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
Technical Specification 5.6.8 Qaps 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 NRC Region IV Regional Administrator S. P. Lingam NRC NRR Project Manager for PVNGS C. A. Peabody 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 Leaverton, Digitally signed by Leavertoa Warren L{V59783)
Warren DN: cn<<Leaverton, Warren UV59783)
Reviewed by: L(V59783)
Reason: I have reviewed this document Date: 2019.093)4 14:1&44 -OrOO Kniesteadt, Approved by: Sabrina DN: cnsKnIesteadt. Sabrina M(Z09662)
Reason: Primary System M(Z09662) Engineering Section Leader Date: 20193>93>614:12-^9 -07W Digitally signed by Gil, Commercial Service Date: 1-28-86 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
SUMMARY
2.0 SCOPE OF EXAMINATIONS PERFORMED 3.0 ACTIVE DEGRADATION MECHANISMS 4.0 NDE TECHNIQUES UTILIZED 5.0 INDICATION
SUMMARY
6.0 TUBES PLUGGED 7.0 PLUG HISTORY 8.0 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 ETSS QUAL Extended BC BC Location Applicability TECH Comment Mechanism NO STATUS DET SIZE Wear BWs, VSs, 96004.1 SITE Tube Y Y Volt DIFF Note ECs R13 VALIDATED Proximity (not dented)
Wear Loose Part 27091.2 QUALIFIED Tubesheet Y N Volt DIFF Note R2 Transition ARRAY Examinations Damage ETSS QUAL Extended Comment Location Applicability TECH Mechanism NO STATUS DET SIZE 11956.3 Wear at Wear BWs, ECs, R2 QUALIFIED Dented X-Probe Note VSs 11956.4 Supports R2 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.
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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 TEC-TEH 12469 12450 BOBBIN HOT LEG VARIOUS 270 208 ARRAY COLD LEG VARIOUS 74 95 ARRAY HOT LEG VARIOUS 19 0 ROTATING COIL Notes:
ARRAY probe technology utilized the X-Probe>'
Rotating Coil utilized +Point^'
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TABLE 2 INDICATION
SUMMARY
DAMAGE STEAM GENERATOR STEAM GENERATOR MECHANISM 11 12 Tubes Indications BW VS EC Tubes Indications BW VS EC WEAR 1% -19% 748 832 478 288 66 926 1042 487 469 86 20%-29% 93 97 67 21 9 76 85 39 40 6 30%-39% 22 22 16 6 0 10 11 8 3 0
>40% 7 9 9 0 0 4 4 4 0 0 PLUGGED (54) (39)
Possible Loose Parts (Array Probe)
PLI PLP 0
6 0
1 te PLUGGED (0) (0)
Ii*
1 -
PREVENTATIVE (19) (14)
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 26 Typical Spacing VS1 VS3 VS4 VS5 36.75 09C 35.95 36.34 28.125
- 28. 25 32.25' 25+ 0.25 clad Center of OSH to 08C Row1 - 17.415 Row 2- 19.736 Out et Row 3 - 22.066 Row 4- 24.377 Row 5 - 26.698 Row 6- 29.019 10 of 41
LEGEND ROW Indicates the row number of a given tube.
COL Indicates the column number of a given tube.
VOLTS Indicates the peak-to-peak voltage of a given indication response.
DEG The measured phase angle of a given indication response.
IND Indicates the analysis code or PCX for percent PER or PCX The percent through the tube wall of a given indication CRN Indicates the channel used to make the call LOCN 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 CRLEN Indicates the flaw length, used to identify the length of a wear indication CRWID Indicates the flaw width, typically used for cracks only CEG Indicates the flaw length, typically used for cracks only BEGT and ENDT Indicates the beginning and of the test; together they document the examination extent PDIA Documents the probe diameter PTYPE Documents the probe type CAL Indicates calibration number L Indicates the leg the examination was conducted from COM 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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APPENDIX C STEAM GENERATOR 12
SUMMARY
DATA SHEETS 24 of 41
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APPENDIX D PLI & PLP DATA SHEETS 32 of 41
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APPENDIX F FORM NIS-1 38 of 41
NIS -1 FORM APS 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 MANUFACTURER SERIAL STATE OR NATIONAL APPURTENANCE OR INSTALLER NUMBER PROVINCE BOARD NO IMRCEEOIA Ansaldo 224 NA 173 STEAM GENERATOR 11 IMRCEEOIB Ansaldo 225 NA 174 STEAM GENERATOR 12 39 of 41
NIS -1 BACK APS 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:
SIGNED: ARIZONA ARIZONA PUBLIC PUBLIC SERVICE SERVICECOMP COMPANYj^^^.j ANYrBAr ill I-Reason; Level lll 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)
INSPECTOR Robert (YH2450) DN: cn=Hogstrom, Robert (YH2450)
COMMISSIONS: N.B. 9685 C,I,N,R Az 264 NATL BOARD, STATE, PROVINCE DATE
NIS - 1 page 3 APS OWNERS DATA REPORT FOR INSERVICE INSPECTIONS SGll S<
Row Col Row Col Row Col Row Col 119 54 52 103 16 75 39 118 129 64 50 105 19 76 41 118 16 75 50 107 24 77 38 119 19 76 47 108 25 78 36 121 24 77 51 110 27 78 35 122 28 79 45 112 28 79 37 122 32 81 47 112 31 80 39 122 34 81 46 113 33 80 31 124 36 83 45 114 35 80 28 125 37 84 42 115 32 81 38 125 38 85 50 115 35 82 25 126 42 85 41 116 36 83 27 126 39 86 45 116 37 84 29 126 43 86 47 116 41 84 24 127 42 87 49 116 38 85 19 128 48 87 40 117 39 86 16 129 41 88 42 117 40 87 43 88 44 117 41 88 42 89 46 117 47 88 48 89 45 118 46 89 45 90 49 118 45 90 47 90 40 119 49 90 49 90 48 119 46 91 44 91 43 120 48 91 46 91 36 121 51 92 45 92 40 121 46 93 46 93 37 122 48 93 50 93 39 122 51 108 47 94 41 122 46 109 46 95 43 122 47 110 50 95 32 123 46 111 47 96 31 124 48 111 49 96 25 126 45 112 48 97 24 127 45 114 50 99 19 128 42 115 47 100 16 129 41 116 50 103 40 117 41 Of 41