RNP-RA/14-0038, Refueling Outage 28 Steam Generator Tube Inspection Report
| ML14127A066 | |
| Person / Time | |
|---|---|
| Site: | Robinson  |
| Issue date: | 04/29/2014 |
| From: | Peavyhouse S Duke Energy Progress |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| RNP-RA/14-0038 | |
| Download: ML14127A066 (7) | |
Text
Sharon W. Peavyhouse H. B. Robinson Steam Electric Plant Unit 2 KNERGY Director - Nuclear Organization Effectiveness ENERGY Duke Energy Progress 3581 West Entrance Road Hartsville, SC 29550 0: 843 857 1584 F: 843 857 1319 Sharon.Peavyhouse@duke-energy.com TS 5.6.8 Serial: RNP-RA/14-0038 APR 2 9 2014 United States Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555-0001 H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 DOCKET NO. 50-261/RENEWED LICENSE NO. DPR-23 REFUELING OUTAGE 28 STEAM GENERATOR TUBE INSPECTION REPORT Ladies and Gentlemen:
In accordance with the H. B. Robinson Steam Electric Plant (HBRSEP), Unit No. 2, Technical Specifications (TS) Section 5.6.8, "Steam Generator Tube Inspection Report," Duke Energy Progress, Inc., submits the attached report.
The attachment to this letter provides the steam generator tube inspection report information for Refueling Outage 28 (R028) required by TS Section 5.6.8.
There are no regulatory commitments made in this submittal. If you have any questions regarding this submittal, please contact Mr. R. Hightower at (843) 857-1329.
Sincerely, Sharon W. Peavyhouse Director - Nuclear Organization Effectiveness SWP/msc Enclosure Attachment cc:
Mr. V. M. McCree, NRC, Region II Mr. S. P. Lingam; NRC Project Manager, NRR NRC Resident Inspector, HBRSEP, Unit No. 2
United States Nuclear Regulatory Commission Enclosure to Serial: RNP-RA/14-0038 Page 1 of 3 H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 REFUELING OUTAGE 28 STEAM GENERATOR TUBE INSPECTION REPORT Pursuant to H. B. Robinson Technical Specification 5.6.8 the following information is provided:
- a. The scope of inspections performed on each SG The SG Tube Inspection Program included the use of multi-frequency Bobbin Coil Rotating Pancake (PAN), Rotating Plus Point (+Pt) and Array X-Probe (XP) probes.
Bobbin Probe Examination Full length examination with bobbin probe of 50% of in-service tubes, including:
- Tubes adjacent to plugged tubes
" Tubes with prior bobbin/RPC PLP above HTS/CTS
" Tubes with bobbin indications from the prior inspection (R026)
- 2-Sigma tubes identified in the Degradation Assessment
" Tubes planned in the Rows 1-2 and Row 9 U-bend array inspection
- Tubes planned to be preventatively plugged
" Additional tubes to make up a 50% sample Array Probe Examination Examination with array probe (X-probe) of the following:
" Hot leg tubesheet to ist TSP (HTE-O1H) of 100% of in-service tubes
" Cold leg tubesheet to 1st TSP (CTE-01C, or CTE-FBC for tubes in the FBC cutout region) of tubes in a two-tube pattern around the periphery and adjacent to the no-tube lane (i.e. rows 1-2)
- U-bend (06H-06C) of 50% of the in-service tubes in rows 1 and 2
" U-bend (06H-06C) of 20% of the in-service tubes in row 9
- Bobbin dent indications > 4. 0 volts (called in RF026 or the current outage)
- Special interest (bobbin I-codes, PLP)
" Bounding of confirmed PLP (1 tube bounding)
- Array exams not required for secondary side loose parts (per Duke Energy steam generator engineer)
MRPC Probe Examination Examination with MRPC probe:
- U-bend (06H-06C) for tubes in rows 1-2 not able to be inspected due to availability of array probes.
- Selected Indications for technology bridging.
Visual Inspections
- All Plugs were visually inspected
" Primary bowl cladding was visually inspected for all steam generators
- b. Degradation mechanisms found a) Anti-vibration Bar (A VB) wear b) Transient foreign object damage (loose part not present) c) Circumferential Primary Water Stress Corrosion Cracking (PWSCC) at hot-leg tube ends
United States Nuclear Regulatory Commission Enclosure to Serial: RNP-RA/14-0038 Page 2 of 3
- c. Non-destructive examination techniques utilized for each degradation mechanism The Non-destructive examination techniques utilized bobbin coil for the detection of A VB wear and the X probe was utilized to characterize the wear indications.
- d. Location, orientation (if linear), and measured sizes (if available) of service induced indications The complete listing for service-induced indications is attached.
- e. Number of tubes plugged during the inspection outage for each active degradation mechanism A total of four tubes were plugged. The four tubes had been identified for plugging due to previously identified manufacturing imperfections as required to support the H* licensing requirements. No tubes were recommended for repair due to current inspection results.
- f. The number and percentage of tubes plugged to date, and the effective plugging percentage in each steam generator The HBRSEP, Unit No. 2, steam generators were replaced in 1984 with Westinghouse Model 44F steam generators with alloy 600 thermally treated tubes. The current analysis supports up to 6% tube plugging. Prior to RO-28 there were 44 plugged tubes. With the 4 tubes plugged in RO-28 there are a total of 48 plugged tubes out of a population of 9642 for the three steam generators. This brings the total plugging to 0.5% as compared to the analysis limit of 6%.
Steam A
B C
Total Generator*
Plugs present 7
21 16 44 prior to EOC 28 Plugs added in 2
2 0
4 EOC 28 Total Plugs 9
23 16 48
% Plugged 0.3 10.7 0.5 0.5
- There are 3214 tubes per generator.
- g. The results of condition monitoring, including the results of tube pulls and in-situ pressure testing The condition monitoring report describes a condition monitoring and operational assessment evaluation for Robinson Unit 2 at R028. The evaluation was performed according to NEI 97-06 using the recommended practices of the EPRI Steam Generator Integrity Assessment Guidelines. The degradation forms evaluated at R028 were wear at A VB locations and wear due to foreign objects at the top of tubesheet and near tube support plates. PWSCC degradation near HL tube ends was detected and is covered separately in an NRC-approved alternate repair criterion.
The worst case AVB wear Non-destructive Examination (NDE)depth projected for R028 in the R026 Condition Monitoring and Operational Assessment (CMOA) was 35 %TW. The deepest AVB wear indication actually seen during R028 was 28 %TW. Foreign object wear was predicted to grow minimally in the
United States Nuclear Regulatory Commission Enclosure to Serial: RNP-RA/14-0038 Page 3 of 3 R026 CMOA. This was true of wear indications that were detected during R026.
But as expected, several new instances of foreign object wear were detected at R028. The largest foreign object wear indication detected at R028 was 34
%TW. No foreign objects remain at locations with wear. Therefore, the previous operational assessment was conservatively bounding for all wear types observed in R026 and R028.
All condition monitoring requirements were met. Projected End of Cycle (EOC) 30 worst case burst pressures meet the limiting structural integrity performance requirement of three times normal operating pressure of 4,350 psi with at least 0.95 probability with 50% confidence. There is no leakage projected at normal operating pressure or accident conditions at R030. Operational assessment structural and leakage integrity requirements are demonstrated.
Primary bowl cladding inspections identified no abnormal conditions.
Plug visual inspections identified no abnormal conditions.
No in-situ pressure testing was required. No tube pulls were performed.
- h. Evaluation of Primary to Secondary Leakage Rate There was no leakage within detectable limits.
- i.
The calculated accident induced leakage rate from the portion of the tubes below 18.11 inches from the top of the tubesheet for the most limiting accident in the most limiting SG.
There was no leakage within detectable limits and no calculated leakage.
- j.
The results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.
No tube slippage was identified.
United States Nuclear Regulatory Commission Attachment to Serial: RNP-RA/14-0038 Page 1 of 3 SG -
A Service Induced Degradation H.B. Robinson 2 RF028 RNP 20131001 11/11/2013 10:09:52
+---------------------,-----+-----+-----+-----+----+---+-
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I Tubes: 16 Records: 16 ST Max
United States Nuclear Regulatory Commission Attachment to Serial: RNP-RA/14-0038 Page 2 of 3 SG - B Service Induced Degradation H.B. Robinson 2 RF028 RNP 20131001 11/11/2013 10:13:24
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+--------------------+-----+-----+-----,-----+----+---+-
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1 Tubes: 25 Records: 26 ST Hex
United States Nuclear Regulatory Commission Attachment to Serial: RNP-RA/14-0038 Page 3 of 3 SG -
C Service Induced Degradation H.B. Robinson 2 RF028 RNP 20131201 11111/2013 10:16:29
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+--------------------+-----+-----+-----+-----+----+---+-
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ROW COL VOLTS DEG IND0 PER CHN LOCN INCHI INCH2 UTILI UTIL2 BEGT ENDT POIA PTYPE CAL LI
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1 Tubes: 27 Records:
31 ST Max