ML19291F576
| ML19291F576 | |
| Person / Time | |
|---|---|
| Site: | Palo Verde  |
| Issue date: | 10/18/2019 |
| From: | Dilorenzo M Arizona Public Service Co (Formerly Arizona Nuclear) |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| 102-07999-MDD/JWK | |
| Download: ML19291F576 (43) | |
Text
Qaps Technical Specification 5.6.8 Palo Verde Nuclear Generating Station 5801 S. Wintersburg Road Tonopah, AZ 85354 102-07999-MDD/JWK October 18, 2019 ATTN: Document Control Desk U. S. Nuclear Regulatory Commission Washington, DC 20555-0001
Subject:
Palo Verde Nuclear Generating Station (PVNGS) Unit 1 Docket No. STN 50-528 License No. NPF-41 Steam Generator Tube Inspection Report Attached please find the PVNGS Unit 1 Steam Generator Tube Inspection Report prepared and submitted by Arizona Public Service Company (APS) pursuant to Technical Specification (TS)
Reporting Requirement 5.6.8. This report describes steam generator tube inspection and plugging results from the Unit 1 twenty-first refueling outage.
By copy of this letter, this submittal is being provided to the NRC Region IV Administrator and the PVNGS Senior Resident Inspector. No commitments are being made to the NRC by this letter.
Should you have questions regarding this submittal, please contact Michael D. Dilorenzo, Nuclear Regulatory Affairs Department Leader, at (623) 393-3495.
Sincerely, Michael D. Dilorenzo Nuclear Regulatory Affairs Department Leader MDD/JWK/mg Attachment cc:
(with attachment)
K. M. Kennedy S. P. Lingam C. A. Peabody NRC Region IV Regional Administrator NRC NRR Project Manager for PVNGS NRC Senior Resident Inspector for PVNGS A member of the STARS Alliance LLC Callaway
- Diablo Canyon
- Palo Verde
- Wolf Creek
Attachment Unit 1 - 21* Refueling Outage Steam Generator Tube Inspection Report
PaloVerde GENERATING STATION UNm U1R21 ARIZONA PUBLIC SERVICE P. O. BOX 52034 PHOENIX, AZ 85072 Prepared by; Douglas Hansen 4-29-19 Reviewed by:
Leaverton, Warren L(V59783)
Digitally signed by Leavertoa Warren L{V59783)
DN: cn<<Leaverton, Warren UV59783)
Reason: I have reviewed this document Date: 2019.093)4 14:1&44 -OrOO Kniesteadt, Approved by: Sabrina M(Z09662)
DN: cnsKnIesteadt. Sabrina M(Z09662)
Reason: Primary System Engineering Section Leader Date: 20193>93>614:12-^9 -07W Commercial Service Date: 1-28-86 Digitally signed by Gil, Katherine J(Z05492)
DN: cn=Gil, Katherine J(Z05492)
Date: 2019.10.11 15:34:15-07'00' 1 of 41
Table of Contents 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0
SUMMARY
SCOPE OF EXAMINATIONS PERFORMED ACTIVE DEGRADATION MECHANISMS NDE TECHNIQUES UTILIZED INDICATION
SUMMARY
TUBES PLUGGED PLUG HISTORY CONDITION MONITORING APPENDIX A - TUBE SUPPORT DIAGRAM, LEGEND, and ANALYSIS CODES APPENDIX B - SG 11
SUMMARY
DATA SHEETS APPENDIX C - SG 12
SUMMARY
DATA SHEETS APPENDIX D - PLI and PLP DATA SHEETS APPENDIX E - PLUG MAPS 2 of 41
UNITl STEAM GENERATOR EDDY CURRENT U1 R21 Refueling Outage 1.0 Summary This report is intended to satisfy the requirements of PVNGS Technical Specifications 5.6.8 for the submittal of a Steam Generator Tube Inspection Report. The steam generator (SG) eddy current examination for the 21^ refueling outage in Unit 1 (U1R21) was conducted during April 2019.
Mode 4 entry was on May 4, 2019. The initial examination plan for both steam generators is listed in Table 1. This table summarizes the examinations performed for each of the various categories, examination types, extents, and the number of tubes or tube locations completed. This examination was a 100% full length tubing inspection.
The examinations resulted in a total of 73 tubes being plugged in SG 11, and 53 tubes being plugged in SG 12. A description of the previous plugging history for these replacement steam generators is contained in Appendix E.
2.0 Scope of Examinations Performed The original examination plan was developed based on the PVNGS U1R21 Steam Generator Degradation Assessment (Intertek document number AIM 190310567-2-1 dated April 11, 2019).
This document was developed per PVGS Procedure 81DP-9RC01 as required by NEI 97-06. In addition, possible damage mechanisms were reviewed along with the specific requirements set forth in Procedure 73T1-9RC01 and the PVNGS Technical Specifications.
This original plan, along with the examinations performed as a result of bobbin indications noted, is summarized in Table 1 of this report.
3.0 Active Degradation Mechanisms The only degradation noted during the examinations was determined to be wear. Section 8.0 contains further discussions relating to this mechanism. Table 2 summarizes the results into categories and sections B and C itemizes all indications reported.
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4.0 NDE Techniques Utilized The following table documents the site validated and qualified techniques utilized during this outage:
BOBBIN Examinations Damage Mechanism Location ETSS NO QUAL STATUS Extended Applicability BC DET BC SIZE TECH Comment Wear BWs, VSs, ECs (not dented) 96004.1 R13 SITE VALIDATED Tube Proximity Y
Y Volt DIFF Note Wear Loose Part 27091.2 R2 QUALIFIED Tubesheet Transition Y
N Volt DIFF Note ARRAY Examinations Damage Mechanism Location ETSS NO QUAL STATUS Extended Applicability DET SIZE TECH Comment Wear BWs, ECs, VSs 11956.3 R2 11956.4 R2 QUALIFIED Wear at Dented Supports X-Probe Note The U1R21 Degradation Assessment and associated site validation provides details for the qualification and use of the above techniques The eddy current examinations were performed by Westinghouse Electric Company using the Core Star OMNI 200 eddy current instrument. Westinghouse Anser software was utilized to acquire the data along with the Pegasys robotic manipulator. This robot was configured with a dual guide tube in each of the hot and cold legs.
The tubing was examined with Core Star manufactured bobbin coil probes and Zetec array and rotating coil style probes. The probe diameter utilized for all bobbin examinations was 0.610.
Array probes and rotating coils were used for the characterization of non-quantifiable or distorted bobbin indications.
Fiber optic cable was used from containment to the data acquisition room located at the PVGS North Annex. Primary and secondary analysis was all performed on site. The Primary and Secondary Resolution Analysts, Independent Review Analysts, and data management were also located at PVGS in the North Annex (G building). Westinghouse provided the data acquisition and primary data analysis. Zetec and NDE Technology provided the secondary data analysis and Framatome provided the independent quality data analysis.
Each individual from Westinghouse, Zetec, NDE Technology, and Framatome who performed data analysis was required to complete and pass a PVGS site specific Eddy Current Data Analysis 4 of 41
Course as well as an associated performance and written examination. All individuals performing data analysis were also required to have Qualified Data Analyst (QDA) certification. Per 73TI-9RC01, all certification records are maintained in the Nuclear Information Records Management System.
5.0 Indication Summary A detailed listing of the location and measured sizes of all service induced indications recorded is included in Appendix B and C. A summary of these indication results is located in Table 2. In addition, Appendix A contains a reference drawing of steam generator support locations and report legend.
Appendix D contains a listing of the possible loose part (PLP) indications that were confirmed with rotating coil examinations. Note Section 8.0 for further discussion on the PLPs.
There were no indications that were identified as linear during this outage.
6.0 Tubes Plugged A summary of the tubes plugged is located in Table 2. Appendix E contains a map that details the plugged tube location along with the previously plugged tubes.
7.0 Plug History A summary of the number and percentage of tubes plugged is also located in Table 2.
8.0 Condition Monitoring Tube Inspection Summary Per the Steam Generator Program, as defined in PVNGS Procedure 81DP-9RC01, a condition monitoring evaluation was conducted by PVNGS Engineering. The results of the eddy current examinations are provided in Section 5.0. An engineering evaluation of the as-found condition of inservice tubes did not reveal any degradation exceeding the threshold values for structural and leakage integrity. As such, all steam generator performance criteria were satisfied for Unit 1 Cycles 20 and 21. No tube pulls or in-situ pressure testing were required based on the results of the examinations.
Foreign Object Search and Retrieval (FOSAR)
FOSAR was performed at the tubesheet elevation in the annulus region and the blowdown lane. The applicable requirements of Revision 4 of the EPRI Steam Generator Integrity Assessment Guidelines Section 10.3, Foreign Object Search and Retrieval, were applied for the FOSAR inspections.
An evaluation was performed to determine if Flow Distribution Plate (FDP) area FOSAR should continue to be performed with the FDP robot (or guide tubes) or if reliance on ECT in the area is considered adequate to find foreign objects. It was concluded that the ECT method is acceptable.
This approach has been used several times in previous inspections. ECT monitoring of the FDP area in SGI 1 and SG12 during U1R21 did not identify any foreign objects or foreign object wear, so further testing of the area from the secondary side was not performed.
5 of 41
No foreign object wear was found in either steam generator 11 or 12. Following is a summary of the foreign objects that were identified in each SG. Sludge rocks, scale and graphite are not discussed, since they are not considered as a threat to tube integrity.
SGll -Foreign object Summary No metallic foreign objects were identified.
SG12 -Foreign object Summary There was one non-sludge/scale object found during FOSAR in SG 12 (very thin piece of weld slag). The object was retrieved from the cold leg top of tubesheet by tube R98C185. The object was approximately 2.0 long. There was no wear identified by bobbin or special interest testing.
Blowdown Patch Plate Weld Inspection Summary Also included in the scope of the FOSAR effort was an inspection of the blowdown patch plate welds in SGI 1 and SG12 that were found to be cracked during 1R15. Inspections confirmed that the weld material in the vicinity of the cracked weld on all 4 patch plates (2 per SG) is intact, and a loose parts concern is not being created. A previous evaluation concluded that, with the presence of the cracked welds, the patch plates in the Unit 2 SGs will continue to perform their design function and that the probability of loose parts being formed is remote. This evaluation also applies to Unit
- 1. Thus, there is a very low risk that the cracked welds will affect the structural or leakage integrity of tubes in these steam generators.
Plug Inspections Summary The EPRJ PWR Steam Generator Examination Guidelines require that a visual inspection of the previously installed steam generator plugs be performed to assess plug integrity. Additionally, the Examination Guidelines require a verification of the location and presence of existing in-service plugs. The conduct of the plug location and integrity verification was performed in 1R21 per the applicable procedure. A review of the inspection results indicated that all plugs were accounted for and no evidence of potential plug leakage was identified.
Channel Head Inspection Summary A channel head inspection was also performed in response to Westinghouse Engineering Nuclear Safety Advisory Letter (NSAL) 12-1, dated January 5, 2012. The inspection identified no degradation.
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TABLE 1 EXAMINATION
SUMMARY
SCOPE DESCRIPTION SG 11 SG 12 Exam Description Extents Scope Scope FULL LENGTH BOBBIN TEC-TEH 12469 12450 HOT LEG ARRAY VARIOUS 270 208 COLD LEG ARRAY VARIOUS 74 95 HOT LEG ROTATING COIL VARIOUS 19 0
Notes:
ARRAY probe technology utilized the X-Probe>'
Rotating Coil utilized +Point^'
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TABLE 2 INDICATION
SUMMARY
DAMAGE MECHANISM STEAM GENERATOR 11 STEAM GENERATOR 12 Tubes Indications BW VS EC Tubes Indications BW VS EC WEAR 1% -19%
20%-29%
30%-39%
>40%
PLUGGED 748 93 22 7
(54) 832 97 22 9
478 67 16 9
288 21 6
0 66 9
0 0
926 76 10 4
(39) 1042 85 11 4
487 39 8
4 469 40 3
0 86 6
0 0
Possible Loose Parts (Array Probe)
PLI PLP PLUGGED 0
6 (0) 0 1
(0) te Ii*
PREVENTATIVE (19)
(14) 1 -
PLUGGED (73)
(53)
TOTAL PLUGGED/
( 184 / 1.4% )
( 173 / 1.4% )
NOTES:
- 1. Numbers in (X) are tubes numbers plugged in each category
- 2. The Tubes column above represents Bobbin Coil results for the number of tubes; using the largest wear indication
- 3. The Indications column above represents Bobbin Coil results for the number of wear indications LEGEND:
BW - batwing VS - vertical strap EC - eggcrate 8 of 41
APPENDIX A TUBE SUPPORT DIAGRAM, LEGEND, and ANALYSIS CODES 9 of 41
PVNGS Steam Generator REPLACEMENTS Center of OSH to 08C Row1 - 17.415 Row 2-19.736 Row 3 - 22.066 Row 4-24.377 Row 5 - 26.698 Row 6-29.019 26 Typical Spacing VS1 VS3 VS4 VS5 36.75 09C 35.95 36.34 28.125
- 28. 25 32.25' 25+ 0.25 clad Out et 10 of 41
LEGEND ROW COL VOLTS DEG IND PER or PCX CRN LOCN CRLEN CRWID CEG BEGT and ENDT PDIA PTYPE CAL L
COM Indicates the row number of a given tube.
Indicates the column number of a given tube.
Indicates the peak-to-peak voltage of a given indication response.
The measured phase angle of a given indication response.
Indicates the analysis code or PCX for percent The percent through the tube wall of a given indication Indicates the channel used to make the call Gives indication location at fNCHl to fNCH2 relative to known landmarks such as supports, vertical straps, and batwings. Typical location codes are as follows:
- 1 Vertical Strap............................. VSl
- 1 Batwing......................................BWl
- 1 Support Plate in Hot Leg............OlH
- 7 Support Plate in Cold Leg...........07C Top Tube Sheet Cold Leg................TSC Tube End Hot Leg...........................TEH Tube End Cold Leg......................... TEC Indicates the flaw length, used to identify the length of a wear indication Indicates the flaw width, typically used for cracks only Indicates the flaw length, typically used for cracks only Indicates the beginning and of the test; together they document the examination extent Documents the probe diameter Documents the probe type Indicates calibration number Indicates the leg the examination was conducted from This comment field is utilized to document comments 11 of41
Analysis CODES:
Absolute Drift.................................................................ADI Bulge.............................................................................. BLG Dented Buff Mark...........................................................DBM Deposit........................................................................... DEP Dent................................................................................ DNT Data Quality Acceptance................................................. DQA Distorted Support Signal With Indication........................DSI Distorted Top of Tubesheet With Indication...................DTI Geometric Indication.......................................................GEO ID Chatter........................................................................IDC Indication Not Found......................................................INF Indication Not Reportable............................................... INR Multiple Axial Indication................................................ MAI Manufacturer Burnishing Mark........................................MBM Mixed Mode Indication................................................... MMI Multiple Circumferential Indication.................................MCI Multiple Volumetric Indication....................................... MVI No Detectable Defect......................................................NDD No Discontinuity Found.................................................. NDF Non-Quantifiable Indication........................................... NQI No Tube Sheet Expansion............................................... NTE Obstructed.......................................................................OBS Over Expanded................................................................OXP Previous Bobbin Call.......................................................PBC Possible Deposit...............................................................PDP Positive Identification......................................................PID Positive Identification Verified........................................ PIV Possible Loose Part with Indication..................................PLI Possible Loose Part..........................................................PLP Previous RC Call..............................................................PRC Possible Support Anomaly............................................... PSA Possible Support Indication............................................. PSI Permeability Variation Noise.......................................... PVN Retest Bad Data...............................................................RBD Retest Identification Check............................................. RIC Retest with Magnetic Bias RC Probe...............................RMB Single Axial Indication...................................................SAI Single Circumferential Indication....................................SCI Single Volumetric Indication.......................................... SVI Senior (Lead) Analysis Review...................................... SR Sludge............................................................................ SLG To Be Plugged.................................................................TBP Volumetric Indication.....................................................VOL 12 of 41
APPENDIX B STEAM GENERATOR 11
SUMMARY
DATA SHEETS 13 of 41
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SUMMARY
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APPENDIX F FORM NIS-1 38 of 41
APS NIS -1 FORM OWNERS DATA REPORT FOR INSERVICE INSPECTIONS
- 2. PLANT PALO VERDE NUCLEAR GENERATING STATION 2a. ADDRESS 5801 SOUTH WINTERSBURG ROAD, TONOPAH, ARIZONA 85354
- 3. UNIT NUMBER 1
- 4. OWNERS CERTIFICATE OF AUTHORIZATION NONE
- 5. COMMERCIAL SERVICE DATE 1-8-88
- 6. COMPONENTS INSPECTED:
COMPONENT OR APPURTENANCE MANUFACTURER OR INSTALLER SERIAL NUMBER STATE OR PROVINCE NATIONAL BOARD NO IMRCEEOIA STEAM GENERATOR 11 Ansaldo 224 NA 173 IMRCEEOIB STEAM GENERATOR 12 Ansaldo 225 NA 174 39 of 41
APS NIS -1 BACK OWNERS DATA REPORT FOR INSERVICE INSPECTIONS
- 7. EXAM DATES April 2019
- 8. INSPECTION INTERVAL 7-18-08 to 7-17-18 (in 1 year extension)
- 9. ABSTRACT OF EXAMINATIONS. INCLUDE A LIST OF EXAMINATIONS AND A STATEMENT CONCERNING STATUS OF WORK REQUIRED FOR CURRENT INTERVAL.
Table 1 in the report summary section documents the number and type of each examination performed.
A summary of the tubes with indications of degradation is listed in Appendix B and C of this report for SG11 and 12 respectively. The tubes identified on the attached page were plugged as a result of this examination.
The number of tubes plugged are as follows: SG 11 = 73 tubes SG 12 = 53 tubes WE CERTIFY THAT THE STATEMENTS MADE IN THIS REPORT ARE CORRECT AND THE EXAMINATIONS AND CORRECTIVE MEASURES TAKEN CONFORM TO THE RULES CODIi;,^I^^KWXf."<<"'
Douglas D£n=Hansen,Doug,as DATE SIGNED: ARIZONA PUBLIC SERVICE COMP ANYrBAr ill I-Reason; Level lll
_SIGNED: ARIZONA PUBLIC SERVICE COMPANYj^^^.j Date: 2019.09.04 08:26:28 -07 00 CERTIFICATE OF INSERVICE INSPECTION I, THE UNDERSIGNED, HOLDING A VALID COMMISSION ISSUED BY THE NATIONAL BOARD OF BOILER AND PRESSURE VESSEL INSPECTORS AND THE STATE OF PROVINCE OF ARIZONA EMPLOYED BY THE HARTFORD STEAM BOILER INSPECTION AND INSURANCE COMPANY HAVE INSPECTED THE COMPONENTS DESCRIBED IN THIS OWNERS REPORT DURING THE PERIOD 04-06-19 to 09-04-19, AND STATE THAT TO THE BEST OF MY KNOWLEDGE AND BELIEF, THE OWNER HAS PERFORMED EXAMINATIONS AND TAKEN CORRECTIVE MEASURES DESCRIBED IN THIS OWNERS REPORT IN ACCORDANCE WITH THE REQUIREMENTS OF THE ASME CODE, SECTION XL BY SIGNING THIS CERTIFICATE NEITHER THE INSPECTOR NOR HIS EMPLOYER MAKES ANY WARRANTY, EXPRESSED OR IMPLIED, CONCERNING THE EXAMINATIONS AND CORRECTIVE MEASURES DESCRIBED IN TIBS OWNERS REPORT. FURTHERMORE, NEITHER THE INSPECTOR NOR HIS EMPLOYER SHALL BE LIABLE IN ANY MANNER FOR ANY PERSONAL INJURY OR PROPERTY DAMAGE OR A LOSS OF ANY KIND ARISING FROM OR CONNECTED WITH THIS INSPECTION.
M nn Cf rn m Digitally signed by Hogstram, nUy ill Ul I I, Robert(YH2450)
DN: cn=Hogstrom, Robert (YH2450)
INSPECTOR Robert (YH2450)
COMMISSIONS: N.B. 9685 C,I,N,R Az 264 NATL BOARD, STATE, PROVINCE DATE
APS NIS - 1 page 3 OWNERS DATA REPORT FOR INSERVICE INSPECTIONS SGll S<
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