128 PRIOR TO INSTALLATION.-
017900 SG 2C 0MB S*G 2 Vl*1 NDEP 9.3 R1 K
QUTLET MANWAY BOLTING -
87.30 SASELINE EXAMINATION ON REPLACEMENT WASHERS 001 THRU 128,' NUTS 001_THRU 122, AND STUDS 001 INRU 128 PRIOR 70 INSTALLATION.
v
(
2 14
l DATE: 02/23/91 SOUTM TEXAS PM0 JECT ELECTRIC GENERATING STAfl0N UNIT 2 REVISION:
0 PAGE:
8 INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERICO, FIRST OUTAGE (1990)
(
CLASS 1 SCHEDULED COMPONENTS
}JEAM GENERATOR 2D (PRIMARY SIDE) (F10URE A tG 21 N
O ASME O G 1 SEC. XI R E N
SUMMARY
EXAMINAfl0N AREA CATGT EKAM E O E REMARKS NUM8ER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R "CAllBRAfl0N BLOCK'*
MANWAY BOLTING 018800 SG 2D LMB D*G 2 VT 1 NDEP 9.3 R1 X
INLET MANWAY BOLTING 87.30 BASELINE EXAMINATION ON REPLACEMENT a
WASHERS 001 THRU 128, NUTS 001 THRU 128, AND STUDS 001 THRU 108 PRIOR TO INSTALLATION.
018900 SG 2D DMB B+G 2 Viet NDEP 9.3 R1 X
CUTLET MANWAY 80LTING 87.30 BASELINE EXAMINAfl0N ON REPLACEMENT WASHERS 001 THRU 128, NUTS 001 THRU 128, AND STUD 001 THRU 128 PRIOR TO INSTALLATION.
2-15
DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
9 REVISION:
0 INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST GUTAGE (1990).
CLASS 1 SCHEDULED COMPONENTS REACTOR COOLANT SYSTEM N
O ASME O C-T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EKAN E D E REMARKS.
NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R
- CALIBRAfl0N BLOCK **
6 RC 2004 NSS (FIC NO A RC 6) 103800 1 B.J PT NDEP 6.2 R3 X
SAFE END TO EL90W 89.11 UT45 STP UT52 R0,C0 X
UT45T X
- S$*9**
6 RC 2015 NS$ (FIC NO A*RC T) 104420 1 8J PT NDEP 6.2 R3 X
=.
SATI END TO BENT PIPE 99.11 UT45 STP UT52 R0,CO X
UT45T X
- gg.9e*
0104500 9
tJ PT NDEP 6,2 R3 k
PIPE TO ELt0W 89.11 UT45 STP UT52 R0,C0 X..
UT457 X
e+gs.9ee 104550 14 s.J PT NDEP 6.2 R3 X
X
' ADDITIDHAL COVERAGE.-
UT45T X
UT60
$TP UT31 R0,00 X-.
- SS 9**
2 RC 2220 881 (FIG WO A RC 17) 109000 1 8J PT NDEP 6.2 R3 X
MANDATORY 18! *.MS UF.
BRANCH CONNECTION TO PIPE 89.40 2 RC 2419 881 (FIC NO A RC 19) 110300'1 0J PT
_ NDE? 6.2 R3 X
-. - MANDATORY ISI
- MS UF, TEE TO PIPE B9.21-
/
. (w-l 2-16
.~..
DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC QENERATING STATION UNif 2 PAGEt 10 REVISION:
0 INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FitrJT CUTAGE (1990) -
CLASS 1 SCHEDULED COMP 0NENTS
(
CHEMitAL AND VOLUME CONTROL SfSTEM N
O 7
ASME O G T SEC. XI R E N-SUMM%RY EXAMINAfl0N AREA CATGY EXAM E-0 E REMARKS WUMA IDENTIFICAfl0N ITEM NO METHOD PROCEDURE C M R **CAllBRATION BLOCK **
2_*CV 2122 tB1 (F10 No A CV 4) 151640 3 s.J PT NDEP 6.2 R3 X
VALVE TO PIPE 89.21 151740 8 8J PT NDEP 6.2 R3 X
PIPE TO REDUCER 99.21 2 CV 2128 881 (FIC WO A CV 6) 153640 3 BJ PT NDEP 6.2 R3 X
VALVE TO PIPE 39.21 9
\\
2fl.5) CV 2122 881 (FIC N0 A-CV 4) 154900 4 5J PT NDEP 6.2 R3 X
MANDATORY 181 TE.
BENT PIPE TO FLANGE 89.21 154905 4F8 BG2 VT 1 -
NDEP 9.3 R1 X.
EVIDENCE OF COOLANT LEAKAGE WAS FLANGE BOLTING B7.50 DETECTED. RFA 901931 WAS ISSUED FOR
'THIS CON 0! TION WHICH WAS EVALUATED AND ACCEPTED FOR CONTINUED SERVICE.
s 2fl.5) CV 2128 BB1 (FIC WO A.CV 6) 156440 2 BJ PT NDEP 6.2 R3 X
MANDATORY lst. TE.
SENT PIPE TO FLANGE 39.21
-156445 2FB B*G 2 VT 1 NOEP 9.3 R1 X
FLANGE BOLTING 87.50 0\\
2 17
DATE: 02/23/91 SOUTH TEXAl PROJECT ELECTRIC GENERATING 51Atl0N UNIT 2 PAGE:
11 REVltl0N:
0 INSERVICE INSPECTION PLAN-FIRST INTERVAL, FIRST PERIOD, FIR $T DUTAGE (1990)
O
- CLASS _1 $CHEDULED COMPONENTS V RESIDUAL HEAT RENOVAL SYSTEN N
O ASME O G_T SEC. XI R E N SUMMART EXAMINAtl0N AREA CATGY EXAM E O E REMARKS NUNSER IDENTIFICAfl0N
-ITEM NO -METHOD PROCEDURE CN-R
- CAllBRATION BLOCK ** -
12 EH 2301 tB1 (F10 NO A.RH 3) 201040 2 8+J PT NDEP 6.2 R3 X
PIPE TO ELBOW 09.11 UT45 STP+UT52 R0,C0 X
UT45T-X e.gg.21**
201160 8 tJ PT WDEP 6.2 R3 X
ELBOW 10 PIPE 89.11 UT45 STP 52 RO,CO X
+
UT45T X
e.gg.21ee 201200 10 9J PT NDEP 6.2 R3 X
ELBOW 10 PIPE 99.11
-UT45 STP UT52 R0,C0 X
UT45T X
- SS 21**
10 RH 2308 BB1 (FID NO A RM 51 202180 3 tJ PT NDEP 6.2 R3 X
- UT45 REFRACTED SHEAR USED FOR 5
REDUC 1NG TEE TD PIPE 99.11 UT45 STP UT52 R0,CD X.
AD0lil0NAL COVERAGE. $$ 57 USED FOR -
UT45T X
REFRACTED SHEAR CAllBRAfl0N.- NO UT45T U145*
STF-UT31 RD,C0 X
ON THE REDUCING TEE SIDE DUE TO REDUCING TIE CONFIGURATION.
- SS 58/ss 57'*
202240 7 9J PT NDEP 6.2 R3 X
PIPE 10 EL90W 89.11 UT45 STP UT52 R0,C0 X
UT45T X
- 58 58**
8 RH 2308 BB1 (FIC NO A RH 5) 203360 1 3J PT.
NDEP 6.2 R3 X
MANDATORY ISI. HS UF.
VALVE 10 PIPE 89.11 UT45 STP UT52 R0,C0 X
- UT60 REFRACTED $ HEAR USED FOR UT45T X
ADDITIONAL COVERAGE. LlHITED UT FR m UT60*
THE VALVE 310E DUE TO VALVE
[
CONFIGURATION.
eagg.11..
- , -18 1
l
\\
DATE 02/23/91 SOUTH TEXAt PROJECT ELECTRIC GENERATING STATION UNIT 2 RLVill0N:
0 PAGEt 12
- lWSERVICE INSPECTION PLAN fitsi INTERVAL, FIRST PERIOD, FIRST OUTAGE (1990)
CLAS$ 1 SCHEDULED COMPONENTS d
- E ACTOR COOLANT MMP 2A N
0 A38E O G T SEC. XI R E-N
SUMMARY
EKAMINATION AREA CATGY EKM E D E REMARKS 7
NUMBER IDENTIFICAfl0N ITEM NO METHOD PROCEDURE CM R **CAlltRATION BLOCK **
PUMP BOLTING (Flc NO A RCP 1) 260130 RCP 2A*SR8 t02 VT*1 WDEP 9.3 R1 X
EXAMlhED DOLT WOS.1 THROUGH 5.
~
SEAL NOUSING BOLTS 57.60 f tYWHEtt (fic Wo A Rep 3) 260170 RCP 2A*fW RG UTO STP UT7 R0,CO X
EXAMINED BORE, KETWAYS, AND BOLT H0LES '
FLYWNEEL 1.14 IN PLACE.
I
- Cs 76**-
)
O 2-19 1
.... ~
DATEt 02/23/91 SOUTH TEXAS PROJECT ELECTRIC GINERATING STATION UNIT 2~
PAGE:
13 REVISION:
0
. INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST. PERIOD, FIRST GUTAGE (1990)
' CLASS 1 SCHEDULED COMPONENTS REACTOR COOLANT PUMP 28 -
N 0
ASME 0 G T SEC. XI R E N SUpmARY EXAMINATION AREA CATGY LXAN E 0 E REMARKS NUMBER IDENTIFICAfl0N lien NO METHOD PROCEDURE ~
C M R.
- CALIBRATION BLOCK'*
FLYWHEEL UIC NO A kCP 21 260270 RCP 28 FW RG UTO STP UT7 k0,C0 X
EXANINED SORE, KEYWAYS, AND SOLT HOLES FLYWHEEL 1.14
.IN PLACE.
- CS 76**
i O
1 n Lv 2 20
-. _... - ~,.
_~. -.
~ _.. _...
DATE: 02/Z3/91 SOUTN TEXAS PROJECT ELECTRIC GENERATING STAfl0N UNIT 2 PAGEt-14 -
REVIS10N:
0 INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST OUTAGE ($990) i CLASS 1 SCHEDULED COMPONENTS REACTOR COOLANT PUMP 2C N
O ASME
'O G T SEC. XI R E N S'JMMARY EXAMlWATION AREA CATGY EXAM E.0 E REMARKS NUMBER IDENTIFICAfl0N ITEM WO METHOD PROCEDURE C M R
- CAllBRATION BLOCK **
FLYWEYL (Ff C WO A RCP 3) 260370 RCP 2C.FW RG UTO STP UT7 RO,CO X
EXAMINED BORE, KEYWAYS, AND BOLT N0LES
=
- FLYWHEEL 1.14 IN PLACE.
eacg.7g,ue
.. g 2 21
DATE: 02/23/91 SOUTH TEUS PROJECT ELECTRIC GENERATING STAfl0N UNIT 2 PAGE 15 REVIS10N:
0 INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST CUTAGE (1990)
CLAS$ 1 SCHEDULED COMPONENTS
\\
REACTOR COOLANT PUMP 2D N
O ASME O C T SEC. XI R E N
$UMMARY EXAMlWAfl0N AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM No METHOD PROCEDURE C M R ** CALIBRATION BLOCK"
.......a......................................................
..........................e.............
FLYWHEEL (FIG NO A RCP 2) 260470 RCP 2D FW RG UTO STP UT7 R0,C0 X
EXAMINED BORE, KEYWAYS, AND BOLT HOLES FLYWHEEL 1.14 IN PLACE.
- C$*76**
l 2 22
DATE ' D2/'t3/91 SOUTH TEXAS PROJECT ELECTRIC GENERATING STAfl0N UN!T 2 PAGE:
16 REvill0N:
D INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST GUTAGE (1990)
O CLASS 2 SCHEDULED COMP 0NENTS k
RECENERATIVE HEAT EXCHANGER (FIGURE t RCX 1)
N O
ASME O G T SEC. XI R EN
SUMMARY
EXAMINAT!DN AREA CATGY EXAM E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R- **CALIBRAfl0N BLOCK **
CIRCUM KRENTfAL WELDS 304400 CSAHRG 2A 51 CB PT NDEP 6.2 R3 X
- UT60 USED FOR ADDIfl0NAL C0VERACE.
N0ZZ1E TO TUBE SHEET C2.21 UT45 STP UT45 R0,C0 X
LIMITED UT FROM THE N022LE $1DE DUE To i
UT45T ICN1,1CN2 X
PROXIMITY OF BRANCH CONNECTION.- N0 UT
=
- UT60*
X FROM THE TUSE SHEET SIDE DUE TO TUBE SHEET CONFIGURATION, e.gg.64**
304450 CSANRG 2A 52 CA UT45 STP UT45 R0,C0 X
- UT60 USED F09 ADDITIONAL COVERAGE.
TURE SHEET TO GHELL C1.30 UT45T ICN1,1CW2 -
X LIMITED UT FROM THE SHELL SIDE DUE TO UT60*
X PROXIMITY OF BRANCH CONNECTION. NO UT FROM THE TUBESHEET SIDE DUE TO TU8E SHEET CONFIGURATION.
eess.63**
C 304700 CSAHRG 2A*S7 CA UT45 STP UT45 R0,C0 X
- UT60 USED FOR ADDITIONAL COVERAGE.
SHELL TO TURE SHEET C1.30 UT45T ICN1,1CN2 -
X LIMITED UT FROM THE SHELL SIDE DUE TO
~
UT60*
X PROXIMITY OF BRANCH CONNECTION. NO UT
.FROM THE TUBESHEET SIDE DUE TO TUBE SHEET CONFIGURATION.
eegg.63**
304750 CSAHR6 2A h8 C8 PT NDEP 6.2 R3 X
- UT60 USED FOR ADDITIONAL COVERAGE.
TUBE SHEE1 TO N0Z2LE C2.21 UT45 STP UT45 R0,C0 X
LIMITED UT FROM THE N0ZZlE $1DE DUE To UT45T ICN1,1CN2 X
PR0XIMITY OF BRANCH CONNEC1'ON. NO UT
+*
l UT60*
X FROM THE TUBE SHEET SIDE DUE 11 TUBE a
SHEET CONFIGURATION.
e gg.64**
INTEGRAL ATTACHMENTS 304850' CSAHRG 2A A1 CC PT NDEP 6.2 R3 X
SUPPORT ATTACHMENT WELD C3.10
\\D 2 23
.~... ~. - -,...-.....~
DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC GENERATING STAfl0N UWlf 2 PAGEt 17 REVISION:
0 INSERVICE INSPECil0N PLAN FIRST INTERVAL, FIRST PER100, FIRST GUTAGE (1990)
N CLASS 2 SCHEDULED COMPONENTS RECENERATIVE HEAT EXCHANGER (FlGURE B RCX*i)
N' O
I A38E O G T SEC. XI R E N-
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS.
NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R ** Call 8AAfl0N BLOCK **-
INTEGRAL ATTACHMENTS 304900 CSAHRG 2A A2 C-C -
PT NDEP 6.2 R3 X
SUPPORT ATTACHMENT WELD C3.10
-l 304950 CSAHRG 2A A3 CC PT NDEP 6.2 6'3 X
SUPPORT ATTACHMENT WELD C3.10 305000 CSAHRG 2A A4 CC PT NDEP 6.2 R3 X
SUPPORT ATTACHMENT WELD C3.10 1 O.
t 2 24
Daft: 02/23/9)
SOUTH f tKAS PROJECT ELECitit OtWERAflWG STATION UNIT 2 PAGE:
18 l
REYttl0Ns D
IWSERVICE IW8PECfl0N PLAN FIR $1 INTERVAL, f!R8f PERIOD, FIRST GUTA0t (1M0)
CLAS$ 2 $CNEDULED COMPOWENT8 Rfl! DUAL MAT kE40 VAL HE AT EXCHANGER 2A N
0 ADME O 4
't BtC. XI R I N
SUMMARY
EMAMlhAfl0N Atta CAftY EXRM I- 0 E R& MARK 8 WUMett IDtWilflCAfl0N litM WO MtfH00 PROCEDURE CM R **CAllBRAfl0N BLOCK" ElEUMitRINTI AL WLbt 010 Wo B RMX=il 305400 RNAHR$.2A*81 C+A UT46 STP Uf4$ RU,C0
. x.
NEAD 70 8 HELL C1.20 UT45T ICN1 x.
U160 X
+
- gg.6Pd i
Y 4
1
(.J L
l 2 25
.. ~. _,,. _,.. _.,,. _ ~.,.. ~, _.,..
CAtt) 02/23/?1
$0U1H I!KAS PROJECT ELECTRIC CtWERAflWG tfAfl0N UNif 2 PAGE:
19 REVill0N:
0 IWstRVICE IWSPECTION PLAN FIR $f INTFRVAL, FIR $f PERIOD, FIR $f OUTACE (1990)
CLAtt 2 $CutDULtD COMP 0NtWit
$Ux!LI Aty FttDW4ttR HELej N
0 Asef 0 0 f StC. XI P C H
$UMMARY EKAMlWAfl0W ARIA CATCY LKAM t 0t REMARKS NLMSER IDtWilFICAfl0W litM NO MtfMOD PROCFDURI C M R **CAllBRAll0W BLOCK **
B AF ?006 CAf tt1 (UC_ WO R AF*i1 350000 i C.F.2 NT NDEP 7.1 R1 X
ktDUCER 10 PIPt C5.51 Uf45 stP U141 R0,C0 X
- CS 2"
'450350 20PL1 20PL8 CC MT WDEP 7.1 R1 X
PIPt LUCS C3.20 350430 24PL124PL4 CC NT WDEP F.1 R1 X
PIPt LUCS C3.20 B AF 2006 CA2tC1 (FIC WO B AF.21 351020 2 CF2 MT WDEP 7.1 R1 X
PIPE 10 REDUCER C5.51 UT45
$1P Ut41 R0,CO X
REDUCER 10 PIPE C5.51 U145 STP Uf41 R0,CO X
ICW1 e cs.gn 6 AF ?DOB CA2 (FIC NO B AF 3. 41 359000 1 CF2 MT WDEP 7.1 R1 X
REDUCtt 10 PlPE C5.51 U145 stP UT41 R0,C0 X
ICW1
.*CS 1**
2 26 w ?W Sh
~ - - -.. - _.
-~
~. -
- -_ - ~ -.. -_
l l
l Daft 02/23/91 SOUTN TEKA5 PROJ!CT titCTRIC OfNERAtlNG $fAfl0N UWlf 2 PACI 20 REV1810ml 0
lk$tRVICE INSPICfl0N PLAN FIR $f IWitRVAL, Piksi PERICO, FIRST GUTAGE (1990)
CLAll 2 $CHEDULED COMPO R tg CONTAINMENT tPRAY SYtTEM i
i N
0 A94E O O f SEC. XI R t M
$UMMART EKAMINAfl0N AttA CATOY EKAN t 0 t REMARK 8 NUmstR IDENflFICAfl0N ITEN NO NtfM00 PROCEDURE CN R **CAlltRA110N WLOCK**
i l
12 tt*2101 UB2 (FID N0 d 08 11 l
400040 2LU C.F.1 PT WDtP 6.2 R3 X
EXAMINED 2.57 At THE INftR$tCilWG CIRC.
LONGifuDINAL WELD C5.12 Uf45 ITP UT35 R0,C0 X..
WLD.
UT451 X
eegg.tgee 400060 2 C.F.1 PT NDEP 6.2 R3 X..
P!Pt 10 Ett0W C5.11 UT45
$1P U135 R0,CO X
U1457 X..
eegg.12**
400000 2LD C+F.i Pt NDEP 6.2 R3 X..
EXAMINED 2.51 AT THE IWitR$tCflWG CIRC.
LONGITLOINAL WELD C5.12 UT45 tiP UT35 R0,C0 X..
WLD.
Uf45T X
\\
- 58 12**
l 8 et 2102 PB2 (FIC NO batt li 412220 4tU C*F.1 PT WDEP 6.2 R3 X
EXAMINED 2.51 Af THE INTER $tcilWG CIRC..
LONGITLOINAL WELD UT45
$fP*UT35 R0,C0 X
WELD. AUGMENTED !$1*lt8 79*17.
U145T X
- st.87+*
412240 4 C.F.1 PT NDEP 4.2 R3 X
AUGMENitD IS!.itB 79 17.
+.
ELtoW to PIPE U145 stP UT35 R0,CO X
UT45T X
- $$ 87**
412250 4LD C F.1 PT NDIP 6.2 R3 X
EKAMINED 2.57 AT THE INTERSECilWG CIRC.
LONGITUDINAL WELD UT45 STP UT35 R0 C0 X
WELD. AucMtufED is!.lta 7917.
U1451 X
- S$*87'*
6 tt 2103 Pt2 (Flo No B ts il 922000 ILU 1-C F*1 PT.
NDEP 6.2 R3 X-.
EXAMINED 2.57 AT THE INftR$tCilWG CIRC.
LONGifLOlW 4 WELD U145 STP UT35 R0,C0 X
WILD. AUOMENTED 181.ItB 79 17.
=.
U1451 X..
e gg.34 e 2 27
-. ~. -. - -.. ~. ~.. ~. - _. ~.. - -.. - -...
- - -. _ -.. ~.. _.. --.
4 j
Daft 02/23/91 South TEXA8 PROJECT ELECTRIC etWERAflWO STAfl0W UWlf 2 PAQtt 21 Rtyl8 ION:
0 IN8tRVICE INSPicflou PLAN.
FIRST INitRVAL, FIRST estl00, FIRST WTAGE (1990)
CLASS 2 $CNEDULtD COMPONENTS l
CONTAINMENT SPAAf tysitM N.
O q
Abut 0 af Dic. Mi R R N SLMMART EXAMINAf!0N AttA CATSY EXAM E O E REMARKS
- IRMttR IDENilFICAtl0N litM NO MtfMOD PROCEDURE CMR **CAllDRAfl0N BLOCK **
j 4
n 2
6 tt*2103 Pat (FIC ho battail 4
f' 422010 iLU 2 C+ Fat PT NDEP 6.2 R3
-X
. - +
EKAMINED 2.Si Af tnt INittsteilNo CIRC.
I LONCifG INAL WELD UT45 STP Uf35 R0,C0 M
+-
WLO. AUOMENitD 181 188 79 17.
j Uf4ST X
+.
j e
- ** u m **
1 422020 1 CF1 PT NDEP 6.2 R3 M + +
AUGMENIED 181+1Et P9*17.
REDUCING fit 70 PIPE Uf45 StP Uf35 R0,00 X
Uf457 X
+ +
a
- 83 34**
l k
i 4
e i
b i
i 4
.l R
1 I
4 4
4 4 :
2 28
?
e,,, - ~,
--n.,
s ---..-
-r,-n.w..-mu e-~w.-
e,,..
.,,.<w,...n.-
,w,-
--n..,
vy, a
g e, er -
cy -
,-n-
I Daft 02/23/91 SOUTH ffEAS PROJECT ELECTRIC DENERAflWG STAfl0N UNIT 2 PAGtt 22 ktVill0N:
0 IN$tRVICE INSPECTION PLAN FIR $7 IWitkVAL, FIR 8f PERIOD, FlR$f th/fA0t (1990)
CLAll 2 SCHEDULED COMP 0NENI$
\\
fi[QgAftR SYIftM N
0 AtMt 0C 1 i
fic. XI R E N l
l SLMMART EKAMINA110N AntA
'iY EXAM E 0 E REMARK 8 NUMetR IDtWilFICAfl0N IFEM NO MtfMOD PROCfDURE CM R **CAlllRAf!ON BLOCK **
........................+..............
_j iB FW 2012 CAF (FIC k0 b FW 1.,11 500000 1 C.F.2 MT NDEP 7.1 R1 X
AUQMENitD 181. B42.
VALVE to P2Pt C5.51 UT45 STP Uf41 R0.C0 X
"CS.3" 300020 i C72 MT NDED 7.1 R1 X
AUGMENit$ !$1+ BE2.
PIPE TO VALVE C5.51 UT45 STP UTA1 R0.C0 X
J
- CS 3" 500040 3 C.F 2 MT NDEP 7.1 R1 X
AUQMENitD 181. SE2.
VALVE TO PIPE C5.51 UT45 STP UT41 R0,C0 X
eeCS 3**
500060 A C.F 2 MT NDEP 7.1 R1 X
AUOMENTED l$1. DEZ.
P!Pt TO PIPE C5.51 Uf45 STP UT41 R0.C0 X
?
AUcMENffD 151. stZ.
ELBOW TO PIPE C5.51 Uf45 STP Uf41 R0,C0 X..
eeeg.4n 503670 1PL1 1PL8 C.C MT WDEP 7.1 Ri X
AUGMENit0 !$1. Bt2. LIMittD EXAMINAf10N PIPE LUGS C3.20 UT45 sfP UT38 RO,C0 X
DUE TO THE PIPE LUG CONFIGURAfl0N.
UT457 ICN1 X
- CS 33**
503680 2 CF2 MT WDEP 7.1 R1 X
AUGMtWitD ISI 8(2.
P2Pt 70 PIPE C5.51 U145 STP UT41 RO,C0 X
eecs.4..
2 29
DAfts C/23/91 SOVfN f tKAS PROJECT ELECTRIC GENERAflNG BTA110N UNIT 2 pAGli 23 REV1810Na 0
IN$tRVICE INSPECitCN PLAN FIR $f INitRVAL, flR$f PERIOD, FIR $f DufAct (1990) fitDWAftk tYSTEN s
N 0
Atst 0 G.T MC. I:)
R I N i
SUMMART EKAMINATION AktA CATCf EKAN E O E RtMARKt MUMeth IDENilFICAfl0N litM NO MtfMOD PROCEDURE-C N R **CALIBRAfl0N BLOCK'*
18 FW 2029 AA2 (FIC 90 3 FW 1) 503700 3 CF2 ptf NDEP 7.1 R1 x..
AUCMENTED 181. str.
71Pt 70 PlPE C5.51 Uf45 sfP U141 R0,C0 x..
"CS 4**
503T20 4 C*t*2 MT NDEP 7.1 R1 x..
I PIPE 10 VALVE C$.31 uf45 ggp.Uf41 R0,C0 x.
- CS 4**
f O.
i i
O 2 30
DAf t s 02/23/91 SOUTN ftKAS P.t0JtCT ELECTRIC 4thttATING STAfl0N UNIT 2 FACET 24 REVill0N:
0 INsttvlCE INSPictl0N PLAN FIRST INitRVAL, FIRST PERIOD, Fik$f CUTAGE (1990)
CLAtt 2 SCHIDutt0 COMP 0NIN!S MAIN STEAM SYSTEM 4
N 0
AllME O C T SEC. XI R E N
SUMMARY
EKAMINA110N AttA CAfGT EKAM t 0 t REMAttl WUM8tt IDENTIFICAfl0N ITEM NO MtfMOD PROCfDURE C M R **CAllRRAfl0N BLOCK'*
30 MS P001*GA2 (FfG N0 0 MS 1, 21 551480 21LUI CF2 MT WDEP 7.1 R1 X.*
EXAMINED 2.57 AT THE INTER $tcflNG CIRC.
10NGif21NAL WLD C5.52 UT45 stP UT41 R0,CO X
MLO.
ICN1
- Ct 5**
551500 21LUD CF2 Mf NDEP 7.1 R1 X
EXAMINic 2.57 AT THE INitkttCilNG CIRC.
LONGITWINAL WLD C5.52 U145 STP UT41 R0 C0 X
WLO.
ICN1 eeCS 5" 551520 21 CF2 MT WDEP 7.1 R1 X
ELBOW TO P2Pt C5.51 U145 stP Uf41 R0,C0 X
O
'~
551540 21LD CF2 ' MT hDEP 7.1 R1 X
EXAMINED 2.57 AT 7NE INitR$tcilNG CIRC.
LONGITWINAL WLD C5.52 U145
$1P UT41 RO,CD X
W LO.
+
- ICN1
..Ct 5**
551620 23LU CF2 MT WDEP 7.1 R1 X
EXAMINED 2.5T AT THE INTER $tCTING CIRC.
LONGITWINAL WLD C5.52 UT45 81P UT41 R0,C0 X
M LD.
ICtf1
- Cl 5" 551640 23 C F*2 MT WDEP 7.1 R1 X
AUGMENTED 181* DEZ.
P2Pt TO PENETRATION C5.51 UT45 STP UT41 R0,C0 X
ICN1
- CS 5**
551700 24 C F*2 MT-NDEP 7.1 R1 X
AUGMENito Isla St!.
+ +
PIPE TO PIPE C5.51 UT45 tiP Ut41 R0,C0 X
- CS C" V
2 31
DAtti 02/23/91
$0VIH ltXA8 PROJECT ELECTRIC GtutRATING $1Afl0N UNif 2 PAGE:
25 Rtvil10N:
0 INltRyltt INSPECTION PLAN FIR $f IWitRVAL, FIRST PERIOD, FIR $f OUTA06 (1990)
CLAS$ 2 SCHEDUltD COMPONENT 8
' v NAIN titAM CTtitM N
0 ADME O eT SEC. XI R t M
$UMMARY (EAMINAfl0N AREA CAfGY i.KM t 0 t REhARKt NUMBER IDtWilFICAfl0N litM NO METHOD PROCEDURE CM R **CAlllRATION BLOCK" 30 MS*2001*GA2 (FIG N0 0 Mtai. 2) 551720 24LO C F*2 MT NDEP 7.1 R1 X
EKAMINED 100E OF WLD LtNGTH. AUGMENitD
- - +
LONCITUDINAL WLD C5.52 U145
$1P U141 R0,C0 X
Islast2.
+
- e.cg.33n 551740 25LU C F.2 MT NDEP 7.1 R1 M
EXAMINED 100% OF WELD LENGIN. AUGMENit0
- +
LONGI 1UDINAL WELD C5.52 UT45 stP UT41 RO C0 x.
IsletEZ.
- CS*33**
551760 25 C+F 2 MT NDEP 7.1 R1 X
AV0 MEN 1tD 181* St!.
PIPE to PIPE C'.51 UT45 stP U141 R0,C0 K
- Cl
- 33" 551760 25LD C F*2 MT NDEP 7.1 R1 X
EXAMINED 100% OF WELD LENGTH. AUGMENit0 LONGITUDINAL WELD C5.52 UT45 STP UT41 R0,C0 x-Isl.stz.
ICN1
- CS*35**
$51782 26LU C+F+2 MT NDEP 7.1 R1 x*
EXAMINED 00% OF WELD LENGTM. AUGMENil" LONGITUDINAL WELD C5.52 UT45 stP UT41 R0,C0 x..
Is! DEZ, LIMittD EXAMINAttou DUt to PIPE $UPPORT. THl3 AttA WILL Bt EXAMINED DURING THE NEXT REFUtllWG OUTAGE WHEN THE PIPE SUPPORT WILL BE REMOVED.
- *Cl a 35" 551784 26 C.F.2 MT NDEP 7.1 R1 X
AUGMEWitD llla BEZ. LIMittD IKAMINAft0N PIPE TO P!PE C5.51 UT45 stP UT41 R0,C0 x.*
DUE To PRoxlMITT OF PERMANENT PIPE SUPPORT.
- CS*35**
[
t\\
2 32 l
DAtts C/23/91 5001N TEKAS PROJECT ELiCitlC OtNtRAflWG STAfl0N UNIT 2 PAGtt 26 ktVISI0ti D
IN$tRVICE lulPICil0N PLAN FIRST INitRVAL, fiksi PEll0D, FIRST CUTAGE (19P0)
CLAtt 2 SCHEDULED COMPOWINTS M1Ntits tfgJg W
0 ADME O 4 f MC. XI R t M SLMMARY EKAMINAT!DN AttA CA10Y EKAM E O t REMRKS NUMBER IDINilFlCAt!ON litM hi METHOD PROCEDURt CM R "CALIBRAf!ON BLOCK" 30 MS 200i+GA2 (f10 No B Mt 1. 21 551786 26LD C.F.2 MT WDEP T.1 R1 X
EKAMINED 1005 0F WELD LtNCfN. AUGMtWitD LONQ!iLCINAL WELD C5.$2 UT45 STP*UT41 40,C0 X
Ill. ht2.
"Cl*35"
$51788 27LU CF2 MT WDtP 7.1 R1 X
EXAMINtp 100% OF WELO LtNGTH. AUGMENitD i LONGITL21NU. 'VLD C5.52 0145
$1P U141 R0,C0 X * -
141 ett.
"Cl 55"
$51790 27 C.F*2 NT NDEP T.1 R1 X
AUONENitD 181* Bt!.
Pl?t TO PIPt C5.51 U145 STP U141 R0,CD X +.
OV "C8 35**
551792 27LD CF2 MT NDEP T.1 R1 X
EKAMINED 100% OF WELD LtNGIN. AUGMEWitD LONGitLDINAL ELD C5.52 Ut45 stP U141 R0.C0 X
Ill.Mt.
"CS 35" 551900 26tu C F.2 MT NotP 7.1 R1 X..*
tKAMINED 62% OF WELD LtNGTH. AUGMENitD LONGITLDINAL WELD C5.52 U145
$fP UT41 RO,C0 X +.
Isl.Bt2 LIMlit0 UT FROM THE DOWNSTREAM
-SIDE DUt 10 PIPE TAPER AND PIPE SUPPORT.
THE PIPt SUPPORT AREA WILL (XAMINED DURING THE NEXT REFUCLING OUTACE WHEN THE PIPE SUPPORT WILL St REMOVED.
- CS 35**
$51820 26 C.F.2 MT NDEP 7.1 R1 X
AUQMENitD 'Bl* SEZ.
+
- CS 5**
1 iG 2 33
.- ~ - -. -. -.... -... -..
~_ - - -.. - - - _._..
DATE: 02/23/91
$OUfN ftKAS PROJECT LLCCTRIC OtWERAf!N0 stall 0N UNIT 2 PAGtt IT htvill0N:
0 IWltRVICE IW8Pitfl0N PLAN fiktf 1NitRVAL, Pikli PERIOD, ))RBf OUTAot (1990)
CLAll 2 SCHEDULED COMP 0NEWit MAfN tilAM BYttig N
0 ADMC 0$ f ttC. Ni R E N
$LMMARY EXAMlbAt!ON AktA CATGY EXAM E OE REMARKS i
NUM$tt IDtWilflCAfl0N IflM NO MtfM00 PROCEDUNE C M R **CAlllRAfl0N BLOCK'*
j 30 Ms 2DDi.CA2 (Flo No t Ms. M 551640 29 C.f*2 NT NDEP 7.1 R1 X..
AUGMfWit0181. D82.
VALVE 10 PlPE C5.51 U145 stP Viti R0,C0 N
- Clal" 551860 29tb C.F.2 MT NDEP 7.1 R1 M
EKAMINED 100% OF WLD LtwofH. AUGMtWitD LONGITUDlNAL WELD C5.52 Uf45
'$fP*0141 n0,C0 X
188+Bt2.
- CS*34**
551670 29PL1 29FLB CC MT NDEP T.1 R1 X
TWO CODE ALLOWABLE LOW AMPLifuDi PIPE LUGS C3.20 UT&5 31P U138 R0,C0 X lNDICAfl0NS ON PL2 UlfM NO MEASURABLE c
U1451 ICN1 X
THROUCHWALL DIMENSIONS. AUGMENTED l
l Ill'8t!. LIMifED EXAMINAll0N DUE 10 P!PE LUG COWfl0VRAfl0N.
"Cla 34" 551860 SOLU C F*2 MT NDEP 7.1 R1 X..
EKAMINED 911 0F WELD LENGTH. LIMittD UT j
LONGif0DINAL W LD C5.52 Ut45 51P Uf41 R0,C0 X
IN AUGMENftD ISI AREA DUE TO PERMANtWT
. =
PlPt SUPPORT. AUGMENit0 l$latt2.
"Cs 34" -
551900 30 C*F*2 MT NDEP ?.1 R1 k..
AUQMEWit0 151. BEZ.
PIPE 10 PIPE C5.51 Uf45 51P*Uf41 R0,C0 X
- Cs.33++
l 551920 30LD 0 U M m D UT LONGifuDINAL W LD C
T45 U
R eCo X
lW AUGMENitD j$1 ARIA ggg 10 PERMANENT j
PIPE SUPPORT. AUGMENTED 131.Bt2.
"Cs 34" t
$$1940 31LU CF2 MT NDEP 7.1 R1-X EXAMINED 28% OF WLD LtNGTH. LIMlitD UT LONCir@lNAL WLD C5.52 U145 81P U141 R0,C0 X
IN AUGMENTED ISI AREA DUE TO PERMANENT O
ICN1 PIPt SUPPORT. AUGMENft0 181*8(2.
"Cl* 34" 2 34
~
Daft 02/23/91 SOUTH TEXAS PROJECT ELECTRIC CENERATING STAfl0N UNIT 2 FAG [t 26 Rivltl0N 0
IN$tRVICE INSPECTION PLAN FIR $f INTERVAL, FIR $f PERICC, FIRST OUTAGE (1990)
O MAfW STEM SYSTEM CLAtt 2 SCHEDULfD COMPONENT $
W 0
A8ME O O f SEC. XI R E N SUMMART EXAMINAtl0N AREA CATCT EKM t 0 t REMARKt WUMetR IDENTIFICAfl0N litM NO Mt1H00 PCOCEDURE CN R **CAlllRAfl0N BLOCL" 50 Mt.2001.CA2 (FIC NO B MS*1. 21
$$1960 31 C.F.2 MT NDEP 7.1 R1 X
AUQMENTED 181. Bt2.
PIPE TO P1Pt C5.51 UT45 STP.UT41 RO,C0 X
ICN1 eeCE*5**
16*Mt.2001.CA2 (FIG No e Ms 21
$$9520 1 C.F.2 MT NDEP 7.1 R1 X
TWO Di'l!'IONAL COVERAGE FROM THE P!PE EXTRUSION TO PIPt C5.51 UT45
$fP UT41 RO,C0 X
SIDE. # nMENTED !$1.BER.
"CS.15"
$59530 2 C F.2 MT NDEP 7.1 R1 MT RISCHEDULED FOR THE NEXT GUTAGE VMEN PIPE TO PIPE C5.51 UT45
$TP UT41 R0,C0 X
PlPt RESTRAlWT WILL BE REMOVED. TWO DILICTION COVERAGE OBTAINED FROM THE DOWNSTREAM SIDE DUE TO PIPE RESTRAlWT INTERFERENCE.
eeC8 15**
559540 3 C.F.2 MT NDEP 7.1 R1 X
TWO DIRECTIONAL COVERAGE OSTAlWED FROM Plvt TO WELD CAP C5.51 UT45 STP*UT41 R0,C0 X..
THE DOWNSTREAM $10t DUE TO BRANCH CONNECTION.
"C8 15" 6 Mt.2001.CA2f A) (FIC No B Mt 2) 566400 1 C.F.2 M7 NDtP 7.1 R1 X
TWO DIRECTIONAL COVERAGE 06TAlWED FROM EXTRUEION TO FLANGE C5.51 UT45 STP.UT41 R0,C0 X
THE FLANGE $1DE.
"CS 75" 6 MS 2001.GA2f t) (FIC No 3 Mt.21 566500 1 C.F 2 MT -
NDEP 7.1 R1 X
AUGMENTED l$1+ 8t!. TWO DIRECTIONAL EXTkus10N 10 FLANGE C5.51 UT45 STP UT41 R0,C0 X
CWERAGE OSTAINED FROM THE FLANCE $10E.
\\
V-oCs.75-2 35 i
m..
__,m
-.-. ~.. _... - -
DATE: 02/23/91 SOUTN TEKAS PROJECT ELECTRIC GENERATING STAtl0N UNIT 2 PAGE:
29 REV1810N:
0 INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PEkl00, Fitsi OUTAGE (1990)
CLAtt 2 SCHEDULED COMPOWENTS MAlW tit AM STITEM N
0 A9ME O G T SEC. XI R E N
SUMMARY
EXAMINAfl0N AREA CATGT EXAM E O E REMARKS NUMBER IDENTIFICAfl0N ITEM NO METN00 PRCIEDURE C M R
- CALIBRAfl0N BLOCK'*
c.............................................................
6 MS 2001 CASfC) (FIC Wo B MS 2) 566600 1 C.F.2 MT NDEP 7.1 R1 X *.
AUGMENTED 181* DEZ. TWO DIRECTIONAL EXTRU510N TO FLANGE C5.51 UT45 STP UT41 R0,C0 X
C0 VERGE 08TAINED FROM THE FLANGE SIDE.
- C$ 75**
6 Ms 2001. GA2fD) (Flc NO B Msg 566700 1 C F.2 MT NDEP 7.1 R1 X
AUGMENTED 181* DEZ. TWO DIRECTIONAL EXTRU$10N To FLANGE C5.51 UT45 STP UT41 RD,C0 X
COVERAGE DETAINED FROM THE FLANGE $1DE.
- Cs.75**
6 Ms 2001 CA2fE) (FIC No B MS 21 s
$66800 1 CF2 MT NDEP 7.1 R1 X
AUGMENTED l$1+ BEZ. TWO DIRECTIONAL EXTRUSION TO FLANGE C5.51 UT45 STP UT41 R0,CO X..
COVERAGE OSTAINED FROM THE FLANGE SIDE.
- C5 7J" 2 36
)
_. -.- -... -..~.. _ - - _...
Daft: 02/23/91 SOUTH ftXAt PROJECT ELECTRIC.sN* RATING STAil0N UNIT 2 PAGE:
30 REVis10N 0
lNSERVICE INSPECTION PLAN FIR $f INTERVAL, flR$f PERIOD, FIRST OUTAGE (1990)
CLAll 2 $CHEDULED COMPONENTS RtstDUAL NEAT REMOVAL SYSTEM X
0 ASME O G T SEC. XI R E N SU9%RT EXAMikAfl0N AREA CATGT EXAM E O E REMARKS N M ER IDENTIFICATION ITEM No METHOD PROCEDURE C M R "CAllBRAT!DN BLOCK" 14 RM.2102.KB2 (PtG No B.RN 1) 600000 1LU C.F.1 PT NDEP 6.2 R3 X..
EXAMINED 2.57 AT THE INTER $tCTING CIRC.
LONGITUDINAL WLD C5.12 UT45 STP UT31 R0,C0 X
WLD.
UT45T X
eegg.gpee 600040 i C.F.1 PT NDEP 6.2 R3 X
REDUCER TO PlPE C5.11 UT45 STP.UT31 R0,CO X
UT45T X +.
"$5 29'*
600060 1LD C.F.1 PT NDEP 6.2 R3 X
EXAMlWED 2.5T AT THE IWitt$tCTING CIRC.
LONGITUDlWAL WLD C5.12 UT45 STP UT31 R0,CO X
WELD.
UT45T X
eegg.gpee 12 RN.2102 KB2 (F10 NO B RN 11 601800 1 C F.1 PT NDEP 6.2 R3 x..
VALVE 10 PIPE C5.11 UT45 STP.UT52 R0,C0 X
U145T X
e.gg.20*O 601840.3 C.F*1 PT NDEP 6.2 R3 X
PIPE TO ELBOW C5.11 UT45 STP UT35 R0,C0 X
UT45T X
eess.13e, 601860 3LD C.F.1 PT
-NDEP 6.2 R3 X
EXAMlWED 2.5T AT THE INTER $fCTlWG CIRC.
LONGITLDINAL WLD C5.12 UT45 STP UT35 R0,C0
' W LD.
X UT45T X
- gs.13ee i
12 RN 2103 KB2 (FIG NO B RH-6) 740 1LU C.F.1 PT NDEP 6.2 R3 X
EXAMINED 2.5T AT THE INTER $tCTING CIRC.
LONGITLCINAL WELD C5.12 UT45 STP.UT35 A0.C0 X.
WLD.
UT45T X
ugg.13u.
2 37
.-n,.
y
+,n--
,, ~ - - -
Daft 02/23/91
$0VTH TEXA8 PROJECT ELECTRIC (.tNERAflWG STAfl0N UNIT 2 PACtl 31 REYll10N:
0 IN$tRVICt INSPttil0N PLAN FIRST INTERVAL, FIRST PERIOD, flR$f OUTAGE (1990)
CLAll 2 SCHEDULED COMPONENTS RESIDUAL HEAT RfMOVAL SYtitM N
0 AteE D G T SEC. XI R E N
$UpotART EkAMihATION AREA CATGT EKAM E OE REMARKS NUMttR IDENitPICAfl0N ITEM NO METHOD PROCEDURE C M R "CAllDRAfl0N BLUCK" 12 RN 2103 K82 (FIC NO I RN 6) 602760 1 C.F.1 PT WDtP 6.2 R3 X..
- . UT60 PERFORMED FOR INFORMAfl0N TO REDUCER TU PIPE CS 11 UT45 STP UT35 R0,C0 Assiti THE Rt80LUT10N OF THE UT45 X
UT45T X
INDICATION.
UT60*
X +
N022LE TO PIPE C5.11 UT45 STP UT35 R0,C0 X
UT45T X *
- e.gg.13u
(
608140 2 CF1 PT WDEP 6.2 R3
- x..
i PIPE 70 ELDOW C5.11 UT45 sTP.UT35 R0,C0 X
UT45T X
ugg.13ee 608160 2LD C.F.1 PT NDEP 6.2 R3 x..
tKAMlWED 2.5T AT THE INTER $1CilWG CIRC.
LONCITLDINAL WELD C5.12 UT45 STP UT35 R0.C0 X
WELD UT45T X
ee$S.13*e 8 RN 2106 K32 (Flo No B RN 7) 611960 13 C.f.1 PT NDEP 6.2 R3 X
- + UT60 REIRACTED $ HEAR USED FOR PlPt TO VALVE C5.11 UT45 STP.UT52 R0,C0 X
ADDITIONAL CovtRAGE.
UT45T X
UI60*
STP UT31 R0,C0 X
- . U160 REFRACTED 5 HEAR U$tD FOR i
VALVE TO PIPE C5.11 UT45 STP U152 R0,C0 X
l ADolff NAL CovtRAct.
UT45T X
UT60*
STP U131 R0,C0 X
+.
- egg.j ju 2 38
Daft 02/23/91
$0VfN f tKAl PROJECT ILECTRIC CthtRAflWG STAfl0N UWlf 2 PAGil 32 REVl810N:
0 INSfRVICE INSPICfl0W PLAN FIR $1 IkitkVAL, ilR$f PERite, fitti OUTA06 (1990)
CLAtt 2 $CHEDULED COMP 0Nikft Rf tfDUAL NEAT REMOVAL SYtfEN N
0 A6ME O O f SEC. XI R I N SU W Rf EXAMikAfl0N AktA CATOY EKAM E O t htMARKR NUMett IDtWilflCAfl0N litM NO MEINQD PROCEDURE CM R **CAllbtAfl0W BLOCK
B RN 2314 ta2 (FIC ho B RN 141 631000 1 C i+1 PT WDEP 6.2 R3 X-+
- . Uf 60 REFRACitD $MtAR Ult 0 FOR
+
VALW TO PIPE C5.11 Uf45 8tP Uf52 R0,C0
+ X
- A00lfl0NAL COVERA 08 Uf45f X
Uf60*
- X eegg.jjee l
2 39 l
O J
APPENDIX 2-B PERSONNEVEQUIPMENT/ MATERIALS l
O 2-40
I~
j APPENDIX 2-B j
PERSONNEL QUALIFICATIONS
)
1 Hamt Company
,UI gI g
yp s
I Anderson, A. R.
SwRI I"
I" I"
I" Fine, R. H.
SwRI III*
III-Jensen, W. A.
SwRI II Jackson, T. E.
SwRI II*
II II II i
Kleinjan, D. R.
SwRI II*
II II II i
Roberds, B. A.
SwRI II*
II II II a
I.ong, J. W.
SSI I
I I
Porterfield, C. E.
SSI I"
I" I"
Smith, D. J.
SSI II II II II Pennanen, A. R.
NES III*
III III II Graham, J. T.
HL&P II II -
II Hubbard, S. K.
HL&P III III III Halley, J. F.
Hl.&P O-II
- II II Murray, H. M.
Hl.AP i
I" Silva, P.
HIAP II II II Suhler, C. D.
HIAP II II II Kieler, W. D.
ESI II II II Company l-SwRI - Southwest Research Institute i
- Sonic Systems International, Inc.
NES
- Nuclear Energy Services HIAP - Houston Lighting & Power Company ESI.
- Ebasco Sewices, Inc.
l
- IGSCC Qualified by EPRI Ixvel I Trainee
2 i i
~I
- - - ~. - - - - -
~~
APPENDIX 2-B SwRI MATERIAL AND EQUIPMENT MATERIAL Certification Ta2s Date Berol Prismacolor Black Pencils #935, Log #2989 26 Feb 90 Berol Prismacolor White Pencils #938, Log #28%
26 Feb 90 Kodak Neutral Gray Card (1/64" Black Line),
Log #1766 02 May 83 MT No.14 AM Prepared Bath, Magnailux, Batch No. 86C089, Log #2214A 22 Apr 86 Batch No. 87C003, Log #2442 04 Mar 87 Batch No. 89G05K, Log #2995 14 Jul 89 PT Cleaner PR1, Ardrox, Batch OB130200 09 Apr 90 PT Cleaner PR1, Ardrox, Batch OD111000 08 Nov 90 PT Penetrant P6F2, Ardrox, Batch 9H0108 (#9265) 09 Apr 90 PT Developer D1, Ardrox, Batch 9L0808 21 Mar 90 Sonotrace 40, Batch #8979, Log #2857 11 Jan 90 O.
EOUIPMENT Brand Calibration Serial No, Date Pyrometer, Amprobe, Fastemp 083 28 Jun 90 Pyrometer, Amprobe, Festemp 112 07 Aug 90 Pyrometer, Amprobe, Fastemp 164 07 Aug 90 Pyrometer, Amprobe, Fastemp 170 28 Jun 90 Pyrometer, Amprobe, Fastemp 171 07 Aug 90 Pyrometer, Amprobe, Fastemp 175 28 Jun 90 Pyrometer, Amprobe, Fastemp 176 07 Aug 90 Magnetic Particle Yoke, Parker 800 05 Jun 90 Magnetic Particle Calibration Block, 11.3 lbs B7019816 17 Mar 81-Spectroline DM 365X Radiometer 164801 29 Aug 90 Pressure Gauge, Ashcroft PG 11 20 Sep 90 Pressure Gauge, Ashcroft PG 12 20 Sep 90 Neutral Grey Cards, Kodak (1/64" Black Line)
Log 1766 02 May 83 i
. 42 -
+
i APPENDIX 2 B SwRI MATERIAL AND EQUIPMENT, cont'd i
EOUIPMENT Calibration Brand Serial No.
Date l
Sonic FTS MK I 01103E 27 Aug 90 Fonic Imi MK I 01104E 18 Sep 90 Sonic FTS MK 1 01105E -
23 Aug 90 Sonic FTS MK I 01111E-28 Aug 90 Sonic FTS MK I 01114E 28 May 90 Sonic FTS MK I 04327E 20 Aug 90.
Sonic FTS MK I 04328E 26 Jun 90 1
Sonic FTS MK I 06582E 01 Oct 90 Sonic FTS MK I M907E 21 Jun 90 Sonic FTS MK I 06909E 29 May 90 Sonic "TS MK I 07010E 07 Sep 90 Sonic rTS MK I 07011E 07 Sep 90
'i Tectronix Oscilloscope 2335 B012689 03 Jul 90 1
O 2-43 i
l APPENDIX 2-B
,tO SwRI MATERIAL AND EQUIPMENT, cont'd i
TRANSDUCERS Certification Brand Serial No.
Date 3
Aerotech 12903 13 Nov 89 i
Aerotech H24833 08 Feb 90 Aerotech H31817 25 Sep 90 l
Aerotech K25224 12 Apr 90 Aerotech K30086 28 Nov 89 SwRJ 582 18 Dec 89 SwRI 784 08 Dec 89 SwRI 848 06 Aug 90 SwRI 1119 03 Aug 90 SwRI 1264 29 Mar 90 SwRI 1525 06 Mar 90 SwRI 1548 03 Aug 90 SwRI 1587 15 Jan 90 SwRI 1788 SwRI 03 Aug 90 1799 03 Aug 90 SwRI j806 SwRI 17 Apr 90 1814 08 Mar 90 SwRI 1977 15 Feb 90 SwRI 2521 13 Jul 90 SwRI 2553 06 Mar 90 SwRI 2672 08 Jan 90 SwRI 2673-02 Aug 90 SwRI 2784 07 Nov 89 SwRI 2832 17 Sep 90 SwRI 2884 18 Dec 89 SwRI 3193 18 Jan 90 SwRI 3438 08 Nov 89 SwRI 3439 08 Nov 89 SwRI 3782 05 Apr 90 SwRI 3785 06 Apr 90 2 44 u.
_...~.
APPENDIX 2 B HLAP MATERIAL, AND EQUIPMENT MATERIAL j
IXDC PT Ceaner SKC NF/ZC 7B, Mvaaflux, Batch 88C078 PT Cleaner SKC NF/ZC 78. t Aux, Batch 88F079 i
PT Penetrant ski-HF/S, s'
., Batch 87C037.
PT Penetrant SKleHF/S, Batch 89K01K 1
PT Developer SKD NFer
..uanux, Batch 88E035 l
PT Developer SKD NF/Z c Ngnaflux, Batch 89H0$S MT Powder, Gray No.1 EOUIPMENT Calibration Brand Sgrial No.
.Due Date Theunometer 100-00520 04 02 09 91 Thermometer 100 00520 15 03 23 91 Thermometer 100 00520 31 11 07 90 Thermometer 100-00520 46 10 27 90 Thermocouple 100-00534 32 03 19 91 0
Thermocouple 100 00534 39 02 10 91 Thermocouple 100-00534 41 12 15 91 Thermocouple 100 00534 47 12 18 91 MT Yoke, ElectroSpect ES X 6
N/A MT Yoke, Magnailux, Y 6 Y6 05 N/A Paint Thickness Gauge 100-01308 03-12/22/90 0
2 45 L
_,we--r-grm e-r =mMF'-W9 TN97-m--WS-*'wrv WT-gr-TIV*y'-g*
7" Trye" ewe 7Vyw W V ryrw--$r T+ vye-T*WW6_y9-gt-y-
- gg y F t v-,
& Par 4-
1 i
i J.
l t
t I
1.
1 8
4
'I i
I I
1 1
1 1
a
,4 I
I APPENDIX 2-C l
1 PROCEDURES 1
l 1
l 2
i k
2 46 I
l l
r l
l l
c, -....., -.. -.....,- -. - -, _..,_.__...
e.,-..
-,.w..___-_.--,.....-,,_...,.,...m._.-._.-,
_..,_...-..,.._-..----..-,--...~.m.------
1 J
APPENDIX 2 C i<
l SwRI OPERATING PROCEDURES Procedure No.
Title 4
SwRI NDE2MM Recording Data from Direct Visual, IJguld Penetrant and Magnetic Particle Examinations SwRI NDE3M/0 Recording Indications During Ultrasonic Examinations l
SwRI NDES/0M Ultrasonic IJnearity Measurements SwRI.NDE6MM Use of Customer Notification Fonns SwRI.NDE7/0M Weld Joint Identification Marking O
s 2-47
APPENDDC 2-C SwRI NDT PROCEDURES Procedure No.
Title STP-VT7/0/0 Visual Examination of Nuclear Power Plant Components STP-PT6/0/0 Fluorescent, Water Washable Uquid Penetrant Examination of Roto-Lok Studs STP MT2/0/0 Fluorescent Magnetic Particle Examination STP UT7/0/0 Manual Ultrasonic Examination of Reactor Coolant Pump Flywheels from the Access Holes STP UT11/0M Manual Ultrasonic Examination of Vessel To Nozzle In c xadius-Sections STP-UT15/0/0 Manual Ultrasonic Examination of Pressure Vessel Welds (Greater than 2 to 12 Inches in Thickness)'
STP-UT17/0/0 Manual Ultrasonic Examination of the Center Drilled Hole Surface in Pressure Retaining Studs Greater Than Greater Than 2 Inches in Diameter STP UT19/0/0 Manual Ultrasonic Examination of Pressure Retaining Round Nuts Greater Than Two Inches in Diameter STP UT21/0/0 Manual Ultrasonic Examination of Pressurizer Support Skirt Attachment Welds STP UT22/0/0 Manual Ultrasonic Examination of Reactor Pressure I C N N o. 1 Vessel Studs ICN No. 2 STP UT31/0/0 Manual Ultrasonic Examination of Austenitic Pressure Piping Welds STP UT35/0/0 Manual Ultrasonic Examination of Austenitic Thin Wall Piping Welds
__2 48
.J
APPENDIX 2-C
!O SwRI NDT PROCEDURES, ccmt'd Procedure No.
Title STP UT38/0/0 Manual Ultrasonic Examination of Pressure Piping ICN No.1 Support Attachments STP UT41/0/0 Manual Ultrasonic Examination of Ferritic Pressure ICN No.1 Piping Welds STP UT45/0/0 Manual Ultrasonic Examination of Pressure Vessel ICN No.1 Welds (0.4 to 2 laches in Thickness)
ICN No. 2 STP UT49/0/0 Manual Ultrasonic Examination Using I.ongitudinal Wave Straight Beam Techniques STP UT52/0/0 Manual Ultrasonic Examination of Similar and Dissimilar Metal Welds in Austenitic Piping Systems STP UT150/0/0 Manual Ultrasonic Examination of Reactor Pressure ICN No. I Vessel Welds in Accordance with Regulatory Guide 1.150.
E (9
y APPENDIX 2 C IIIAP PROCEDURES Procedure No.
Title NDEP 6.2 Rev. 3 Color Contrast Solvent Removable IJguld Penetrant Examirmtlon of h
ASME XI PSI /ISI NDEP 7.1 Rev.1 Dry Powder Magnetle Particle Examination for ASME XI PSI /ISI NDEP 9.3 Rev.1 ASME XI Examination for VT 1 and VT 3 O
h O
2 30 1,
--mm___m m-m
O 1
i APPENDIX 2-D ISI EXAMINATION LBIITATIONS p
f I
O 2.s1
t APPENDIX 2-D ISI EXAMINATION LIMITATIONS Table of Contents STPEGS 2 Summary of Inservice Examination Limitation PASA 2 53 Opls_i_ Component 1 ASME Category B A Reactor Pressure Vessel 2 56 ASME Category B D (yessurizer 2 57 ASME rlf#cory B F Preamth, t 2 58 ASME Catego f bG 1 T
2 59 RPV Closu.6 litad Bolting ASME Category &N Pressurizer 2 60 O
ASME Category D.J Piping 2 61 Residual Heat Removal System Class 2 Components ASME Category C A 2 62 Regenerative Heat Exchanger ASME Category C B 2-63 Regenerative Heat Exchanger ASME Category C-C Piping 2 64 Feedwater Main Steam
- 'SME Category C F 2 L
I Piping 2 65 Main Steam
)
o
(
2 52
d SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION, UNIT 2 O
SUMMARY
_OF INSERVICE EXAMINATION LIMITATIONS i
The following tables provide details on the limitations which were encountered during-the inservice examinations (ISI) at the South Texas Project Eleptric Generating Station (STP), Unit 2.
Each table of this' summary provides -the following information as described:
Column 1 Class / Category / Item No./ Examination Requirement 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 25001 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.
Column 2 Line No/ Subassembly 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 laentification number, SwRI 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, 6(TT) 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 uad the remaining balance from 100% as the total c verage.
't-O
-l 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 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 = a + 2*b (effective coverage formula, angle beam)-
where a = one direction only percentage b = two direction percentage :
Examples:-
p (1) none 1 dir 2 dir 0%
0%
100 %
c = 0 + 2
- 100
=-100% effective coverage O
~
- (2) none 1 dir 2 dir 0%
100 % 0 %
c = 100 +
= 50% effective coverage 2
(3) none 1 dir 2 dir 50 % 50 % 0%
c =50 +
= 25% ejective coverage 2
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
' n the calculation of the average.-
i 2-54
~
Column 5 Limitation O
A description of the type of limitation and primary reason for why the coverage was limited is provided in this section.
O 2 55 1
ASME SECTION XI CODE COVERAOE LIMITATIONS 5
4
'v' 1990 2RE01 ISI SOUTH TEXA8 FROJECT ELECTRIC OENERATINO STATION, UNTT 2 ARME CATIGOPY S-A SYSTDt: REACTOR FRES5URE VESSEL (CLASS 1)
- LINE NOJsVBA55CMJLY CLASS -
+ WELD IDENTIFICATION '
4COVERACE.
CATOY WELD ID FIOURE ITEM NO.
EXAM '.-
1 DIR 2-
- EFF, EXM RQT
- EXAMIN AT10N kt1m10D '
TYPE-NONE ONLY D!R -
COV.
TOTAL LattTATION 4
RFY2 UTO 30 70 LIMfTED UT DUE TO PROXIMITY OF FA 103-101 UT45 3
0 77 97 LIFTINO LUOS AND INSULATION Bl.21 FIOURE NO. A-RFV-3 UT45T 30 0
10 70 SUFFORT RINO.
VOL (Closum Hud)
UT60 1
0 99 90 DOME-TO-TORUS UT607 30 0
10 70 El UT
.w I
RFV2 UTO 95 LIMITED UT FROM THE FLANCE SIDE DUE FA 101-101 UT45 1
0 99 99 FLANGE CONFIOURATION.
81.40 FIOURE No. A-RFV-3 UT45T 5
0 95 95 VOU3URF (Closum Hud)
UT60 3
0 97 97 TORUS-TO-FLANGE UTe07 5
0 95 95 UT/MT MT 0
100 ks
\\b[
2-56 l
k I
v ASME SECTION XI CODE COVERAGE LIMITATIONS 1990 2RE01 ISI SOUTH TEXAS l'ROJECT ELECTRIC OENERATINO ST ATION, UNIT 2 ASME CATEGORY FD SYSTEM; PRESSURIZER (CLASSI)
- Lir4E NOJsVBASSEMBLY <
CLASS '.,.
- WELD IDENTIFICATION.,
's COVERAGE:
s CATOY;
- WELD ID MOURE :-
BPFl.
<l,.
rfnr TTEM Noi EXAMj' l DIR 2[j E
EXM RQT
- EX AMIN ATION METHOD -..
TYPE:
NONE ONLY D!R '-
COV.
TOTAL
> ' LIMITATION.--
^
I PRZ 3 UTD 31 69 NO UT FROM THE NOZZLE SIDE DUE TO -
D-D N3 UT43/to 4
96 0
48 FOZZLE CONFIOURATION.
83.110 FIGURE NO. A PRZ-1 UT457 31 0
69 VOL UTeof 31 0
69 69 SHELL-TO-NOZZLE M
ITT I
FRZ-2 UTO 30 70 NO UT FROM THE NOZZLE SIDE DUE TO B-D N4A UT43/60 4
96 0
de NOZZLE CONFIOURATION.
83.110 FIGURENO A PRZ 1 UT45T 30 0
70 70 VOL UT607 30 0
70 70 SHELL-TO NOZZLE 65 UT b
2 57 s
ASME SECTION XI CODE COVEP. AGE LIMITA'110NS 1990 2RE01 ISI SOUTH TEXAS PROJECT ELBCTRIC OENERATINO STATION, UNTT 2 ASME CATHOORY D-P SYSTEM: PRfAsURIZER (CLASS I)
- LINE NOJSUBASSEMBLY J
>+
.R %
~
p; N:
ey CLA&S,
5 WELD IDENTIFICATION JA It COVERIOE i'
^
le;y 4
CA10Y::
- WELD ID PIOURE h c;0
?.,, g
- fTID4 NO.
EXAMT 1 DIR fj (
EFF.
',[
- p!:,; ) [
EXM RQT
- EXAMINATION METHOD :.
TYPE ~-
NONE ONLY DIR "
COV.
TOTAL -
? LIMITATION 0 1
PRZ-2 UT43 6
50 44 69 LIMITED UT45 FROM THE SAE END SIDE S-P N3-SE UT437 0
0 100 100 DUE TO N0ZZLE CONFIGURATION.
R$.40 FIOURE NO, A-PRZ-1 SS VOU5URF
. NOZZLE-TO SAFE END UT/PT M
0
=
100 1
PRZ 2 UT4)
Il 49 40 65 LIMITED UT43 FROM THE SAFE END SIDE 9-P N4A 5E UT45T 0
0 100 100 DUE TO NOZZLE CONFIOURATION.
33.40 FIGURE NO, A-PRZ-1.
42 VOUSURF NOZZLE-TO-SAFE END UT/FT PT 0
100 i
a 2-58
i ASME SECTION XI CODE COVERAGE LIMITATIONS 1990 2RE01 ISI SOUTH TEXA8 PROJECT ELECTRIC OENERATMO STATION, UNIT 2 -
AME CATBOORY D-O-1 SYSTEM: RFV CLO8URE HEAD DOLTNO (CLAS$ I) i
.3 7 LINE NOJ8UBASSEMBLY<
~
,s
,4 7-g;;
CLA88 G '
- WELD IDENTIFICATION 5COVERAOR e-x CA'10Y-$ - WELD 3D FIOURE y
_g
$4 3, s g4Nh'f' s,,[.h,'
x
~
4@s-ITEM NO,
. t w..
s EXAM" I DIR !s 1, EPP.._..
WJ?d
'jn ;'h VN 7,
EXM RQT
- EXAMNATION METHOD' '
TYPE:
NONE ONLY DIR
COV.
TOTAL I
IE"
- LIMTTATirtNO s2 I^
1 CLOSURE NUTS U1D.
9 98 LD41TED UT PROM THE OD SURFACE DUE _
FOl 1 A,4 A,7A.10A,13A,16A, UT43 0
18 82 91 TO SPANNER WRENCH SLOT 8.
86.10 -
- 19A.22A,2$A,28A.S L A.MA 91 UT PERFORMED A8 A SUPPLEMENTAL' SURP PROURE NO. A-RPV-2 EXAMMATION OF THE THREADED AREA.
MT PERPORMED ON ALL SURPACE8 EXCEPT THE THREADED PORTION DUE TO MT YOKE tJT/MT MT 0
100 ACCESS.
I CLOSURE STUD 8 UT43/40 0
11 89 95 D-O-1 I A.4A,7A.10A 13A.16A.
EXAMNATION VOLUME N ACCORDANCE 95 WITH CODE CASE N 3071, 36.30 19A,22A 25A,28A,31 A,34A VOUSURP LIMITED UT OF THE ROTO-LOK LUO8 DUE PROURENO. A RPV-2 TO CONPIOURATION OF THE LUO8.
UT/MT/PT MT/PT 0
=
=
100 3
(Q 2-59 i
n
. ~,
~
O ASME SECTION XI CODE COVERAGE LIMITATIONS 1990 2RE01 ISI SolfTH TEXA8 PROJECT ELECTRIC OENERATING STATION, UNTT 2 ASME cal t900RY B-M SYSTEM: PRESSURIZER (CLASS !)
- LINE NOJ50BA88EMBLY,-n CLASS :
WELD IDENTIFICATION 1
&,4".;.
- g,, -...., _
t 5COVERAGEi CATOYJ WELD ID FIOURE 5 e
'hi TTEM NO,
..... i. ;.....
EXAMn I DIR 2;.
COV.
TOTAL
- LIMTTATION s EXM RQT - EXAMNATION METHOD -
TYPE' NONE ONLY DIR 2
. x1 T-1E EFF.
]
y 3
.,s.
PRZ-2 PT 10 90 NO PT ON TOP OF THE BRACKETS DUE TO B-H I A,13,2A.28 PROXIMITY OF PERMANENT SUPPORT 88.30 FlOURE NO, A PRZ 1 FRAME.
SURF VT 1 PERPORMED A8 A SUPPLEMENTAL SUPPORT BRACKETS EXAMMATION.
PT e
%)
2 60
l.
I ASME SECTION XI CODE COVERAGE LIMITATIONS 1990 2RE01 IS1 SOUTH TEXAS PROJBCT ELBCTRIC OENERATINO STAT 10N, UNIT 2 ASME CATinORY B-J SYSTEM: RESIDUAL HEAT REMOVAL (CLASS I)
- LINE NOJsVSAssEMBLY:-
CLASS 7 WELD IDID4TIP1 CATION.;
'#COVERicBC
, W.
W
~
4 CATOY,;.
- WELD ID FIGURE :'
-4 TTPAt NO; EXAM; I DIR 3%
EFF,.
ppt g
g.
'(4 EXM RQT EXAMINATION METHOD - - TYPE-NONE ONLY DtR '
COV.
TOTAL LIMfTATION i-s 1
IO-RH 2500 UT45 0
0 100 100 NO UT45T ON THE REDUCING TEE SIDE t-1 3
UT45T 10 0
42 82 DUE TO REDUCINO TEE CONFIOURATION.
D9.11 FMURENO. A RH-S 91 VO!/SURP REDUCINO TEE-To PIPE UT/FT PT 0
100 I
6-RM 250s UT45/eo 0
25 Tl 99 LIMITF55[r PROM THE VALVE SIDE DUE B-3 1
UT45T 0
0
-100 100 TO VALVE CONFIGURATlON.
99.11 FIOURE NO. A RH 5 W
Vo1>5URP YALVE-To-PIPE UTIFT FT 0
=
100
.r
\\
2 61
-. - ~. -. - - -......
ASME SECTION XI CODE COVERAGE LIMITATIONS i
1990 2REo1 ist -
SOUTH TEXAS PROJECT ELBCTRIC OENEA,.TINO STATION, UNIT 2
)
ASME CATBOORY C-A l
SYSTEM: REOENERAT!VE HEAT EXCH ANOER (CLASS 2) '
- LINE NOJSUBA45DIBLY;-
j _,...
s 7
s
- g.. 7 class; WELD IDENTIFICATION,
i E COVERAOE t htl:,
CATOY._
- WELD ID FIOURE 5 'i%
I DIR l '<
EFF..
c;w,
s ITDI No;;
..., K
._..,./
EXAMi s
EXM RQT
- EXAMINATION METHOD ~
TYPE' NONE ONLY DIR -
COV.
TOTAL i
LIMITATION T 1
(2AHRO-2A UT4SMO I
3 M
M LIMITED UT PROM THE SHELL SIDE DUE.
C-A 82 UT457
-0 0
100 100 TO PROXIMTTY OF BRANCH CONNECTION Cl.30 FIOURE NO. >ROX-1 99 NO UT PROM THE TUBE SHEET SIDE DUE VOL TO TURE SHEET CONFIOURATION!
1UBE SHEET-TO-BHELL UT 1
UT45M0 1
3 pe LIMITED UT PROM THE SHELL 31DE DUE CA 37 UT43T 0
0 100 100 TO PROXIMTTY OF BRANCH CONNECTION.
Cl.30 FIOURE NO. B-ROX 1.
99 NO ITT FROM THE TVBE SHEET SIDE DUE VOL '
TO TUBE SHEET CONFIOURATION, SHELL-TO-TUBE SHEET UT
\\
i Lt 2-62 L
l l
1
.. ~.....
~
l I
ASME SECTION XI CODE COVERAGE LIMITATIONS 1990 2RE01 ISI SOUTH TEXAS PROJIICT ELIK.TIUC OENERATINO STAT 10N UNTT 2 A5ME CATBOORY C-B SYSTIN: RB0llNERATIVE HEAT EXCHANGER (CLASS 2)
- LINE NOJ8 USA 88EMBLY.
CLAS8'1
- V"JLD IDENTIFICATION { [
p w:in s a. r
,.s 4
'5COVERAOE??DI
"; ^W 'D9[i g[
f.
CATOY;;~.
- WELD ID F10URE 2
~
[%" x'9^3 Q.._, 7g,[T ', [QEF
- " " ' ~
' ' 'p f,
.x 1.
ITIN Hoi l';.
l.R.. %
EXAMb
~11 7
y3
,s s
l'DIR 2h, EFF[ ik EXM RQT EXAMINATION METHOD -
TYPE-Not:5ONLY DIR i COV.
TOTAL
' LMITATIONT 2
CSAHRO-2A UT45/to 3
1
-M F7 LIMITED UT PROM THE NOZZLE SIDE DUE C-B SI UT43T
- 18 4
78 to 70 PROXIMITY OF BRANCH CONNECTION.
C2.21 F10URE No. B-ROX 1 88 No UT PROM THE TUDE SHEET SIDE DUE VOl>5URF TO TUBE SHEET CONP10VRAT10N, N0ZZLB TO TUBE SHEET UTIFT FT 0
100 2
CSAHRO-2A.
UT45/to 0
1 99 100 L.IMITED UT FROM [HE NOZZLE SIDE DUE C-3 88 UT437 18 0
82 82 TO PROXIMITY OF BRANCH CONNECTION.
C2.21 FIGURE NO. B-ROX l 91 NO UT PROM THE TUBE SHEET SIDE DUE VOL/sVRP TO TUBE SHEET CONFIGURATION, N0ZZLE-TO-TUBE SHEET UT/FT PT 0
100
=
=
l V
1 OV 2-63
l 1
ASME SEC1'lON XI CODE COVERAGE LIMITATIONS 1990 2RE01 ISI i
SOUTH TEXAS PROJBCT ELECTRIC OENERATNO STATION, UNIT 2 Ame CATE00RY C C SYSTIM: FREDWATER (CLASS 2) i t
aa_
LINE N015USAs5EMBLY j
. g f, c-y s _,
,s., 76
~
s COVERAGE t Ag' 'y
- rc m%g... W7i?. S ^
CLAaB3+
- WELD IDENTFICATIO.N P MUt!
,.o
's a, c.,
- . -.f. Q.,.c..
CATOY;i
- W
((. ELD ID FIOUREi$$$ ; j.. [,
EXAM)
.,4>
p" 7
s,
.g
'3 5 W?W "
m,*;.% s
- I't#
s w-2 EFF.'
,{, [h&f hfk[ _ [hr,~ '
.J l ITEM NUk
+3 D(IR -J
.m.
g,,
1DR EXM RQT
= EXAMINAT10N MirrHOD TYPEE NONE ONLY COV.
TOTAL
^4 lLIMffATION YW:.,_.
I 14-FW 2029 UT43 1
35 64 82 LIMITED UT AND MT COVERAOE DUE TO CC IPLt IPL4 -
82 ?PELVOCONFIOURATION.
C3.30 FIGURE NO. B-FW-1 SURF YOL*
FRELUOs UTIFT PT 49
$1
- - ADOMENTED 181 - BI2 SYSTEM: MAN STEAM (CLAS8 2) -
- LINE NOJ3USASSEMBLY 1 CLA38 ?.
- WELD D."NTIFICATION f
..g_ -
y,....s y.
gg
' 4
'4 1:gg.
- 5 COVERAGE E
- r J s
N,' J@N.. ' ' Sh CATOY-
_ WELD ID FIGURE i * '
f N-t tm,.,
-$; f-%y, c,s,.W j$.,.. _ a fis [ ' ^
~ ~n 4,
x TTEM N0;
.j__.,_.___M LKAM i
- l. DIR 2L..
n.1 EFFJ a
lf Q g-EXM RQT
+ EXAMINATION METHOD :
TYPE" NONE ONLY DIRT COV.
TOTAL
^
> F4MLIMTTATIONfR ' +
2 30-MS-2001 UT45 T2 30 7e
. at C-C 29PLl 29PLS LIMITED UT AND MT COVERAGE DUE To d
88 PPE LUO CONF 10URAT10N.
C3.2 F10URE NO. B-M8-2 SURF YOL*
FPE LUOs UTIPT PT 46 1
M
- AUOMENTED ISI-BEZ 2 64'
~ =. - -
. ~..
ASME SECTION XI CODE COVERAGE LIMITATIONS OV 1990 2RE01 ISI SOUTH TEXAS FROJECT ELPLTRIC OENERATNO STATION. UNIT 2 ASME CATBOORY C-P-2 SYSTEM: MAN STEAM (t1 ASS 2)
- LNE NOJSUBASSEMBLYg CLASS:
+ WELD IDENT[FICATION :. '
<di
% COVERAGE a
gs.
1 CATOYC
- WELD 3D FIGURE i i"
1 s
s TTEM NOJ EXAMf I DIR 2 :l _
EFF.'
x EXM RQT
- EXAMINATION METHOD TYPE
NONE ONLY DIR.
COV.
TOTAL
-' LIMTTATlON
2 30-MS-2001 UT45 13 0
87 87 LIMTTED UTMT DUE TO PROXIMTTY OF C-P-2 26 87 PFJtMANINT P&E SUPPORT, C5J1 FIOURE No. D-MS-2 VOUSURP PIPS TO PIPE UT/MT MT 11 89 2
30-MS-2004 UT45 9
0 91 91 LIMITED UT DUE TO PROXIMTTY OF C-P-2 30LU 91 PERMANENT PRE SUPPORT.
C5.32 FIGURE NO. B-MS-2
'M L TTED N AUOMENTED ISI-BEZ AREA VOU5URP OF LONOTTUDNAL %T.LD.
100
=
=
2 30-MS-2001 UT45 48 0
32 32 LIMTTED UTMt DUE TO PROXIMTTY OP g
C-F-2 30LD 52 PERMWENT PRE SUPPORT.
{
C$.32 FIGURE NO. B-MS-2 LIVE N AUOMENTED ISI-BEZ AREA V
VOUSURP OP LONOTTUDNAL WELD.
$2 2
30-MS-MI -
UT45 s.
0 28 28 LIMITED UTMT DUE TO PROXIMTTY OF C-P-2 SILU 28 PERMANENT PRE SUPPORT.
C5.32 FIGURE NO. B-MS-2 LIMTTED N AUOMENTED ISI-BEZ AREA VOUEURP OF LONOTTUDINAL WELDi LONOTTUDNAL WELD UTMT MT 72 28 4
r
'y 2-65 1
1
V APPENDIX 2-E Ov.
OWNER'S REPORT FOR INSERVICE INSPECTIONS NIS-1 FORMS
(
2-66 i
I 1990 ISI. 2RE01. Welds (Class 1)
Page 1 of 3 FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECITONS As requiral by (Fe Provisions of the ASMB Code Rules p
- 1. Owner Houston Lichtint &, rwer Company: Electric Tower: P.O. Box 1700: Houston. Texas 77001 l
U (Name and Address of Owner)
i (Name and Address of Plant)
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorization (if required) NA
- 5. Commercial Service Date 06/1929
- 6. National Board Number for Unit NA
- 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 Appurtenance or Installer Serial No.
Board No.
Class 1 Pinine Ebasco (I)
N.A.
N.A.
Reactor Picsiure Combustion Engineering /
Vessel Westingho_use (M) 12173 22391 Jressurizer Westinghouse (M) 2161 19 Steam
__ Generator 2A Westinghou,e (M) 2151 29 Steam Generator 2B Westinchouse (M) 2152 30 Steam
~
Generator 2C Westinehouse (M)
Os Steam
~
2153 31 Q
_GCDerator 2D Westinghouse (M) 2154 32 Reactor Coolant 1080-Pump 2A Westinghouse (M) 1163E2rG01 14_
46 i
Note: Supplemental sheets in form of lists, sketches, or drawings may be used, provided (1) size is 8% in.
O) x 11 in., (2) Information in items 1 through 6 on this report is included on each sheet, and (3) each sheet is numbered and the number of sheets is recorded at the top of cach form.
l 1
2 67
1990 ISI. 2RE01. Welds (Class 1)
Page 2 of 3 FORai NIS 1 (Back)
- 8. Examination Dates 08S 1 0 to 11/0190 _ 9. Inspection Interval from 06/19189 to.Na/1999.
psj
- 10. Abstract of Examinations. Include a list of examinations and a statement concern g status of work required for current interval. (ASME Code Class 1 (IWB) Items. Welds Progrrm)
See Sr 'lon 2.4 and Appendix 2-A of 2RE01 Summary Report for list of examn.at!ans performed.
- 11. Abstract of Conditions Noted.
Evidence of leakage was noted on the Pressurlict manwiy botting and 2(1.5) CV 2122 4FB (piping flange boltin6 Volumetric examination of Pressurizer welds PRZ 2 N3 (nonJc-to-shell) and PRZ-2-SK (supput skirt) revealed code allowsble flaws. These same (Liws were detected during PSI and dispositioned as cceeptable. See Section 2.5 of 2RE01 Summary Report for discussion.
- 12. Abstract of Corrective Measures Recommended and Taken.
%c Pressurlict manway bolting and 2(1.5)-CV 2122-4FB cvidence of leakage was evaluated and found acceptable for mntinued service. Ilowcwr, corrective action was specified for these botting mnnections to be reworked. His rework was not performed during 2RE01. No additional corrective measures were taken or recommended.
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 ICS.2Z. __,19 9 i Signed Houston 1.ichting & Pow ( Co. By i
Owner
- h. L Bev O
LJ CERTIFICNIE OF INSERVICE INSPECTION I, the unde.rsigned, holding a valid commission issued by the National Board of Boller and Pressure Vessel Inspectors and the State or Province of Texas and employed by Arkwricht Mutual Insurance Co.
of Norwod. Mass have inspected the components described in this Owner's Report during the period 1W9'- /- Go to
"? 4 8-93
. and state that to the best of my knowledge and belief, the O(ndrTa's 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.
g Factory Mutual System Al. uw 'N Commissions Tex 826
' Ihspector's Signature National Board, State, Province, and Endorsements B. R. Russell Date d ' M 19 9/
O L.)
I 2-68 l
1990151 2RE01. We13 (Class 1) l Page 3 of 3 SUPPLEMENT TO PORM NIS 1 OWNER'S REPORT FOR INSERVICE INSPECTIONS FOR ASME Code Class 1 OWB) Items Welds Program O
L Owner _ Houston Lichtine & Power Company: Electric Tower: P.O. Box 1700Wouston. Texas 7700_1_
V (Name and Address of Owner)
- 2. Plant,$outh Texas Project Electric Generatine Station: P.O. Box 289LWadsworth. 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 Boa:J Number for Unit --N.A.
ASMB ASMB COMPONENT EXAM CA'IY1Y TIEM or SYS7EM.,,,
IDPNT1 FICA 110N NO.
MFi1IOD REMARKS BA Bl.40 RPV RPV2101401 UT,hrt Oosuit Head Torus to flange BA B121 RPV RPY2403101 LTT Oosure Head Dome to Torus BA Bl.22 RPV RPV2401104A LTT 00s llead Mer!d. Weld (Aa. 0)
BA Bl.22 RPV RPV2-101104B LTT Cks Head Merid Weld (Az. 90)
B-N4 B13.10 RPV VESSEL INTERIOR VT3 Accessit4e areas B44 B630 RPV 1,4,7,10,13,16,19,22,25,28,31 & 34 LTT,MTyr RPV Ckuure Studs B-04 B6.10 RPV 1.4.7,10,13,16,19,22,25,28.31 A34 MT,lTT RPV Coeure Nuts B-04 B630 RPV 1,4,7,10,13,16,19,22,25,28,31 & 34 Vr4 RPV Cosure Washers B-D B3.110 PRI PRZ 2 N3 LIT Safety Nozzle to Shen BD B3.120 PRZ PRZ 2 N34R UT Safety Nozzle Inner Radius B-F B5.40 PRZ PRZ 2 N3 $B IJT7T Safety Nor21c to Safe End BD B3.110 PRZ PRZ 2 N4A LTT Relief Nozzle to Shell BD B3120 PRZ PRZ 2 N4A4R UT Relief Nozzle Inner Radius BF B5.40 PRI PRZ 2 N4A SB UT,PT Relief NozzJe to Safe End B04 B720 PRZ 1thru16 VT4 Manway Bolting B-H 118.20 PRZ PRZ 21 A,1B,2A,2B IT Support Brackets BH B8.20 PRZ PRZ 2 SK MT,tTT Support Skirt Weld B02 B730 SO S0 2A 1MB (Baseline)
VT1 Inlet Manway Bolting n
R02 B730 50 i
VT.1 Outlet Manway Bolung
(
B04 B7 30 SO S0 281MB (Baseline)
Vr4 Inlet Manway Botting BO2 B730 50 50 28 OMB (Baseline)
VT.1 Outlet Manway Botting BO2 B7,30 SO
$0 2C4MB (Baseline)
VT4 Intet Manway Boliing B04 B730 SO SG 2C OMB (Baseline)
VT4 Outlet Manway Bolting BO2 B730 SO
$0 2D 1MB (Baseline)
VT.1 b4et Manway Bolting BO2 B7.30 SJ S0 2D OMB (B:.seline)
VT.I '
Outlet Manway Bolting B-04 B7.60 RCP 2A RCP 2A SHB (1 thru 5)
VT.1 Seal llousing Boliing BJ B9.21 CV 2 CV 2122 3 PT Piping Butt Weld B4 B9.21 CV 2 CV 2122 8 PT Piping Butt Weld B4 B921 CV 2 CV 2128 3 PT Piping Butt Weld DJ B9.21 CV 2(1.5FCV 2122 4 IT Piping Butt Weld B-O-2 B7.50 CV 2(1.5)-CV 2122-4FB Vr4 Flange Bolting B4 B921 CV 2(1.5)-CV.2128-2 PT Firing Butt Weld B-0 2 B7.50 CV 2(15)-CV 2128 2FB VT.1 Flange Boliing B4 B9.11 RC 6 RC 20044 LTT,PT Piping Butt Weld B4 B9,11 RC 6-RC 20154 UT7T Piplog Butt Weld B4 B9.11 RC 6 RC 2015 9 UT7T Piping Butt Weld DJ B9.11 RC 6-RC401544 UT7T Piping Butt Weld 84 B9.40 RC 2 RC 22201 IT Piping Socket Weld BJ B9.21 RC 2 RC 24194 IT Piping Buti Weld B4 B9.11 RH 12.RH 23012 UT,PT Piping Butt Weld DJ B9.11 RH 12 RH 23018 UTyr Peing Butt Weld B4 B9.11 RH 12 RH 2301 to UTyr Piping Butt Weld B4 B9.11 RH 10 RH 2303 7 LTryr Piping Butt Weld B4 B9.11 RH 10 Ril 2308-3 UT,PT Piping Butt Weld B4 B9.11 RH B RH 23084 UTyr Piping Butt Weld r
(3 HL ff'
{
O'E xj Ad/ /
2 22 / 91 p-?8-9 9 2-69 l
PORM NIS.1 OWNER'S REPORT POR INSERVICE INSPECI1ONS-As required by the Provisloas of the ASMB Code Rules :
- 1. Owner _ Houston Llehtina & Power Comnany: Electric Tower: P.O. Box 1700: Houston. Texas 77001
~
(Name and Addicss of Owser)
- 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 Certl6cate of Authorization (if required) N.A.
j
)
- 5. Commercial Service Date 963MEL 6. Nation:1 Board Number for Unit _ NA
- (See Pase 3 of 3 for Identination Numbers)'
Manufacturer -
Component or -
Manufacturer or Install r National Appurtenance or Installer 1 Serial No.
Board No.
_Qass 2 Pinine Ebasco (I)
NA Regenerative' NA
_HeatExchancer Josenh Oat Corn. (Mi 2380.1B RHR 2052-Heat Exchanger 2A Joseph Oat Corp. (M) 23124D 993 O
i 1
Note: Supplemental sheets in form of lists, sketches, or drawings may be used, provided (1) size x 11 in., (2) Information la items 1 through 6 on this report is included on each sheet, and (3) eac is numbered and the number of sheets is recorded at the top of each form.
2-70 I
131 J2RE01. Welds (Class 2)
Page 2 d I pg ggs.1 (BacQ
- 8. Examinatl'on Dates - 09/19SO _ to - 11A)S/90-
_9. Inspection Interval from 06/19189 to 06/19199
,q
- 10. Abstract of Examinations, include a list of examinations and a ststement 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 2RE01 Summary Report for list of examinations performed. -
4
- 11. Abstract of Conditions Noted.
Volumetric examination of 30 MS-200129PL2 (plpe lug) in accordance with Augmented ISI BEZ_
l 1
requirements revealed code allowable flaws. Thme same flaws were detected during the PSI and dispositioned as acreptable. See Section 2.5 of 2REGl Summary Report for discussloa.
- 12. Abstract of Corrective Measures Recommended and Taken.
1 No mrrective measures were taken or rcoommended.
We certify that the statements made in this report are mrrect and the examinations and corrective measures taken conform to the rules of ASME Code,Section XI.'
i Certificate of Authorization No.(if applicable)
N.A.
Erpiration Date -
N.A.
Date.__IE13 7 Z.
19 i Signed,,}]p31 ton Lichtine & Power Co._ ByNA.
M_
Owner h.L.Beverl 1
AU CERTIFICA*lT! OF INSERVICE INSPECrlON 1, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectos and the State or Province of Texas and employed by Arkwricht Mutual Insurance Co.
F#d- /-*of Norwoo<!. Mass _ have inspected the components described in this Owner's Report during t
~
to _-_ J - M-c?/
_. 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-la this Owner's Report.
Furthermore, neither the Inspector not his employer shall be liable in any manner for any personal injury or propert damage or a loss of any kind arising from or conaccted with this inspection.
Factory Mutual Splem wP Commissions Tex 826 Inspector's Signature National Board, State, Province, and Endorsements B. R. Russell Date J-J6-19 9/
r 2-71 j
l
1990 ISI,2RE01 + W4)ds (Qass 2)
Page 3 of 31 SUPPLEMENT 'lV PORM N151 OWNER'S REPORT POR INSERVICE INSPECrlONS
- POR -.
ASME Code Oass 2 (IWC) Items. Welds Prog, 2
14 Owner Houston Linhtine & Power Comnany: Electric Tower: P.O. Box 1700: Houston. Texas 77001~
7\\
(Name and Address of Owner)-
j 2 Plant South Texas Protect Electric Generatina Station: P.O. Box 289: Wadsworth. Texas 774
~
(Name and Address of Plant) i'
- 3. Plant Unit - 2
_4 Owner and Certificate of Authorization (if required)
N.A. -
5, Commercial Service Date 06/19189
- 6. National Board Number for Unit - N.A.
a ASMB ASME COMPONINT EXAM ff[gy 1111g gr SYlftEM IDFNrtFICA'110N NO -
MirINOD REMAREE CB
- C2.21 Regn HX.
GAHROGA41-III,PT Nosale40 Tube Sheet -
C-A -
C130 Regn HX CSAHRO4A 82 LTT
- Tube Sheet 40-Shell C.A C1Jo Regn HX CSAHRO 2A47 ~
UT Shell40-Tbbe Sheet -.
. C.B -
C2.21 Regn HX g
- GAHRO 2A48 J UT7T Tutie Itheet40 Nossle =..
CC c 10 Regn HX-GAHRO 2A A(14)-
1 PT -
Support Aitachement Welds CA C1.30 RHR HX RitAHRS 2A41
- LTT Head to Shell C F'2 C5J1
'AF 8 AF4006(C]1 LTT.MT Piping Butt Weld OC C3.20 - AF 8 AF 2006[C] 20PL(14) :
MT Pipe top CC C3.20 AF 8 AF4006[C] 24Pyl 4) hrt.
Pipe 1up C-F 2 C5 51 AF 8 AF 2006(Ol4 UT,MT Piping Butt Weld ;
C F4 C5J1 AF 8 AF4008(0)1-_
. Piping Butt WeW -
C F4 _
C5 51 AF.
6 AF4006-1 '
Piping Butt Weld C-F1 C5.11,12 Cs 12 CS 21012,2LU,2LD ITT7T
- Piping BattAnng. Welds :
CF1 CS
- 8 CS 2102 4,4LU,4LD UT7T Piping Buttioog. WeWs C F1 Q _
Piping Bust /Long. Welds e C F2 C5 51 FW 18 FW 20121 -
Piping Butt Weld CF2 C531 FW 18 FW4012 2
'UT,hrt -
Piping Butt Weld O
_ Piping Butt Weld C F4 C5.51 FW 18 FW4012 4 UT.MT Piping Butt Weld C-F 2 C5.51 FW 18 FW40291 UT,MT '.
- Piping Butt Weld
CC:
C3.20 FW-18 FW40291PL(14)
- C5J1, FW-
.18 FW4029 2 LTT,hrt
- Piping Butt Weld.
CF2 C5 51 FW 18 FW4029-3 UT.MT -
Piping Butt Weld C F4 C5 51 ~ FW 18-FW 2029 4 LTT.MT Piping Butt Weld -
C F4 C5.51,52 MS
%MS 200121,21LU1/0,21LD 1TT,MT Piping But16. Welds CF-2 C531,52 MS SMS 200123,23LU,
UT,hrr
. Piping Butt /Long Welds.
3 CF2 CS.51,52 MS -
SMS 200124,24LD ;
UT,MT Piping Butt /leng. Welds C F4 C5.51,52 MS EMS-200145,25LU,25LD tTT.MT Piping Buttions, Welds -
CF4 C5.51,52 ~ MS
%MS 200146,26LU,26LD -
UT MT Piping Butt /long. Welds C F2 -
C5 51,52 MS 30 MS 2001-27,27LU,27LD :
C F4 C5.51,52 MS
. 30 MS 200129,29LD -
1 LTT.MT Piping Butt /long. Weids.
CC~
C3.20 ' MS 4 SMS 200129PM14)
UT,MT Pipe Lup CF4 C5J1,52 MS SMS 200140,30LU,30LD -
LTT,MT Piping Butt /long. Welds -
CF2 C5 51,52 MS MMS 200131, SILU
- LTT,MT -
Piping ButtAong. Welds CF2-C5.51 ' MS 16 MS 20011 UT,MT
- Piping Butt Weld "
CF2-C531-MS 16-MS 20013 :
_ ITT,MT
- Piping Butt Weld C F-2 C5.51 MS-6 MS 20011A
-CF2 C531 MS 6 MS 20011B 1TT,MT -
Piping Butt Weld
'CF2 C5.51 MS
. 6 MS 20011C _
Piping Butt Weld C.F.2 -
C5.51
Piping Butt Weld C-F 2 C3.51 MS 6-MS 2001 lE '
LTT,MT
- Piping Butt Weld CF1-
~ C511,12 RH 14 RH 21021, ILU,1LD UT7T
- Piping ButtAmng. Welds C-F1" C5.11 '
'RH.
~12 RH 2102-1.
UT7T Pipin. Butt Weld CF1
' C5.11,12 RH 12 RH 2102 3,3LD
. UT7T _
Piping Butt /Long. Welds'
- CF 1 C511,12 RH -
12 RH41031, ILU UT7T Piping Butt / tong. Welds CF1 C5.11 RH 12.RH 23121.
- tTT7T
. Piping Butt Weld -
- CF1
' C5.II,12 RH 12.RH4312 2,2LD UT7T Piping Buttions. Welds C-F1 C511 RH 8 RH 210613
. 'N CF1 C5.11 E RH 8-RH 21071
-UT7T-
- Pipi g Butt Weld.
['
iTT7T Piping But Weld
.Q_
C F-1
- C5.11 - RH
. 8 RH 23141
- UT7T L Piping Butt Weld 2Q' M -
A 0 + 2-11
?? l-
}g, jaf 2
ft
$-2841
3.0 STEAM GENERATOR TUBE EXAMINATIONS
\\g
')
3.1 Introduction This section of the summary report addresses the eddy current ISI of selected tubing in the four (4) steam generators conducted during the 1990 refueling outage of the South Texas Project Electric Generating Station, Unit 2 (?PE01). It is intended to respond to the reporting requirements of ASME Code Section XI, IWA 6000 and 4.4.5.5 (b) of the STPEGS Techrical Specification.
Each of the four (4) steam generators is a model E2 recirculating design generator, designed and fabricated by Westinghouse Electric Corporation of Tampa, Florida. Each generator contains 4851 tubes. The tubing is ASTM SB 163 Inconel material having a ncminal outer diameter (OD) of 0.75 inches and nominal wall thickness of 0.043 inches.
The examination agency for the 2RE01 eddy current examination of steam generator tubes was Babcock & Wilcox Nuclear Service Company (BWNS) who subcontracted the work to Conam Nuclear, Incorporated. They acquired the first eddy current data on October 27,1990. The last eddy current data analysis was performed on October 30,1990.
3.2 Scope of Examinations
(].
The STPEGS 2 Ten Year ISI Plan, previously filed with the NRC, describes the ISI k
program for examination of steam generator tubing. Additionally, a supplemental ISI plan (ISI Outage Plan) entitled," 1990 Outage Plan for the Inservice Inspection of Steam Generator Tubing at the South Texas Project Electric Generating Station, Unit 2" was prepared by Houston Lighting & Power Company (HL&P).
The ISI Outage Plan identified the steam generator tube areas expected to be examined and the eddy current examination procedures expected to be used during this iSI. Prior to the beginning of the ISI, tubes were selected in accordance with 4.4.5.2 of the STPEGS Technical Specification (NUREG - 1346) and assigned to the first (4%), second (8%), or third (16%) sampbs listed in the ISI Outage Plan.
Because the results of the initial examinations identified by the ISI Outage Plan could have identified a situation where additional examinations of other tube areas or the same tube areas (with different 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 Outage Plan Change Forms. Five (5) changes were made to the ISI Outage Plan during the outage. Each of the five (5) is included as Appendix 3-A. The ISI Outage Plan and plan changes are consistent with the requirements of the Ten Year ISI Plan.
OV 31
l
~
3.3 Personnel, Procedures, and Equipment O
3.3.1 Personnel Qualifications The Conam personnel who performed eddy current examinations and data analysis were certified in accordance with the requirements of IWA 2300 of ASME Code Section XI and a Conam certification practice approved by HlAP. In addition, all data analysts were required to have satisfactorily completed (1) specific training in eddy current data analysis and (2) site specific training. The site specific training lecture addressed the specific design and operating history, previous eddy current examination results, and the data acquisition procedure and analysis guideline to be used for the STPEGS Unit 1 and 2 steam generators. The site specific training also included hands on review or indications of flaw types which have been experienced at plants of similer 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 Conam personnel who performed examinations and data analysis and their certification levels are listed in Appendix 3 B.
3.3.2 Examination and Analysis Procedures For those eddy current examinations which respond to the requirements of the STPEGS Technical Specifications, Conam used the bobbin probe technique in their procedure entitled; "Multifrequency Eddy Current Procedure Westinghouse Model E2 Steam
/]
Generator Tubing MIZ-18 Digital Eddy Current System South Texas Project " (HIAP k
Document No. 400477 00037 A2U). This technique requires that the 550,400,100,and 10 kHz frequency differential and absolute coil data be recorded for each tube. The Conam bobbin probe procedure (400477-00037 A2U) is an ahernative to the technique described in ASME Code Section V, Article 8, I 42, which requires that the probe pull speed not exceed 14 inches per second. Instead, the procedure permits a maximum pull speed of 24 inches per second. At this pull speed the digital signal sampling rate must be raised from the typical 400 samples per second to 800 samples per second.
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.
The eddy current data analysts worked to HIAP Engineering Instruction EI-8.01," Steam Generator Eddy Current Data Analysis Guidelines", Revision 0 including the Analysis Guideline Exception Forms entitled " Update 2" and " Update 3" The data for each steam generator tube was analyzed by two (2) independent analysts in accordance with HIAP Engineering Instruction EI 8.02," Steam Generator Eddy Current Data Control", Revision i
1.
Every system calibration and calibration verification, along with the time and date of calibration, has been recorded on a uniquely numbered digital magnetic tape which is 3-2
stored as a record. The unique digital tape number is entered on the eddy current data sheet. The data sheets are also' stored as records. They make it.possible to locate the calibration data for each tube examination. The oscillographs (depictions of the MIZ-18 video display) for each flaw with a through wall dimension (TWD) greater than twenty (20) percent are included in Appendix 3 C, filed with the applicable system response curve.
The system response curves are graphs of calibration standard flaw depths versus the voltages of the corresponding indications.
3.3.3 Equipment Conam used MlZ-18 eddy current examination instruments to record the raw data and Eddy Net software to analyze the data. The MIZ 18 and Eddy Net, manufactured and produced by Zetec, Inc., are digital instruments and software which have a significantly improved dynamic range and signal to noise ratio as compared to analog systems. The MlZ-18 is capable of being operated at locations remote from the steam generators (e.g.,
in low radiation areas). Conam_ used 0.610 inch diameter magnetic biased bobbin coil probes. However, bobbin probes as small as 0.580 inch diameter were used in a few cases in order to pass the small radiused U bends in Rows 1 and 2. ASME Boiler and Pressure Vessel Code. Nuclear Components Code Case N-401," Eddy Current Examination
- Section XI, DMsion 1_", was used after the digital equipment and the eddy current 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 eddy current calibration standards _used were not subjected to that heat treatment. ASME Boller and Pressure Vessel Code, Nuclear Components Code Case N 402," Eddy Current Calibration Standard Material,Section XI, Division 1" was used after it was demonstrated-to the satisfaction of the ANII that calibration standards with and without this heat treatment result in equivalent examiaations. Otherwise, the design and material of the eddy current calibration standards used meet the requirements of the ASME Code Section XI.
33
~.
3.4 Summary of Examinations 4
3.4.1 Technical Specification Examination Examinations were conducted of 201 tubes in each steam generator, approximately four (4) percent of the total tubes installed. All of these tubes were examined over their full length (from tube end to tube end).- The tubes that constitute these groups of 201 tubes-consist of the first samples, defined in the ISI Outage Plan, with the following changes:-
Steam Row-Col. Row-Col. -
Reason Generator Removed-Added A
48 - 55 41 - 62 41 - 62 was erroneously entered on the list of tubes to examine instead of 48 - 55.
A 48 - 57 42-- 62 42 - 62 was erroneously entered on the list of tubes to examine instead
- of 48 - 57.
O B
6 - 60 6 --61 6 60 could not be reached without repositioning the manipulator. So,.
- the choice of 6 - 61 was ALARA.
C 2 - 48 2 - 45_ Manipuistor n in ' the. - other bowlI would; not permit - full length examination.
C 4 - 53
_4 Manipulator in __ the - _other ' bowl -
would not pennit full length examination.-
C 3 - 24 3 - 25 3 - 24 had been previously removed -
from service.
3-4
- )
4 Steam Row-Col. Row-Col.
Reason Generator Removed - Added C
12 - 80 46125 12 - 80 was examined part length, 46'- 25 was examined inadvertently, i
D-3 - 56 2 - 58 Manipulator in the other bowl j
would not permit full - length -
q
- examination.
These examinations constitute the portion of the tube examinations conducted which -
g" responds to the requirements of the Technical Specification.' The ' examinations of tubes listed in the second and third samples of the ISI Outage Plan were not performe6. _.
3.4.2-Augmenting Examinations-In addition to the tube eddy cununt examinations required by the Technical Specification,-
several tubes were examined for other reasons. The reason for performing tube testing not required by the Technical Specification was chiefly to investigate possible loose parts but also included inadvertent testing of tubes not listed in-the ISI Outage Plan and the inability to test the full length of a few tubes originally listed in the. plan. Tube areas 1
Os which were _ examined for reasons other than compliance with Technical Specifications -
comprise the augmented program, in some cases tubes 'or ' portions of tubes'in the-
- Technical Specification program were also included in the augmenting program / -The additional numbers of tubes which were examined over their entire lengths as part of the augmenting program only are as follows:
- Number Examints A
3-B 120 C-57 D
160
_l 3.
The augmeraing program facluded the following numbers of tubes which were examined over only a portion of the tube length:
{
Eteam Gggtgtat Number Examings -
A=
g' B:
1 j
C 22 D
40-3.5-Examination Results and Corrective Actions-No flaw indication was detected by the Technical Specification program with a depth equal to or greater than 40 percent of the nominal tube wall th!ckness. One indication of a tube flaw, which was greater than 20% of the nominal wall thickness and grew in depth by more than 10 percent of the thickness since the previous examination, was detected by thei Technical Specification program. This flaw, in Tube 46 - 59 of Steam Generator D, had a depth of 29% at the second antivibra' ion bar. Ws indication was reported on RFA.
No. 90-2116. Four (4) other tubes ccntain indications which were less than 20% in' depth.'
)
The magnetic tape data for the preservice eddy current examination of one of these tubes, No. 6 - 85 in Steam Generator B, was reviewed and revealed that the indication was not
}
service induced but existed prior to service. The Technical Specificction 4.4.5.4.a.3 says
'L that a degradad tube' means a tube containing imperfections greater than or equal to 20%
4 of the nominal wall thickness caused by a service-induced damage mechanism. Therefore, there were no defective tubes. and-one-(1) degraded tubo detected by; the Technical
_ Specification program.
No. corrective actions.were performed; because of any flaw,-
4 d:tected by the Technical Specification program, with a reduction of tube _ wall thickness.
No flaw indication was detected by the augmenting program with a depth equal _to-or greater than 20 percent of the nominal tube wall thickness.1No corrective actions:were performed because of any flaw, detected by the augmenting program, with n reduction of-tube wall thickness.-
..An roscillograph of the flaw indication detected with a depth greater than 20 percent of -
the nominal tube wall thickness is incleded in-Appendix 3 C.
The location of the indication was recorded relative.to the adjacent anti-vibration bar. The-tube support plates and baffle plates were numbered consecutively from' 01H to 10H (on the hot leg) and from 11C to 23C (on the cold leg) starting on the hot leg side, over the U bends, and J
down the cold leg side of the steam generator. The antivibration 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 to TEH or TSH (hot leg) or TEC or TSC 3-6 4
(cold leg) depending on whether the indications were at The tube end (d) u seccadary face (S), In addition, the vertical distances from these landmarks to flawwere recorded.
Lists, including the locations and depths, of all flaw indications which are character.ized as reductions in the iube wall thickness in tioth the Technical Specification and augmenting progrems are included in Appendix 3-D.
Lists of all dents and dings detect:d in each steam generator by both the Technfr,al Specification rmd augmenting programs are included in Appendix 3-E.
- A substantial effon was expcuted during the PSI to identify and disposition tubesheet expanslot? anotualles, So, as a general rule, eddy current data analysts were not required to report the occurrence of 11dications af anomalies in 1.ke tube hydraulic expnsions during the ISI. However, one (1) "BLG" mdications was r: ported one -(1) inch abnve the tubesheet on the hot leg end of tube 35-49 in Steam Oct.crator C.
A _"BLG" type indicaticn is a " Bulge". This condition was reported in tube 35 49 during the PSI.
The tubes whbh were removed from service i;y plugging prior to this ISI are as follows:
Steam Tube Steam Tube Generator
?mber Generator NumW
-A 3-20 B
3 20 21-20 21-20 31 20
'31-20 34-20 21 34 35-20 31.'4 21 34 3 40 31 34 3 60 3-40 3 81-3 61 21-87 e
i 9 66
'3137' 3 81 3-101 21 87 21-101 31-87 31 101 3-101 21-101 31 101 O
s-,
1
Steam Tube Steam Tube h
Generator Number Generato,.
Number C
3 20 D
3 20 21 20
? b20 31 20 31 20 31 21 48 27 3 24 J,1-34 21 39 31 34 31 34 3 43 3-@
3-60 y
40 4
??I 3-49 21-87 4-49 31-87 5-49 10
,)
3K 3 101 4 50 21 101 5-50 31-toi 3 61 3 81 21 87
=
31 87 3-101 21-101 31 101 No tubes were removed from service by plugging as a result of the eddy current ISI performed during this outage. No corrective actions were performed as a result of dings, dents, obstructions, or the "BLG" 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 Un9 2 ISI examinations described in this Summary Report. The STPEGS Unit 2 ISI examinations have been certified by our ANII, Factory Mutual Systems, on the NIS-1 form included in Appendix 3-F.
3-8 4
,n,,
_m
O APPENnIX 3-A CIIANGES TO TIIE ISI OlJI' AGE PIAN O
i 39
- 4,.
1./.f'..
f, '
- OUTAGE PLAN CilANGE FORM
' 's. : a,2, RESCRIPTION 0F CilANGE fADDITION OR DELETIONlt Add to the inillal scope of work the eddy current bobbin coll test of the r te areas defined on the attached pH so, y.g, s
pages. those paru were dhcovered in these areas during this outage, & M t:: 1;;'d h
': :f og 4e 4;.;, ';,;tter" : : ;:r-' t' H ? :! 1 M.; All of these areas should be tested during g,q,9" thh outage to determine if wear is present. For those paru which how not been removed, the acope of tute should te expanded if necessary to map the entire perimeter of the part and test the tubes adjacent i
to the part for wear. If otJecu which remain in the tube bundle are not located within the tearch area glven, additional tubes should be tested in en effort to locate the object. Include the hot leg side of tube 46 97 h st. gen. C Data for paru on the cold leg side should be analped in the area DC 15C Data for paru ori the bot leg side should be analped in the area 75H.0lH.
- EfdSON FOR Cl!ANGE:
To assist in the disposition of RF' 42015.
I IECilNICAL BASIS:
loose parts haw been known to cause tube wear.
D l O ECilEDULE lhlPAC[1 12 Crew Hours.
l l
AUTilORIZATIONS:
A tend Analyst:
U Date 4 % %
b * (h d
Date.,.jp 14-fc CTO Engineen e
\\.
3 10
y L n.[ + b..:
NN
~
s n.e
. )r *$,
~
M....
~
Supplerrental Eddy Current Testi.g i
STPEGS Unit 2 Steam DmrSciew Kea e4 Imemmise resinisa Eddy Car viet Isupanism d c-. : _
Steam GeneratwA Mae=wr IIeder wafne, 2 IW s 315/if s SW.
Ye R12.M O O M 12 A mad a, amnant R11. att ampurugt er J/J2" arparamassereder R72 Off RJJ, Ge9 AM Ce9 Coin g T-elet Manat Rm;~,41/2* s 15/If x WIC Tar Jt2741. OI PlmwEdsenhuume O2, JtN - J2 y
/.
Aime Wadar, saw med weedsd, Yer Asammans, OJ M A =senters met RM, CE2. dr (I) 2 IW s 2 314"s SW amps sur assuemig meer oIW (2) 2 Il37 s 215114* s 211J2" asusurungar 5132*
Scram Generator R Cdney MenalBar 211/14*s SW s Sil6*
Ya R42-M, Of FInvasalueenmana 09, Rn - M Ene Oddrg, adesmer Fed ( Red Ne Jt22-2J, C22-4 pnengst a sour Jt22, C22 4 Aime M CZ2.M Neder, adamese weifRed N.
R22-2J OK-47 rimeuser er somr Jt22, Cr7 47 Ene Jt2J, C27 47 4
m O
O
'n
- 1. ~
- .% A..
g-Supplemental Eddy Current Testig STPEGS Uidt 2 54 Dexripeise E W_
In huisine FJdy Cammt " _, ' T Ares Gomerske-Sreene C.
^ - C Maleg Menal Jted,4 Il37 s if To Teenamar, O T-40 PIweEnt er one R!, OS - 43 sur Neair 7)deleur O&ner Monat Jand,3 fir z !!!C Ter Ta6enmar.CWs0 H n row R1, OS - 42 nur Nacir adedner w
Coadhg T.eine Mennt Bar,4 IWz 1* x TilC Te Ammalm, Cid-57 Ammaha R4 C11 - 59 L
N M.est Jhr, 41/f 17W z i/f, Yer 4 nha, Cre-57 A maar curved Wadre 3 7W at 21137 s MEC Te hummha,07-N Ammaha, permEnt R4 CES - 71 separing er 3ri r er and &
l row see 1
Memway Aning Meant Jtent, 141311f x if Yer R" ' ' 03 Tangsat to R42, 0 02 M
primamar eder R43, OM R44, 09 R4*,CN Rai, C95 K M CPd HerIrg,h6anadir MeaalSehr Me Jt25-26, C75-E03 P\\n w Ent er se e R25, C75 - 103 sur xx C7s-Jes i
i
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4 Supplemental Eddy Current Testing
{
STPEGS Unit 2 1
l sseen W
u m,mt rm minien Euy car,,c, _ ^* ; A cowreser I
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"J ^ O j
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Fav,IN J/#*s I/fd' Te Ammmesq, CM349 rheuest am ses-Net,(X2-at sur
".884T siemmedir Sadee= Thder Me JtyyJR, CZ3 43 rmse sueur, JtJ7, CZF -4 p sea dar e ame JtM CE7-e Nede M 3 Finds JInd Me Jt27-JE, CME-F7 risued a w Jt:7, CMS - 77 a=r JtM CMS-77 1
4 czy-c i
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1 WN. TNT
OLTTAGE PIAN CilANCE M)RM
()
' !i % ".?
(.
5 e &. f.T,.'
DESCRIP170N OF CIIANGE (ADDITION OR DELETION):
j 1.
Add tube 3 25 to the first sample for Sicam Generator C j
2.
Add tubes 2 45 and 4.$$ to the first sample for Steam Generator C 3.
Add lobe 46 25 to the first sample of Sitam Generator C REASON FOR CilANGE:
L Tube 3 25 replaces 3 24 which had been previously removed from service, i
2.
Tubes 2 45 and 4 55 replace 2 48 and 4 53 which could not be fully examined beause of the 1
pcening firture installed in the hot leg.
3.
Tube 46 25 was erroneously examined.
I IECIINICAL B4filjj Track changes to the plan and data base management systems.
S.C.JJEDULE IMPALT:
Negilgible.
I AUTilOR17ATIONS:
M lead Analyst:
h #I.
CTO Engineer:
L #a:
Date /o"M-fd 4um Date le-29-fa 3-14
_7
~ '
OUTAGE PIAN CilANGE K)RM
- svbc..
,,. ].
d.' '
h.,
f
.y.w-pflCRIPTION OF CilANGE fADDITION OR DELETIONh 1.
Add bobbin coil examination for loow parts and wear at the hot and cold leg tubesheet face in Row 21, Columns 1719,2133, snd 35 47 and Row 24, Columr417 47.
2.
Perform a full length bobbin coil examination oi 6-61 Instead of 6-60.
i REASON FOR CIIANGE:
1.
To assist in the disposition of RFA 90-2015, 2.
6 60 can not be reasonable reached without significant repositioning of the SM.10. Since 6 61 is as sufficiently simikt to 6 60, this substituilon acceptable and helps msintain radialion dosages ALARA.
TECIINICAL BASIS:
(
).
$1nce the locations of these '.ose parts were not known precisely and the initial test did not see the parts, expanding the sample will help assure that the tube adjacent to the parts are tested for Star.
2.
640 was originally selected beause of the sort radius U bend. 641 is similar.
O_
SQ]EDULE IhlPACT:
1, 2 to 4 crew houts.
2.
Negligible.
AUTilOR17ATIONS:
.O lead Analyst
~M Dale /# *M 4 CI'O Engineen M 2dn.u, Dale /A..lff 74
()
0 3 -
~.... - - - -
- - -. ~.....
OUTAGE PIAN CIIANCE FORM f
. ~.a. ( *:.
~
DESCRIPTION OF CilANGE fADDITION OR DELETIONh 1.
Add tubes 4162 and 42 62 to the first sample for Steam Generator A 2.
Remove tute 4833 and 48 57 from the first sample for $1 cam Oenersiot A
\\
)
RFASON FOR CilANGE:
Conam erroneously entered 4162 and 42 62 Into their database scope instead of 48 $$ and 48 57.
IECilNICAL 11 ASIS:
e Track changes to the plan and data base management splems.
l
{
O SCllEDtlLE IMPAcri Negligibic.
AUTilORIZATIONS:
lead Analysts _ CfM //e/ /d Am Dale /A d-to CI'O Engineer [y o
i 4bWho#
i Dale //. 5-fa l
i O
3*
i
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_. _.. ~.__._._
e OUTAGE PIAN CllA.NGE FORM -
{
Change No. 5
(.
i
[ESCRIPTION OF CllANGE (A11111110N OR DELETIONh 1.
Add tube 2 58 to the first scope of Steam Ocnerator D.
2.
Add bobbin coil examination of the full length of tubes 26 76 thru 97 and 29 76 thru 97 to the 6 cope of Steam Generator D.
1 t
i
)
1 l
REASON FOR CllANGEr 1.
- Ihis tube is added to compensate for the fact that tube 3.M could not be examint : ever its full length because of the peening fixture Installed in the hot leg.
2.
These tubes were added to expand the area in which to nearch for a loose part which was left in Steam Generator D and the possible wear it may have caused.
IJ:CilNICAldlAS111 1.
2 58 is a reasonable substitute in the sample for 3.M.
2.
$1nce the locailons of these loose parts were not known precisely and the initial test did not see the parts, expanding the sample will help assure that the tube adjacent to the parts are tested for
~'
O SCllEDUI,E IMPACT:
1.
Negilgible.
2.
2 to 4 trew hours.
AUTilOR17ATIONS:
- lend Annipli _ &dM /u >/244h Date. //- t f a CI'O Engineer [/ %Wein.
Date - N-F-fo -
0 0
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O APPENDIX 3 D LIST OF EXAMINATION AND DATA ANALYSIS PERSONNEL O
3 18
l APPENDIX 3 B LIST OF EXAMINATION AND DATA ANALYSIS PERSONNEL 1
i l
l l
l l
l NAME IRVEL Donovan, G.
IIB Ferguson,B.
IIA Funanich, J.
III Hayes, M.
None (Data Manager)
Janet,J.
IIA Jones, B.
IIA Kencipp, M.
IIA O.
Marlow, B.
IIB Miranda, E.
IIB Pire,J.
I (Data Manager)
Webb, R.
IIA Wright, K. C.
IIA 3 19 I
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APPENDIX 3-C OSCILLOGRAPHS AND SYSTEM RESPONSE CURVES FOR FLAWS GREATER THAN 20 PERN O
32o O
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APPENDIX 3 D I4AWS WITH TUBE WAIL TIIICKNESS REDUCTION 3 23
APPENDIX 3 D l
O FLAWS WITII TUBE WAIL TIIICKNESS REDUCI' ION 1
l i
i Steam Row.
Percent Indication -
Reel Generator Column Depth location Number A
44 62-15 AV2 + 0.0 003 A
44-62 15 AV3 + 0.03 003-A
-44 62 11 AV4 + 0.0 003 A
46-62 8
AV4 + 0,0 003 B
G85 13 07H + 21.2 003 D
45 59 13 AV2 + 0.0 002 Os D
45 59 13 AV4 + 0.0 002 D
46 59 29 AV2 + 0,0 002 D
46-59 11 AV4 + 0.0 002 d
i O
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I APPENDIX 3-E DINGS AND DENTS i
i I
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I T
t APPENDIX S E DINGS AND DENTE t
e Steam Row.
Indication Generator Column Location A
8 42 09H + 41,45 A
35 69 12C + 29.26 -
4 2
A 35 69 12C + 20.45 A
6 114 08H + 12.68 B
48 - 94 11C + 0.39 -
O D
6 10 16C + 3.67 D
5 34 11C + 0,40 -
O o
,.26
)
J-
O APPENDIX 3-F OWNER'S REPORT FOR INSERVICE INSPECTIONS NIS-1 FORM 3 27-
1590151 2RE01. Stean Ocnerator hbes Page 1 of 2 f
FORM NIS 1 OWNER'S REPORT POR INSERVKE INSPECI10NS As required by the Prmisloes of the ASME Code Rules 7
3 l'
- 1. Owner Houston Lichtint & Power Company. Electric Towr: P.O. Inox 170&. Houston. Texas 77001 (Name and Address of Owner)
- 2. Plant South Texas Protect Electric Ocneratina Station: P.O. Box 287. Wadsworth. Texas 77483 (Name and Addrus of Plant)
- 3. Plant Unit,_2,
- 4. Owner and Certificate of Authorization (if required) NA
- 5. Commercial Service Date Qlil19189_6. National Board Number for Unit NA
- 7. Components inspected ASMB Code Qass 1 (!WB) Items. Steam Generator hbes Manufacturet Component or Manufacture or Installer National Appurtenance or Installe Serial No.
Board No.
\\
l
~
Steam
_O.tRClator 2A Westinghome (M) 2151 29 Steam
_QtacIntor 2R Westingh0ne (M) 2152 30 Steam
_QtatIAlDr 2C Westinghousg,4M) 2153 31
(
Steam Generator 2D WestlDgh0MtJM) 2154 32 5
i tM s
Note: Supplemental sheets in form of lists, sketches, or drawings may be used, provided (1) size is 8% in.
O x 11 in.,(2) Information in items 1 through 6 on this report is included on each sheet, and (3) each sheet Q
is numbered and the number of sheets is recorded at the top of each form.
3 28 =
1 a
19901S1 2RE01. Stean Generator hbes Page 2 of 2 PORM NAS 1 (Beet)
- 8. Examination Dates 10/27/90 - to _1GGa90 _9. Inspection Interval from ;06/19189 to 06/1999-
- 30. At* tract of'Etaminations. Include a list of examinations and a statement concerning status of work required for current interval. (ASME Code Oass 1 (IWD) Items. Steam Generator %bes)
Soc Section 3.4.1 of the 1RE01 Summa:y Report.
- 11. Atstract of Conditions Noted.
See Section 3.5 of the 2RE01 Summary Report.
- 12. Abstract of Correcthe Measures Recommended and Taken.
Soc Section 3.5 of the 2RE01 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.
4 Certificate of Authorization No.(if applicable)
N.A.
Expiration Date N. A.
Signed _ Houston Lichtint & Power Co. Dyh[K Date E66. To 1991 m/m owner CERTIFICATE OF INSERVICE INSPECI10N O
1, the undersigned, holding a valid commission issued by the National Board of Beller and Pressure Vest.cl Inspectors and the State or Province of *[t3n and employed by Arkwricht Mutual Insurance Co.
of Norwood&ig, have inspected the components described in this Owner's Report during the period 3
/o-/ fo to !-Jo-91
. and state that to the best of my knowle4ge and belief, the Owner has performed examinations and taken correcthc ineasures 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 impiled, concerning the examinations and corrective measures described in this Owner's Report.
Furthermore, neither the Inspector not his employer shall be liable in any manner for any personal injury or property d age or a loss of any kind arising from or connecte4 with this inspection.
Factory Mutual System Commissions Tex 826 Inspector's Signature National Board, State, Province, and Endorsements E. R. Russell Date J ;2g-19 ff,,,,
3 29
,wp,,,,--.----yr er - -
--r y
,w_re-v,-,,.y--
.7e, y
4.0 COMPONENT SUPPORT EXAMINATIONS 4.1 Introduction ISI of Class 1,2, and 3 component supports and Class 3 integral attachments of STPEGS.
2 was performed between September 17 and December 5,1990. These examinations constitute the first ISI of the first inspection intenal for the Component Supports Examination Program for STPEGS 2.
This Section of the Summary Report documents the examinations of component supports perfr*med by HL&P OC NDE Personnel in accordance with the following documents:
(1)
HL&P Specification SUO36JS004," Inservice Inspection Examination of Component Supports of South Texas Pry.ct Electric Generating Unit 2 First inspection Interval",
(2)
" Examination Plan for the 1990 2RE01 Inservice Inspection at the South Texas Project Electric Generating Station, Unit 2" including changes made during the outage (Outage Plan).
The HL&P Specification provides a detailed description of the rules for exemption and selection of Class 1,2, and 3 component supports for ISI. The 1990 Examination Plan is n
an individual Outage Plan for implementing ISI component support examinations as V
designated in the HL&P Specification.
4.2 Scope of Examinations A total of ninety nine (99) component supports were visually examined. These supports, selected from the Component Supports ISI Examination Plan (SUO36JS0004), constitute approximately sixteen (16) percent of the total piping and equipment supports required to be examined during the first inspection interval.
gass 1 Twelve (12) Class 1 piping supports and one (1) Class 1 equipment support were examined in the following systems:
Pipinc Equipment Chemical & Volume Control (CV) 2 0
Reactor Coolant (RC) 8 1
Residual Heat Removal (RH) 2 0
41
i
+
1 i
Class 2
- O rhirtv six <>e) Ciass 2 vivieS surger 1s end seven (7) Ciess 2 esuirment serPerts were i
examined in the following systems:
Piplug Equipment Auxillary Feedwater (AF) 2 0
1 Chemical & Volume Control (CV) 0 7
i Containment Spray (CS) 2 0
j Main Steam (MS) 5 0
g l
Residual Heat Removal (RH) 7 0
j l
Safety Injection (SI) 18 0
3 I
Class 3 Thirty seven (3") Class 3 piping supports and six (6) Class 3 equipment support werc-
{
examined in the following systema:
Piping Equipment j
Auxiliary Feedwater (AF) 7 0
l Chemical & Volume Control (CV) 0 4
l Component Cooling (CC) 23 0
i Diesel Generator Starting Air (SD) 0 1
)
Diesel Genetutor Jacket Water (JW) 0 1
l Essential Cooling Water (EW) 6 0
j Reactor Make-Up (RM) 1 0
A complete list of component supports examined during IRE 02 is contained in Appendix 4 A.
4.3 Personnel and Procedures 4.3.1 Personnel Qualifications i
Component supports were visually examined (VT 3 and VT 4) by HL&P QC NDE l
- personnel certified in accordance with ASME Section XI (IWA.2300) and HL&P Nondestructive Examination Procedure NDEP 1.0, " Qualification and Certification for Examination Personnel"._ A listing of the personnel who performed visual examinations of j
component supports, including their. certification level, is included in Appendix 4 B.
i 4.3.2 Examination Procedure Visual (VT 3 and VT-4) examinations of component supports were performed in j
accordance with NDEP 9.2, " Visual Examination of Component Supports for ASME XI Inservice Inspection".
O l
42 4
?
i 4.4 Summary of Examinations
! O 1
4.4.1 piping and Equipment Supports I
Eighty five (85) piping supports and fourteen (14) equipment supports were examined just prior to and during 2RE01 as shown in Appendix 4 A.
j I
4.4.2 Additional and Successive Examinations -
The results of the visual examinations of component supports performed during 2RE01 did not require that any additional examinations (IWF 2430) be performed or any succe:sive-j examinations (IWF 2420) be scheduled.
4.5 Examination Results s,nd Corrective Actions One (1) Cass 1 and two (2) Cass 2 spring hanger pipe supports were found with the spring hanger setting out of tolerance in the cold load condition. One Class 3 rigid restraint pipe support wat found with she sway strut bent approximately 1/8 inch over Its length.- RFA's were issued for these conditions as noted in Table 4-1 below.
Cass 1 support RH 2201 HL5009 and Cass 2 support RH 2204 HL5003_ (spring hanger settings) were evaluated to the spring hanger cold load. settings after the hot functional test O
n(HFT) and found to be within _ tolerance. Therefore, these supports were d ot be in a nonconforming condition. No' corrective action was taken or recommended for these supports. Class 2 pipe support SI 2106 SH10 (spring' hanger setting) was analyzed to substantiate its integrity for its intended service and found to be acceptable. However, it was recommended that the spring hanger for SI 2106 SH10 be reset to its design cold load setting and WR SI 118268 was issued to for this task.. This work request was'not completed during 2RE01 due to the low priority established for this task. Class 3 pipe support CC 2116 HL5006 (bent sway strut) was analyzed to substantiate its integrity for its intended service and found to be acceptable. No corrective action was taken or recommended for this support.
t h
O 43
. ~ :.
.,. a. -. ~.
,.. i.-. ; ~ a, a -
e.
e-.
W i
Table 4 !
Summary of Component Support Visual Indication Disposition Component ID Condition RFA Ng Disposition WR No, RH 2201 HL5009 Spring Hanger 90 2375 Invalidated RFA N/A setting out of, tolerance RH 2204 HL5003 Spring Hanger 90 2376 Invalidated RFA N/A setting out of tolerance i
SI 2106 SH10 Spring Hanger 90-1776 Accept as is SI 118268 setting out of until rework tolerance completed CC 2116 HL5006 Sway strut 90-1834 Accept as is N/A slightly bent O
4.6 Certification of InspectionsSection XI NIS 1 forms, " Owner's Report for Inservice Inspections",- have been prepared to 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 Systems, on the NIS 1 forms included in Appendix 4-C, O
44
l O
APPENDIX 4-A
SUMMARY
OF EXAMINATIONS O
(~T U
4-5 1
4
.m
DAfr, A r23/91 SOUTH f tXAB PROJECT ELECTRIC CNERAllNG stAf!N UNIT 2 PAGE:
1 Af,Villim 0
IN$ttylCC INsPECfl0N PLAN Fiktf INftRVAL, fitti Pitl00, vlR$f OUTA04 (1990)
CLAlf 1 SCHEDULED copCwtNf8 ICM t.VDLUMt..CMTRQL N
o ASME O 8 f SEC. XI g g y E M MRY EXAMINAtlDN # tA CM0Y EXAM t 0 t tim 4RKS NUMBit IDENTIFICAtl0N litM NO 41H00 PROCEDURE C M D **CAUBRAfl0N BLOCK" 3
f CV 2121 asi.A1A1 000100 CV 2121 Ms5001 PIPING VT.3 N0tr 9.2 30 g
1 GUIDE 000200 CV'2121*Nt5002 PIPING VT 3 NDEP 9.t R0 X
yg.4 g
$N*V
~O
.V i
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-- 4 6 -
a, DATE: 02/23/91 SOUTH.tXA5 PROJECT ELECTRIC GENERAfl%0 $1dfl0N UNif 2 PAfet t 2
RtrM4Mt 0
-lN$tRVICE INSPECTION PLAN f
FIR $f INTERVAL, FIR $f PERIOD, Flktf OUTAGE (1990)
OitACTOPCOOLANT class 1 SCNEDutto CCW0ktNTS i
i A N!
O G f i
SEC. XI R t M SU9%RT EXAMINA110N AktA CAf0T EK4M 200 REMARES NUMRER IDENflFICAfl0N litM NO MtfMOD PROCtDUitt CM R 5+CAllDRAtl0R BLOCK
4..........
Ac1001RR,t.g 000300 RC.2003*HL5001 PIPING V43 NDEP 9.2 R0 x..
RR i
RC 2123 31hh 000400 RC 2123 ML5010 PIPING VT.)
Nbtp 9.2 R0 K
RR j
l 000500 RC 2123+HL5011 PIPlNG Vf*3 NDEP 9.2 R0 x..
/*
t
\\
000600 RC 2123' L5012 PIPINC VT*3 NDEP 9.2 R0 x.
RR Rt 2125 tai A 3
000700 tt.2125 ML5009 PIPING VT*3 O tP 9.2 R0 x.
VT.4 x..
SM*V 000800 RC.2125aHL5010 PIPING VT.3 NDEP 9.2 R0 x..
GulDE s
RC.2126-R_R1;g l
000900 RC 2126 sH01 PIPING VT.3 sedP 9.2 Rb x..
VT 4 K..
SM V I
1 i
O L
47 L
l l
DATE: 02/23/91 SOUTN TEXAS PROJECT ElfCTRI' 7
- RATING $f Afl0N UWlf 2 PACE:
3 REVill0N 0
INSERVICE INSPECTION PLAN fikST INTERVAL, flRST PEkl00, FIRST DUTACI (1990)
CLASS i SCHEDULED COMPONENTS CTOR C00tAWT tA N
O ASME O O T SEC. XI R E N
SUMMARY
EXAMlWATION AREA CATGY EXAM E O E RrMAtXS WUMBER IDENTIFICATION ITEM NO METN00 PROCEDURE C M k " CAL I BR* TION - r *.**
Rt.2412.pt}
001000 RC.24WitL5004 P1 PING VT.3 NDEP 9.2 R0 X
RR O
ou 48
--.. ~. - -.. -
. =.
- ~. -
DATE: 02/23/91.
SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
4 F0VISIONJ 0
INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST CUTAGE (1990) eESIDUA'NEATREMOVAL CLASS i SCHEDULED COMPONENTS N
O j
ASME O G T-SfC. XI R E N
SUMMARY
EXAMINATION ARIA CATGY EXAM E O E REMARKS-NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R
- CALIBRAfl0N BLOCK" l
RH.2201.BBPi 001100 RN.2201.HL5002 PlPING VT.3 NDEP 9.2 R0 X
3R M 's.BB1 L THE AS40UND COLD LOAD SETTING EXCEEDED 001200 RN*2201.tlL5000 PIPING VT 3
.NDEP 9.2 R0 X
~ DESIGN DRAWING TOLERANCES. RFA 90 2375 VT.4 X
SN.V WAS ISSUED AND DISP 0$lil0NED AS ACCEPTABLE WHEN COMPARED WITH THE SETTINGS FOUNL AFTER THE HOT FUNCTIONAL TEST (NFT). THE.'tFORE,. A NONCONFORNING CONDITION DOES NOT ?XIST.
3 t
{
v 49 4
l l
DATE 02/23/91 SOUTH TEKAS PROJECT ELECTRIC OENERATING STAfl0N UNif 2 -
PAGE:
5 REVISION:
0 int!RYlCE INSPECTION PLAN FIRST INTERVAL, FIRST *tRIOD, FIRST OUTAGE (1990)
&*EQUIPMENTSUPPORTS CLASS 1 BC6.4DULED COMPONENTS N
O ASME O G f SEC. XI R E N
SUMMARY
EKAMINATION AREA CATGY EKAM E O E REMARKS NUMBER IDENTIFICAfl0N ITEM NO METHOD PROCEDURE' C M-R
- CALIBRAfl0N BLOCK **
1Ri12NP21Lif
~
DC1300 PRS 1 EQUIP VT*3
. NDEP 9.2 R0 X
PRESSURIZER.* SINGLE SASE SUPPORT.
RC PRES SASE
=
4 10
_._._.____._.._._m___
DATE:-02/23/91 SOUTH TEMAS PROJECT ELECTRIC CNERATING STAfl0N UNIT 2 PAGE:
6 RfVl810N 0
INSERVICE INSPECTION PLAN.
FIRST INTERVAL, FIRST PERIOD, FIRST GUTAGE (1990)
CLAS$ 2 SCHEDULED COMPONENTS N
O AlfE O O 1 SEC. XI R E N
SUMMARY
EKAMINAft0N AREA CATGY
- EXAP, E O E REMARKS NUMBER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R - **CALIBRAfl0N BLOCK +*
AF 2012*CA2 C 001400 AFa2012*HL5007 PIPING VT 3 NDEP 9.2 R0 X
RR AF 2012*CA2*H 001500 AF 2012*NL5009 PIPING VT*3 NDEP 9.2 R0 X
RR O
4-11
DATE: 02/23/91
$0UTH TEKA1 PROJECT ELECTRIC GENERATING STAfl0N UNIT 2 PAGE:
)
REYl810N 0
INSERvlCE INSPECTION PLAN FIRST INTERVAL, FIR $T PERIOD, FIRST CUTAGE (1990)
CLASS 2 SCHEDULfD COMPONENTS TAINMENT SPPAY N
0 ASME O C T SEC. XI R E N
SUMMARY
EXAMINATION AREA CATCY EXAM E O E REMARKS WUMBER IDENTIFICAfl0N ITEM NO METHOD PROCEDURE C M R **CALIBRAfl0N BLOCK'*
CS 2203 PB2*C 0017tM CS 2203*HL5005 PIPING VT 3 NDEP 9.2 R0 X
RR CS 2301 UB2 A 001800 Cs.2301 HL5003 PIPING VT 3 NDEP 9.2 R0 X
RR 4-12
DATE: 02/Z3/91 SOUTH TEXA8 PROJECT ELECTRIC GENERATING STAfl0N UNIT 2-PAGEt 8
REVISION:
D INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST CUTAGE (1990)
CLASS 2 SCHEDULED COMPONENTS N
O l
ASME O G T SEC. XI R
E. M EMMARY EX4MINATIDW AREA CATGY EXAM E O E REMARKS E MBER JDENTIFICAfl0N ITEM NO METHOD F:10CEDURE C-M R **CAllSRAfl0N SLOCK**
FW 2016 GA2 P 001900 FW 2016 ML5013 PIPING VT 3 NDEP 9.2 R0 X
SM V (2)
VT 4.
X FW 2031*AA2 D 002000 FW 2031 ML5001 PIPING
\\. ?
NDEP 9.2 R0 X
SH V (2)
VT*4 X
OG O
4 13 l
0
I DATE: 02/23/91 SOUTH TEKAS PROJECT ELECTRIC GENERATING $1Afl0N UNIT 2 P,tCE:
9
)
REYill0W:
0 INSEkVICE INSPECTION PLAN FIRST INTERVAL, FIR $1 PERIOD, FIRST CUTAGE (1990)
CLA$$ 2 SCHEDULED Cor.*0NENTS
. IN STEAM N
0 ASME O G T SEC. XI R E N
SUMMARY
EXAMINAfl0N AREA CATGY EKAM E D E REMARKS WUMBER IDENTiflCATION ITEM NO MTN00 PROCEDURE CN R
- CALIBRAfl0W BLOCK **
MS 2001 GA2 D 002100 MS 2001 ML5001 PIPING VT 3 WDEP 9.2 R0 X.
RR 002200 MS 2001 HL5002 PIPING VT.3 WDEP 9.2 R0 X
RR MS 2002 GA2 D 002300 MS 2002 ML5002 PIPING VT 3 NDEP 9.2 R0 X
=
t(2 MS 2003 GA2 J 002100 MS 2003*HL5018 PIPING VT 3 NDEP 9.2 R0 X
VT 4 X
SH.V (2)-
002500 M$*2003 ML5019 PIPING -VT 3 WDEP 9.2 R0 X
VT 4 -
X SM*V (2) v4 4-14 p--
r e
g, w
1-u*+
,:1 ef v-M U-i*&
G
l DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC GEWERATlWG STAfl0N UNIT 2 PAGE:
10 REVIS10N:
0 INSERVICE INEPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST CUTT.GE (1990) eESIDUAL MEAT REMOVAL CLASS 2 SCHEDVLED COMPONENTS N
O ASME O G T SEC. XI R E N St.setART EXAMINATION AREA CATGT EXAM E O E REMARKS WUMBER IDEWilflCAfl0N ITEM NO METHOD PROCEDURE C M R
- CAllBRATION BLOCK **
i RM 2103*KB2 ta 002600 RM 2103 NL5001 PIPING VT*3 NDEP 9.2 R0 X
RR 002700 RH 2103 RR06 PIPING VT.3 WDEP 9.2 R0 X
GUIDE RH 7103 KB24 002800 RM 2103 RR04 P! PING VT 3 WDEP 9.2 R0 X
+.
RR eD V
RH 2204-KB2 A 002900 RH+2204 ML5005 PIPING VT 3 NDEP 9.2 R0 X
THE AS*FOUND COLD LOAD SETTING EXCEEDED SH V VT 4 y
DESIGN DRAWING TOLERANCES RFA 90 2376 WAS ISSUED AND DISPOSITIONED AS ACCEPTABLE WHEN CCMPARED WITH THE SETTINGS FOUND AFTER THE HOT FUNCTIONAL TEST (HFT). THEREFORE, A NONCONFORMING CONDITION DOES NOT EXIST.
003000 RH 2204 RR02 P! PING VT.3 NDEP 9.2 R0 X
RR 003100 RH 2204 RR03 PIPlWG VT 3 NDEP 9.2 R0
-X RR RH 2204 KB2 C RM 2204 HL5012 PIPING VT 3 NDEP 9.2 R0 X
GUIDE 4 15 i
-)
DATE: 02/23/91 SCUTN TEKAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
11
)
REVIS10W:
0 INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FI AST OUTAGE (1990) eMITYINJG,1gg CLASS 2 SCHEDULED COMPONENTS N
0 ASME D G T SEC. K1 R E N
SUMMARY
EXAMINATION AREA CATGY EXAM E O E REMARKS NUMBER 3DENTIFICAfl0N ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCK'*
81 2101 UB2 AF 003300 St.2101.SN11 PIPING VT.3 NDEP 9.2 R0 X
VT.4 X
SM.V 81 2101.U82 L 003400 St.2101 RH07 PIPING VT-3
'NDEP 9.2 R0 X
RR St.2101-UB2 M1 St.2101=HL5023 PIPING VT 3 NDEP 9.2 RD X
803500 GUIDE SI 2101 U82 Y 003600 $1 2101.RR23 PIPING VT 3 NDEP 9.2 R0 X
RR 003700 St.2101.RR24-PIPING VT 3 NDEP 9.2 RO X
RR 003800 $1 2101*SM13 PIPING VT.3 WDEP 9.2 R0 X
GUIDE 81 2106 082 B 003900 $1 2106 RR12 P! PING VT 3
- DEP 9.2 R0 X
RR OU 4-16
l DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTalt GE~~ RATING STATION UNif 2 PAGE:
12 REVis10N:
0 INSERVICZ IWtPECil0N PLAN FIRST INTERVAL, FIRST PERIOD, FIRST OUTAGE (1990) eAFETY INJECTION CLASS 2 SCHEDULED COMPONENTS N
O ASME O G T SEC. XI R E H
SUMMARY
EXAMINATION AREA CATGY EXAM E 0 E REMARKS NUMBER IDENTIFICAfl0W ITEM No METHOD PROCEDURE C M R
- CALIBRAfl0N BLOCK'*
l ti.2106 DB2 3 004000 $1 2106 SH10 PIPlWG VT 3 NDEP 9.2 R0 X
THE AS.FOUND COLD LOAD SETTING EXCEEDED VT*4 X DESIGN DRAWING TOLERANCES. RFA 9C.1776 SH*V WAS ISSUED AND THE SUPPORT WAS ANALYZED TO SUBSTANTIATE ITS INTEGRITT FOR ITS INTENDED SERVICE. THE SUPPORT WAS FUUND ACCEPTABLE, ALTHOUGH, SPRING RESET WAS RECOMMENDED.
El 2106 DB2 t
\\
004100 SI 2106 RH08 P! PING VT*3 NDEP 9.2 R0 X.-.
at 200 $12106 RR09 P! PING VT.3 NOCP 9.2 R0 X
AR 51 2106 DB2 K 004300 $1 2106 GU70 PIPING VT 3 NDEP 9.2 R0 X
CulDE 004400 31 2106 ML5012 PIPlWG VT 3 WDEP 0.2 R0 X
GUIDE St.2106-DB2 N 004500 St.2106 RR56 PIPING VT.3 NDEP 9.2 R0 X
RR O
i i
v 4-17
DATE: 02/23/91 SOUTH TEKAS PROJECT ELECTRIC GENERATING STAfl0N UNIT 2 PAGEt 13 REVISION:
0 INSERVICE INSPECil0N PLAN FIRST INTERVAL, FIRST PERIOD, FIRST GUTAGE (1990)
CLASS 2 $CHEDULED COMPONENTS FtfY INJft M N
0 A$st 0 G T SEC. XI R E N RMMART EKAMINATION AREA CATCY EKAM E O E REMARKS NUMBER IDENTIFICATION ITEM No METHOD PROCEDURE C M R ** Call 8AAT10N BLOCK **
Bl.2106 DB2 N 004600 $1 2106 RR58 PIPING VT.3 NDEP 9.2 R0 X
RR St.2106 DR2 P 004700 St.2106.RR54 PIPING VT.3 WDEP 9.2 R0 X
RR 004800 81 2106=RR55 PlPING VT.3 NDEP 9.2 RO X
RR 0
004900 $1 2106 RR59 PIPING VT.3 NDEP 9.2 R0 X
RR SI 2106 DR2 T 005000 St.2106 RR57 PIPING VT.3 NDEP 9.2 R0 X
RR 4-18
DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC GENERATING STAfl0N UNIT 2 PAGE:
14 CIVltl0N:
0 INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST _0UTAGE (1990)
&
- EQU1PMENT SUPPORTS CLASS 2 SCHEDlf.ED COMPONENTS N
0 ASME D G T SEC. XI R E N SumARY EXAMINAfl0N AREA CATGY EXAM E O E REMARKS-WUMSER IDENTIFICATION ITEM NO METHOD PROCEDURE C M R **CAllSRAfl0N SLOCK'*
2R172NMX201A 005100 RRX1 EQUIP VT 3 NDEP 9.2 RD X
REGENERATIVE HEAT EXCHANGER SUPPORT 15 LOCATED NEAREST TO SHELL INLET AND CV REGEN NXT OUTLET CONNECTION.
005200 RMX2 EQUlP VT*3 NDEP 9.2 R0 X
REGENERATIVE HEAT EXCHANGER. SUPPORT IS ADJACENT TO SUPPORT RHX1.
CV REGEN NXT
'e c
005300 RHX3 EQU1P VT 3 NCEP 9.2 R0 X
-REGENERATIVE HEAT. EXCHANGER SUPPORT 18 CV REGEN HXT ADJACENT TO SUPPORT-RHX2.
SR172NHX202A a
005400 LDHX1 EQUIP VT 3 NDEP 9.2 R0 X
LETDOW HEAT EXCHAGER. FIXED SUPPORT, CV LTDWN HTX
{
005500 LDNX2 EQUIP VT.3 WDEP 9.2 R0-X LETDOW HEAT EXCHANGER SLOf TED CV LTDW HTX SUPPORT.
E NHX2Q3A 00A00 EXHX1 EQUIP VT 3 NDEP 9.2 R0 X
EXCESS LETDOWN HEAT EXCHAWGER - FIXED CV EXDW HTX SUPPORT.
005700 EXHX2 EQUIP VT 3 NDEP 9.2 R0 X
EXCESS LETDOWN HEAT EXCHANGER. SLOTTED CV EXDW NTX SUPPORT.
U 4-19
DATE: 02/23/91 SOUTM TEXAS PROJECT ELECTRIC GENERATING STAfl0N UNIT 2 PAGE:
15 REVl510Na' 0
INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERICD, FlkST CUTAGE (1990) i CLAS$ 3 SCHEDULED COMPONENTS AUX 1LIART FEEDWATER N
0 ASME 0 G T-j.
SEC. XI R E N
SUMMARY
EXAMINAtl0N AREA CATGY EXAM E0 E RF. MARKS -
WUMBER IDENTIFICAtl0N ITEM NO METHOD PROCEDURE C M R **CAllBRATION BLOCK **
AF 2047 GA3 E -
4 005800 AF 2047+ML5002 P!PlWG VT 3 NDEP 9.2 R0 X
QUIDE
-i 005900 A7 2047 HL5003 PIPING VT 3 WDEP 9.2 R0 X i-
^
GulDE AF 2047.GA3 P 006000 AF 2047 HL5001 PIPlhG W3 NDEP 9.2 R0 X
GUIDE AF 2079 WB3 F 006100 AF 2079 ML5003 PIPING-VT 3 NDEP 9.2 R0-X GUIDE AF 20 N WB3 0 006200 AF 2079 ML5004 PIPING VT 3 hDEP 9.2 R0 X
GUIDE AF 2079 WB3 H 006300 AF 2079*HL5005 PIPING VT 3 NDEP 9.2 R0 X
GUIDE 006400 AF 2079 ML5006 PIPING VT 3 NDEP 9.2 R0 X
GUIDE
[
4-20 1
________m_-____
DATE: 02/23/91 SOUTH' TEXAS PROJECT ELECTRIC QENERATING STAfl0N UNIT 2 PAGE:
16 REVIS10N 0
INSERVICE INSPECTION PLAN-FIRST INTERVAL, FIRST PERIOD, FIRST GUTAGE (1990)
CLASS 3 SCHEDULED COMPONENTS N
O ASIE 0 0 i SEC. XI R E N SupMARY EXAMINAT10el ARSA Ct.TGY ERAM E O E-REMARKS IRMRER 10EATIFICAT10N ITEM NO ME!l4D PROCEDURE C H R **CAllDRAfl0N BLOCK **
gfdt)13 WA3 u
(
0065(t CC 2115 RR25 PIPING Vf*3 NDEP 9.2 no X
RR E
006600 CC.2115 RR26 PIPlWG VT.3 NDEP 9.2 R0 X
RR et 2115 WA3 P 006700 CC 2115+RR23 PIPING VT 3 NDEP 9.2 RD X
RR v
006400 CC 2115 RR24 PIPING VT 3 NDEP 9.2 R0 X
kR CC 2116*WA3 DA 006900 CC 2116 HL5005 PIPING VT.3 NDEP 9.2 R0 X.~.
RR 007000 CC 2116 HL5006 PIP!NG VT 3-NDEP 9.2 R0 X RIGID RESTRAINT SWAY STRUT HAS A BOW OF APPROXIMATELY 1/8" DVER ITS LENGTH. RFA RR 90 1834 WAS ISSUED FOR THIS CONDITION.
THE SUDPORT WAS ANALYZED TO SUBSTANTIATE ITS INTEGRITY FOR ITS INTENDED SERVICE AND FOUND TO BE ACCEPTA3LE.
cc 2116 WA3 0 007100 CC 2116*RR17 PIPING VT 3 NDEP 9.2 R0 ~
X.
- RR U
4 21 u
~ _ _....~....,._.
DATE: 02/23/91
$0UTN TEKAS PROJECT ELECTRIC GENERATING STAfl0N UNIT 2 PAGE:
17 REVltl0N:
0 INSERVICE INSPECTION PLAN flRST INTERVAL, flRST PERIOD, f!RST DUTAGE (1990)
O CLA$$ 3 $CHEDULED COMP 0kENTS COMPONENT COOL 1NC N
O A$ME D G T SEC. XI R E N
SUMMARY
EXAMINAfl0N AREA CATGY EXAM E O E REMACKS NUMBER IDENTIFICf'10N ITEM NO METHOD PROCEDURE C M R **CAllBRAfl0N BLOCK **
Ct.2116.WA3 M j
007200 CC.2116 RR18 PIPING VT.3 NDEP 9.2 R0 X
QUIDE CC.2116-WA3.J 007300 CC.2116-RR19 P!PlWG VT.3 NDEP 9.2 R0 X
RR 007400 CC.2116 RR20 PIPING VT.3 NDEP 9.2 R0 X
RR O
CC.2116 VA3.K 007300 CC.2116.RR01 PIPING VT*3 NDEP 9.2 R0 X
RR 007600 CC.2116.RR02 PIPING VT.3 NDEP 9.2 R0 X
RR CC.2117.WA3.L 007700 CC.2117 ML5006 PIPING VT.3 NDEP 9.2 R0 X
SH.V (2)
VT 4 X
007800 CC.2117.RR16 PIPING VT 3 NDEP 9.2 R0 X
AR O
4-22 1
l
DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
18 REvill0N 0
INSEPVICE INSPECTION PLAN FIRST INTEt/AL, !!RST PERIOD, FIRST OUTAGE (1990) eOMPONENT COOL 1NC class 3 SCHEDULED COMPONENTS N
O i
ASME O G T SEC. XI R E N
SUMMARY
EKAMINAfl0N AREA' CATGY EXAM E OE REMARKS WUMBER IDENTIFICAfl0N ITEM NO METNOD PROCEDURE CM R **CAllBRATION BLOCK **
9 tc.2117 m3 L 007900 CC 2117 RR17 PIPING VT.3 NDEP 9.2 R0 X
RR 008000 CC 2117 RR18 PIPING VT 3 NDEP 9.2 R0 X-*
RR CC 2117 WA3 M-008100 CC 2117 RR13 PIPING VT.3 WDEP 9.2 R0 X
AR OV 008200 CC*2117 RR14 PIPING VT.3 NDEP 9.2 R0 X
RR 008300 CC 2117 RR15 PIPING VT 3 NDEP 9.2 R0
.X RR tc.2117 WA3 N 008400 CC 2117*HL5005 PIPINO VT 3 NDEP 9.2 R0 X
RR CC 2117-WA3 R 006500 CC 2117 RR03 PIPING VT 3 NDEP 9.2 R0 X
GUIDE L
4 23
A DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2
-PACE:
19 REVill0N:
0 INSERVICE INSPECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST CUTAGE (1990) e.0MPONENTCOOLING CLASS 3 SCHEDULED COMPONENTS N
O ASME O G T SEC. XI R E H SUMMART EXAMINAfl0N ARCA CATGY EXAM E O E REMARKS NUMBER IDENilFICAfl0N ITEM NO METHOD PROCEDURE C M R ** CALIBRATION BLOCX**
CC 2117 WA3 T 008600 CC 2117 WL5001 PIPING VT*3 NDEP 9.2 RD X
VT*4 X
SH+V 008700 CC 2117 HL5003 PIPING VT 3 NDEP 9.2 R0 X
RR V
1 4 24 l
~
..-~.
DATE: 02/23/91 500TN TEXAS PROJECT ELECTRIC GENERATING STATION UNIT 2 PAGE:
20 REVIS10N '
0 INSERVICE IN=PECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIR $f CUTAGE (1990) e$$(WilALCOOLINGWATER class 3 SCHEDULED COMPONENTS-N O
ASME O G T SEC. XI R.E N SUMMART EXAMINAfl0N AREA CATGY EXAM E O E REMARKS NUMRER IDENTIFICAfl0N ITEM NO METHOD PROCEDURE C M R "CALIBRAfl0N BLOCK" EW 2101 WT3 B D08800 EW 2101.HL5001 PIP!NG VT.3 NDEP 9.2 R0 X
GUIDE EW 2101 VT3 t 008900 EW 2101 ML5002 P!P!NG VT.3 NDEP 9.2 R0 X
GUIDE
)
EW 2102 WT3 AJ.
D09000 EW 2102 HL5001 PIPING VT.3 NDEP 9.2 R0 X
g RR i
EW 2102 WT3 AP 009100 EW 2102 HL5003 PIPlWG VT.3 NDEP 9.2 R0 X
AR EW 2106 WT3 GG 009200 EW 2106 ML5001 PIPING VT 3 NDEP 9.2 R0 X
GUIDE
[W 2121 VT3 B 009300 EW 2121.HL5001 P! PING VT 3 NDEP 9.2 R0 X
GUIDE O
4-25
j.
1.
DATE: 02/23/91
.' 5OUTH TEXAS PROJECT ELECTRIC GENERATING STAil0N UNif 2 PACE:
21 REV1810Ns 0
INSERVICE INSPECTION PLAN FIRST INTERVAL, FIR $f PERIOD, FIRST CUTAGE (1990) 4EACTOR Mart UP WATER CLASS 3 SCHEDULED COMPONENTS N
0 ASME 0 0 T SEC. XI R E N SUMMART EXAMINATION AREA CATGT EXAM E O E REMARKS WUMBER IDENTIFICAfl0N ITEM NO METHOD PROCEDURE C M R **CAllBRATION BLOCK **
RM 2002 W3 A 009400 RM 2002 NL5001 PIPING VT*3 NDEP 9.2 R0 X
GUIDE
=
I 4 26
DATE: 02/23/91 SOUTN TEXAS DROJECT ELECTRIC CNERAflWG STATION UNIT 2 PAGE:
22 REY!$10Ns 0
INSERVICE INES'ECTION PLAN FIRST INTERVAL, FIRST PERIOD, FIRST OUTAGE (1990)
CLASS 3 SCHEDULED COMDONENTS
- EDUIPMENT SUPPORTS N
O ASME O O T SEC. XI R E H SUMMAR*. JAMINATION AREA CATGY EXAM E O F REMARKS NUMBER IDENTIFICATION ITEM No METHOD PROCEDURE C M R ** Call?RAfl0N BLOCK **
3R172NFR205A 009500 LDF1A EQUIP VT*3 NDEP 9.2 R0 X
LETDOW FILTER 2A SUPPORT IS LOCATED CV LTDW FLT BETWEEN THE QJTLET AND DRAIN CONNECTION.
009600 LDF2A EQUIP VT 3 NDEP 9.2 R0 X
LETDOW FILTER 2A SUPPORT l$ LOCATED CV LTDW FLT IMMEDIATELY CLOCXVISE FROM SUPPORT LDF1A..
LETDOWN FILTER 2A SUPPORT is LOCATED I
009700 LDF3A EQUIP VT*3 NDEP 9.2 R0 X
CV LTDW FLT IMMEDIATELY CLOCKWISE FROM SUPPORT LDF2A.
O LDF4A EQUlP VT 3 NDEP 9.2 R0 X
LETDOWN FILTER 2A SUPPORT.15 LOCATED CV LTDW FLT IMMEDIATELY CLOCKWISE FROM SUPPORT LDF3A.
/U 4 27 l
l
DATE: 02/23/91 SOUTH TEXAS PROJECT ELECTRIC GENERATlWG STAfl0N UNIT 2 PAGE:
23 REVil10N 0
INSERYlCE INSPECTION PLAN FIR $f INTERVAL, FIR $f PERIOD, FIRST GUTAGE (1990)
CLAts 3 $CNEDULED COMPONENTO G JW
- EQU!PMENT SUPPORTS N
O AlfE O G T SEC, XI R E: M BUMMARY EXAMINAfl0N AREA CMGY EXAM E O E REMARKS NUMBER IDENilflCA110N ITEM NO METN00' PROCEDURE C M R **CAllBRATION BLOCK'*-
30152MPX0134 009900 JCP1A EQUIP VT*3 NDEP 9.2 RL-X JACKET WATER CIRC. PUMP * $1NGLE BASE
- =
O 4 l
l 1
l DATE:-02/23/91 SOUTH TEMAS PROJECT ELECTRIC GENERATING STAfl0N UNIT 2 PAGE:-
24 REVISION:
0 lusERVICE IMPECT10N PLAN.
FIRST INTERVAL, flRST PERIOD, flR$f OUTAGE (1990)
CLASS 5 SCHEDULED COMPONENTS 1 SD EQU1PMENT SUPPORTS N
O
. A98E O G T SEC. XI R E N i
SUMMARY
EXAMINAfl0N AREA CATGT EMAM E-0 E REMARKS NUMSER IDEEfiflCAfl0N
-ITEM NO METHOD PROCEDURE C M R
- CAllBRATION BLOCK **
34152Mit0134 010000 SAT 1A EQUIP VT 3 NDEP 9.2 R0 x..
STARTING AIR RECEIVER 1A
- St,.4LE BASE SD STRT AIR SUPPORT.
O 4-29
)
l
I O
APPENDIX 4-B PERSONNEL O
O 4->o 1
-i i
)
APPENDIX 4-B PERSONNEL Name Company
],gyy.gl O. A Claxton HL&P.
1*
J. T. Graharn ht&P
- II M. J. Harris HL&P II S. K. Hubbard HL&P III D. L. Langston HL&P.
Il H. M. Murray HL&P II e
d' C. A. Murry HL&P II P. Silva HL&P II C M. Sist HL&P II C. D. Suhler '
HL&P II
. W. D. Kieler ESI-II A. R. Pennanen NES II O
Comnany HL&P - Houston Lighting & Power Company ESI
- Ebasco Services Inc.
NES
- Nuclear Energy Services
- Level I Trainec 4 31 l
w e
6 O
4 APPENDIX 4-C OWNER'S REPORT FOR INSERVICE INSPECTIONS NIS-1 FORMS
(]
i O
4-32
1990151 2RE01 - Component Shpports (Class l)'-
Page 1 of 3 FORM ltlS4 OWNER'S REPOP.T FOR INSERVICE INSPECTIONS As required ty the Provisions of the ASME Code Rules
.- u
- 1. Owner llouston Ughting 4 Power Company: Electric Tower: P.O. Box 1700;lipuston. Texas 77001 (Name and Address of Owner) m
- 2. Plant South Texas Project Electfic Generatini Station: P.O. Box 289: Wadswonh. Texas 77483 (Name and Address of Plant)
- 3. Plant Urd! _ _2 4, Owner and Cenlaate of Authorization (if required) NA
- 5. Commercial Senice Date Pf>/19/69
- 6. National Board Number for Unit N.A.
l
- 7. Components inspected -
ASMll Code Cass 1 Component Supports - P!plag and Equipmcar (3e6 Page 3 of 3 for Identiacation Numbers) l Manufactutet -
'l Component or
. Manufacturer or Installer--
National -
Appurtenance or Installer Serial No.
Board No.
Class 1
_pipine Soccorts Ebasco (11 NA
.JA PressbrlteFBase luf@r PRBI Westinghouse (M) 2161 19 m.
1 Note: Supplemental sheets in form of lists, sketches, or drawings may be used, provided (1) size is 8% in.
x 11 in., (2) information in items 1 through 6 on this report is included on each sheet, and (3) each sheet-O is numbered and the number of sheets is recorded at the top of each form.
4 33
{
WJ M 2MM torsp6Gs0 suppGB (Cho @ '
~
7aleToC FORM NIS-1 (Back)
- 8. Exarnination Dates 1022SO to 12M4/90 9, inspection Interval from 06/19At9 to M/19/99-
- 10. Abstract of Examinations. Include a list of examinations and a statement concerning status of wark G
required for current interval. (ASME Code Class 1 Compacut Suppons - Piping and Equipment)
See Sxtion 4.4 and Appendix 4 A of 2.RE01 Suramary Report for list of examinations performed.
- 11. Abstract of Conditions Noted.
No relevant cxmdi Jons were noted.
b
- 22. Abstract of Corrective Measures Recommended and Taken.
No corrective rneasures were taken or recommended.
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 oppilcable)
N.A.
Expiration Date N.A.-
Date fg6. 2 t-1991 Signed Houston IJehtine & Power Co. By Mg wd, owner R. L Bev r
CERTIFICA'II! OF INSERVICE INSPECTION 1, the undersigned, holding a valid commission issued by the National Board of Boller and Pressure O
Vestel Inspectors and the State or Province ofIcxas and employed by Arkwittht Mutual Insurance Co.-
of Norwood. Mass have inspected the components described in this Owner's Report during the period
/o -/ - fa to 4 -#A -4 l
. and state that to the best of my knowledge and belief, the Ownct has performed examinations and taken corrective measures described in this Owners Report in accordance with the inspection plan and as required by the ASME Code,Section XI.
By signing this certificate neithen J. Inspector not his employer makes any warranty, express or implied, concerning the examinations u.1 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. loss of any kind arisinC from or connected with this inspection.
Factory Mutual System Commissions Tex 826 Inspector's Signature National Board, State, Province, and Rndorsements B. R. Rucell Date
- " #d.'" 19.9/
)
4-34
1990 ISI 2RE01 Component Supports (Class 1)--
Page 3 cf 3 SUPPLEMEV. T'IV PORM NIS-1 OWNER'S REPORT FOR INSERV1CE JNSPECTIONS FOR ASME Code Class i Component Supports i
1 Owner Houston Lightint & Power Comrgy: Electric Tower: P.O. Box 1kn Houston. Texa177001 (Name and Address of Owner)
- 2. Plant. South Texas Protect Electric Generating Station: P.O. Box 289: Wadsworth. Texas 77483 (Name and Adorcss of Plant)
- 3. Plant Unit _2
- 4. Owner and Certificate of Authorization (if required)
N.A.
- 5. Commercial Service Date 06/19/8916. National Board Nu nber for Unit N.A.
PIPING SUPPORT MARK NO-CY 2121 HS5001 CV 2121.HS5002 RC 2003-HL3001 RC.2123-HL5010
-1 RC 2123 HL5011 RC 2123 HL5012 RC 2125 HL5009 RC 2125 HL5010 q
RC-2126 SH01 RC 2412 HL500/,
RH 2201 HL5001 RHJ2201 HL5009 EOUTPMENT Sl?i> ORT MARK NO.
PRBI J
- ML i P 2/n/11
/f44.
AN,II 9-9841 i
1 D
a 4-35 1
1990 ISI. 2RE01. Component Supports (cass !)
' " Tilt rFi PORM NIS.! 0% NER'S REPORT POR ISSimVICE IN3PEC110NS As required h the PrmWes of the N;ME Code Rules
--=
- n
- 1. Owner _liouston Lithlint & Power Company.Fketric Towen P.O. Box 1700t flouston. Texas 77001
~
(Name and Address of Owner)
- 2. Plant South Texas Project Electric Get.tt3 tine Staiton: P.O. Box 2P9. Wadsworth. Texas 77483 (Name and Address of Plant)
- 3. Plant Unit 2
- 4. Owner and Certificate of Authorhation (if required)
N.A.
- 5. Commercial Service Date 06/19189
- 6. National Board Number for Un" N.A
- 7. Components inspected ASME Code cans 2 Component Supporta. Piping and Equipment (See Page 3 of 3 for Identification Nombers)
Manufacturer--
Component or Manufacturer or Installer National Appurtenance or Installer Scrial No.
Board No.
Class 2
_ Piping _ Supports Ehasco(I)
N.A N A.,,
Regenerative j
._ ltat Dchangtr_ _-
JossplLQat, Carp. IM) 2380.jB
_20$ L l
2tdown
_}icaLExchangen Joseph Oat CorpdM) 2312 1D 987 Excess Letdown
_llcal Exchanger Jpicph Oat Corp. (M) 2312.3B 989 a
O s
4 5
Note: Supplemental sheets in form of lists, sketches, or drawings may be used, provided (1) size is 8% in.
x 11 in., (2) Information in items 1 through 6 on this report is included on each sheet, and (3) each sheet j
is numbered and the number of sheets is recorded at the top of each form.
4 36 iin
.,_a
!?90 ISI - 2RE01 Component Supports (Clau 2)
Page 2 of 3 FORM NIS.! (Bsck)
- 8. Examination Dates _ 09/1890 to 12A1580
- 9. Inspection Interval from 06/19#9 to 06/19N9-r
- 10. Abstract of Examinations. Include a list of examinations and a.tatement conectning status of work required for current interm. (ASME Calc Class 2 Component Supports. Piping and Equipment)
Soc Section 4.4 and Appendiz 4 A of 2RE01 Summary Report for list of examinations performed,
- 11. Abstract of Conditions Noted.
Piping support $12105S1110 was found with the sprint bqer setting out of tolerance in the cold load mndition. Sec Sutton 4.5 of 2RE01 Sutamary Re :>rt for dhcussion.
- 12. Abstruct of Corrective Measures Recommended and Taken.
De St.210 Mil 10 support was analynd to sutstantlate its Integrity for its intended service and found to te acxrptable, llowever, it was remmmended that the spring hanger be reset. %Is work was not completed during 2RE01. No additional (nrrective measurcs were taken or recommended.
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 Authorintion No.(if applicable)
N.A.
Expiration Date,.f.A.
Date M.Of-19'U_, Signed. Houston Lichtinc & Power CL By OM L.Deverl{'
Owber CERTIFICATE OF INSERVICE INSPECTION 1, the undersigned, halding a valid commission issued by the National Board of Boiler and Pressure Vessel inspectors and the State or Province of Inu and employed by Arkwricht Mutual Insurance Co.
s, of Norwood Mass have inspected the components described in this Owner's Report during the perisd a
<? - /5~- fe _,,,, to # c24-#h
. and state that to the best of my knowledge and belief, the Owner has performed examinations and taken corrective mrasures described in this Owner's Report in accordance with the inspection plan and as required by the AFME 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 prope damage or a loss of any kind arising from or connected with this inspection.
Factory Mutual System Commissions Tex 826 Inspector's Signature National Board, State, Province, and Endorsenients B. R. Russell Date c7 - # 0 *19 9 /
O u
4 37
1990 ISI. 2RE01 Component Supports (Qass 2)
Page 3 of 3 SUPPLEMENT TO IORM NIS 1 OWNER'S REPORT FOR INSERVICE INSPECPIONS FOR ASME Code Gau 2 Component Supports
- 1. Owner Houston Ilehtinc & Power Com.pany. Electric Tower: P.O. Box 1700 Houston. Texas 77001
[V_')
(Name and Address of Owner)
- 2. Plant South Texas Prolect Electric Generatinc Station: P,0. 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!!929
- 6. National Board Number for Unit N.A.
PIPING SUPPORT MARK NO.
AF 2012 HL5007 AF 2012 HL5(99 c 2203 HL5005 CS 2301 HL5003 FW 2016 !{L5013 FW 2031 l{L5001 MS 2001 HL5001 MS 2001 HL5002 MS 2002 HL5002 MS 2003 HL5018 MS 2003 liL5019 RH 2103 HL5001 RH 2103 RR06 RH.2103 RR04 RH 2204 HL5003 RH 22%RR02 p}
RH 2204 RR03
('
RH 22%HL5012 SI 2101 SH11 S!.2101 RH07 St 2101 HL5023 SI 2101 RR23 St 2101 RR24 Sl 2101 SH13 SI 21%RR12 St 21%SH10 SI 21%RH08 SI 21%RR09 SI 21%GU70 SI 21%HL5012 SI 21%RRS6 SI 21%RR58 SI 21%RR54 SI 21%RR$5
{$',7 SI 21%RR$9 St 21%RR57 p,p3 41 EOUTPMENT SUPP_ ORT MARK NO.
kh, "lal War 7/tz/9/
RHX3
,7~'N LDHX1
(.)
LDHX2 EXHXI EXHX2 4,3g
two 161 2kLol. tempunem 1,uppmu (uau.4 4 p A u. a TORM NIS 1 OWNER'S REPORT FOR INSERVICE INSPECTIONS As required ty the Prtwisions of the ASME Code Rules
- 1. Ownct flouston Llchtint & Power Company: Electric Tower: P.O. Bot 17Cn Houston. Texas 77001
( )
(Name and Address of Owner)
- 2. Piant 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) NA
- 5. Commercial Service Date 06/1929
- 6. National Board Number for Unit NA
- 7. Components inspected ASME Code Class 3 Component Supports. Piping and Equipment (Soc Page 3 of 3 for Identification Numbers)
Manufacturer Component or Manufacturer or Installer National Appurtenance or Installer Serial No.
Board No.
Class 3
_PJplng_SuppoJts EbucoJ)
NA NA Paul Trinity lcidomLEilter 2A MitIQ Corp _(M)
SEH.F9073 3 17444 DO Jacket Water Cooper Energy
_Gremhtmn SenitcLIhD 8L0101 NA DO Starting Air Cooper Energy
,Rgce!ver 1 A SCDdecs :(M) 8KD30L _
1050 g
Na Note: Supplemental sheets in form of lists, sketches, or drawirigs may be used, provided (1) size is 8% in.
x 11 in., (2) information in items 1 through 6 on this report is included on cach sheet, and (3) each sheet (3
is numbered and the number of sheets is recorded at the top of each form.
t i
4 39
1990151 2RE01 Component Supports (Class 3)
Page 2 of 3 FORM NIS.1 (Back) 1
- 8. Examination Dates 09/17B0 to 11/1390
- 9. Inspection Interval from 06/1939_. to 06/19199-
[
- 10. Abstract of Examinations. Include a list of examinat!ons and a statement concerning status of work required for current interval. (ASME Code Class 3 Component Supports Piping and Equipment) v Soc Section 4.4 and Appendix 4-A of 2RE01 Summary Report for lht of examinations performed.
- 11. Abstract of Conditions Noted.
Piping support CC 211o.IIL5006 was found with a slight bow in the sway strut of approximately 1/8' over its length. See Section 4.5 of the 2RE01 Summary Report for discussion.
- 12. Abstract of Corrective Measures Recommended and Taken.
nc CC.2116-lilSX)6 support was analynxi to substantiate its integrity for its intended service and found to be aweptable. No cortcctive measures wrc taken or recommended.
We certify that the statements made in thM 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 FM3 21 19 7 /
Signed Houston 1.fchtinc & Power Co _ By M8b-R'. L Bever/]y Owner CERTIFICATE OF INSERVICE INSPECPION r~ s 1, the undersigned, holding a valid commission issued by the National Board of Boller and Pressure
(
Vessel inspectors and the State or Province of Texas and employed by Arkwricht Mutual Insurance Co.
of Norwood. Mass hwe inspected the components described in this Owner's Report during the period 4-/f #10 to
.P - M --f /
. and state that to the best of my knowledge and belief, the Owner has perform?4 cxaminations 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 4 mage or a loss of any kind arising from or connected with this inspection.
Factory Mutual System
- h Commissions Tex 826 e
Inspector's Signature National Board, State, Province, and Endorsements B. R. Russell Date 2 19 4 /
/
((
4-40
1990 ISI 2RE01 Component Supporu (Clau 3)
Page 3 of 3 SUPPLEMENI"IO FORM NIS 1 OWNER'S REPORT FOR INSERVICE INSPECrlONS FOR ASME Code Qau 3 Cbmponent Supports f
- 1. Owner Houston Lichtint & Power Comriany: Electric Tower: P.O. Box 1700: Houston. Texn 77001 j
(Name and Address of Owner) 2 Plant South Texas ProkSt Electric Generatint Station P.O. Box 289: Wadsworth. Texas 77483 (Name and Addreas of Plant) 3 Plant Unit 2
- 4. Owner and Certithste of Authorization (if required) _ N.A.
- 5. Commercial Service Date 06!!9/89 6 National Board Number for Unit N.A.
{
PIPING SUPPORT MARK No.
AF 2047 HL5002 j
AF 2047 HL5003 AF 2047 HL5001 AF 2079 HL5003 AF 2079 HL5004 AF 2079 HL5005 i
AF 2079 HL5006 i
CO2115 RR25 CC 2115.RR26 CO2115 RR23 l
CO2115 RR24 CO2116 HL5005 CC 2116 HL5006 CO2116 RR17 CC 2116 RR18 O
CO2116 RR19 CC 2116 RR20 CC 2116 RR01 CC 2116 RR02 CC 2117 HL5006 CC-2117 RR16 CO2117 RR17 CC 2117 RR18 CO2117.RR13 CO2117 RR14 CO2117 RR15 CC 2tl7 HL5005 CC 2117 RR03 CC 2117 HL5001 CC 2117 HL5003 EW 2101 HL5001 j
EW 2101 HL5002 EW 2102 HL5001 EW 2102 HL5003 gg/
EW 2106-HL5001 pj EW 2121 HL5001 p./6 -4l RM 2002 HL5001 h
EQUIPMENT SUPPORT MARK No.
p LDFIA VI 7/tsh/
f "N LDF2A-Q
! DF3A i
I LDF4A JCPIA SATIA 4,43 n
n m