ML14135A365
| ML14135A365 | |
| Person / Time | |
|---|---|
| Site: | Surry  (DPR-032) |
| Issue date: | 05/06/2014 |
| From: | Lane N Virginia Electric & Power Co (VEPCO) |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| 14-209 | |
| Download: ML14135A365 (11) | |
Text
VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 May 6, 2014 United States Nuclear Regulatory Commission Attention: Document Control Desk Washington, DC 20555-0001 Serial No.
SPS-LIC/CGL Docket No.
License No.14-209 R1 50-280 DPR-32 VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNIT 1 STEAM GENERATOR TUBE INSERVICE INSPECTION REPORT FOR THE FALL 2013 REFUELING OUTAGE Technical Specification 6.6.A.3 for Surry Power Station Units 1 and 2 requires the submittal of a Steam Generator Tube Inspection Report to the NRC within 180 days after Tavg exceeds 200°F following completion of an inspection performed in accordance with Technical Specification 6.4.Q, Steam Generator Program. Attached is the Surry Unit 1 report for the Fall 2013 refueling outage.
If you have any questions concerning Mrs. Candee G. Lovett at (757) 365-2178.
this information, please contact Very truly yours, N. L. Lane Site Vice President Surry Power Station
Attachment:
Surry Unit 1 Steam Generator Tube Inspection Report for the Fall 2013 Refueling Outage Commitments made in this letter: None
Serial No.: 14-209 Docket No.: 50-280 Page 2 of 2 cc:
U.S. Nuclear Regulatory Commission Region II Marquis One Tower 245 Peachtree Center Avenue NE Suite 1200 Atlanta, Georgia 30303-1257 Dr. V. Sreenivas NRC Project Manager - Surry and North Anna U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 08 G9A 11555 Rockville Pike Rockville, Maryland 20852-2738 NRC Senior Resident Inspector Surry Power Station Mr. R. A. Smith Authorized Nuclear Inspector Surry Power Station
Serial No.: 14-209 Docket No.: 50-280 ATTACHMENT SURRY UNIT 1 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2013 REFUELING OUTAGE VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)
Serial No.: 14-209 Docket No.: 50-280 Attachment Page 1 of 7 SURRY UNIT I - FALL 2013 STEAM GENERATOR INSPECTIONS
[END-OF-CYCLE 25 (EOC25) / REPLACEMENT-END-OF-CYCLE 20 (REOC20)]
The following satisfies the Surry Power Station Technical Specification (TS) reporting requirement of TS 6.6.A.3.
During the Surry Fall 2013 refueling outage, steam generator (SG) inspections in accordance with TS 6.4.Q were completed for SG B.
This was the first inspection in the 4th inspection period which has duration of 72 effective full power months (EFPM).
Surry Unit 1 exceeded 200'F on November 18, 2013; therefore, this report is required to be submitted by May 19, 2014. The SGs had operated for 300.9 EFPM at the time of this inspection.
Bold italicized wording represents TS verbiage. The required information is provided under each reporting requirement as follows:
A report shall be submitted within 180 days after Tavg exceeds 200°F following completion of an inspection performed in accordance with the Specification 6.4.Q, "Steam Generator (SG) Program." The report shall include:
- a. The scope of inspections performed on each SG.
A summary of the eddy current tube examinations performed during the outage is provided in Table 1.
The primary side inspection activities performed in SG B also included a video/visual examination of both channel heads (as-found/as-left), specifically including the plugs, the divider plate weld region, and the bottom of the bowl per Nuclear Safety Advisory Letter NSAL-12-1 with the bowl dry. No anomalous conditions associated with these inspections were found.
Serial No.: 14-209 Docket No.: 50-280 Attachment Page 2 of 7 Table 1 - EOC25 Actual ECT Examination Scope SG B Scope Description Extent Tested Bobbin Coil Exams Full Length TEHTEC 3043 H/L Straight (Row 1-2) 7HTEH 179 H/L Candycane (Row 3) 7CTEH 93 H/L Candycane Restricted (Row 3 C20) 7HTEH*
1 C/L Straight (Row 1-3) 7CTEC 273 Array Exams H/L TSH Array (Non-Baffle Plate)
TEH1H 841 H/L TSH Array (Baffle Plate)
TEHBPH 2475 C/L TSC Array (Non-Baffle Plate)
TEC1IC 841 C/LTSC Array (Baffle Plate)
TECBPC 2475 Additional Array Exams Various 2
MRPC Exams Ubend +PT (Row 1-2) 7H7C 178 Ubend +PT Restricted Row 1-2) 7H7C 1
Ubend +PT Restricted (R3C20) 7H7C 1
MRPC Special Interest H/L Previous WARNOL Various 10 H/L Previous MBH Various 20 H/L Previous DNT >2V (50% Sample + 5 Largest Volts)
Various 73 H/L Bobbin/Array Indications Various 47 UB Previous DNT >2V (Largest Volts)
Various 2
UB Bobbin Indications Various 4
CL Previous DNT >2V (Largest Volts)
Various 3
CL Bobbin/Array Indications Various 27 H/L Select Tube +PT (TS Anomalies)
TSHTSH 40 Select Tube +PT Various 8
- dented tube location Total 1 10637 The following secondary side exams were conducted in SGs B and C:
Visual examination, from the steam drum in SGs B and C, of the accessible steam drum components and structures, including the feedring exterior, the upper tube bundle, and the 7th tube support plate (TSP) via probe drops through the primary moisture separators. No adverse conditions were noted during these inspections.
Serial No.: 14-209 Docket No.: 50-280 Attachment Page 3 of 7
- b. Degradation mechanisms found.
Degradation mechanisms targeted by the inspection plan included anti-vibration bar (AVB) wear, pitting, foreign object wear, tube support wear, and stress corrosion cracking (SCC) at various locations within the SG tube bundle.
AVB wear and foreign object wear were detected.
- c. Nondestructive examination techniques utilized for each degradation mechanism.
The inspections focused. on the degradation mechanisms listed in Table 2 utilizing the referenced eddy current techniques.
Table 2 - Inspection Method for Applicable Degradation Modes Classification Degradation Location Probe Type Mechanism Bobbin - Detection Existing Tube Wear Anti-Vibration Bars Bobbin and +PointTM -
Sizing Bobbin - Detection Existing Tube Wear Tube Support Plate Bobbin and +PointTM -
Sizing Tube Wear Bobbin and Array - Detection (foreign objects)
+PointTM - Sizing Hot Leg Top-of-Tubesheet Bobbin and Array - Detection Sludge Pile Area
+PointTM - Sizing At the Tube ends Inspection not required per TE + 4 Inches PARC Existing PWSCC Hot Leg Top-of-Tubesheet Array - Detection and Sizing Bobbin - Detection Existing OD'Pitting Top-of-Tubesheet
+PointTM - Sizing Bobbin - Detection Potential Tube Wear Flow Distribution Baffle Bobbin and +PointTM -
Sizing Array - Detection Potential ODSCC Freespan and Tube Supports Array Sizn
+PointTM - Sizing Potential PVWSCC Hot Leg Within Tubesheet Array - Detection Anomaly Locations
+PointTM - Sizing
Serial No.: 14-209 Docket No.: 50-280 Attachment Page 4 of 7
- d. Location, orientation (if linear), and measured sizes (if available) of service induced indications.
As stated in the (b) response above, wear type indications were noted (i.e., AVB wear and foreign object wear).
Tables 3 and 4 provide detailed information regarding these indications.
Table 3 - AVB Indications SG Row Col AVB Depth (%TW)
No.
(ETSS 96004.1) 2010 2013 B
22 72 AV3 13 B
26 61 AV3 10 15 B
27 53 AV2 14 B
28 66 AV2 11 B
31 33 AV2 17 14 B
32 26 AV3 10 8
B 34 58 AV2 20 24 B
34 58 AV3 15 19 B
34 79 AV3 10 B
35 17 AVI 13 B
35 17 AV2 11 11 B
35 17 AV3 19 22 B
36 33 AV3 10 B
36 65 AV4 11 B
38 22 AV2 10 11 B
39 36 AV3 10 6
B 39 66 AV1 11 B
40 25 AV2 18 16 B
40 26 AV2 10 9
B 41 27 AV2 11 13 B
41 27 AV3 11 13 B
42 29 AV2 15 15 B
42 30 AV2 13 14 B
42 30 AV3 12 10 B
43 32 AV2 13 B
43 34 AV3 12 6
B 46 45 AV2 15 20
- Not reported during that outage.
Notes:
ETSS 96004.1, Rev. 13 sizing parameters:
- 1) Total (technique + analyst) Random Sizing Uncertainty at 95/50: 13.3 %TW
- 2) Upper Bound 2013 Depth: [0.98] x [Field Call] + [2.89] + [13.3]
- 3) Fall 2016 Projected Depth: [Upper Bound 2013 Depth] + [(6.5%TW/Cycle) x 2 Cycles]
Serial No.: 14-209 Docket No.: 50-280 Attachment Page 5 of 7 Table 4 - Summary of Non-AVB Wear Volumetric Degradation Max Axial Circ.
Foreign SG Row Col Location ETSS Depth Length Length Signal Present Prior to Current Outage?
Cause Object S(%TW)
(in)
(In_ Reported Remaining?
B 1
7 TSH+0.17" 21998.1 22 0.71 0.37 2007 Yes. No change since initially reported.
Historical SG N/A I
3Maintenance B
31 15 BPH+0.59" 27901.1 19 0.29 0.43 2010 Yes. No change since initially reported.
Foreign Object No B
31 16 BPH+0.59" 27901.1 22 0.31 0.48 2010 Yes. No change since initially reported.
Foreign Object No B
32 15 BPH+0.59" 27901.1 19 0.23 0.37 2010 Yes. No change since initially reported.
Foreign Object No B
32 18 BPH+0.59" 27901.1 19 0.26 0.43 2010 Yes. No change since initially reported.
Foreign Object No B
33 18 BPH+0.61" 27901.1 20 0.29 0.51 2010 Yes. No change since initially reported.
Foreign Object No B 35 20 BPH+1.09' 27902.1 16.0.65 0.53 2010 Yes. No change since initially reported.
Foreign Object No Yes. Indication present in 1994 but not Small Volumetric B
37 31 4H-24.06" 21998.1 7
0.26 0.32 2013 reported until array exam in 2013.N/A e ui since 1994 B
40 50 TSH+0.40" 27901.1 30 0.37 0.48 2007 Yes. No change since initially reported.
Foreign Object No B
40 51 TSH+0.34" 27901.1 32 0.31 0.48 2007 Yes. No change since initially reported.
Foreign Object No B
41 51 TSH+0.10" 27901.1 24 0.29 0.32 2007 Yes. No change since initially reported.
Foreign Object No Yes. Indication present in 1992 and 45 48 TSc+2.85" 21998.1 30 0.35 0.37 2013 reported as NQH since 1994 but not with no change N/A reported as VOL until array exam in since 1994 2013.
- e. Number of tubes plugged during the inspection outage for each degradation mechanism.
No tubes required plugging as a result of SG inspections performed during the EOC25 outage.
- f. The number and percentage of tubes plugged to date, and the effective plugging percentage in each steam generator.
The effective plugging percentage for the Surry Unit 1 SGs to date is identified in Table 5.
Table 5 - Tube Plugging Summary TubesInstlled Effective Plugging Percentage To-Date SG A 3,342 44(1.3%)
SG B 3,342 26(0.8%)
SG C 3,342 36(1.1%)
Total 10,026 106 (1.1%)
Serial No.: 14-209 Docket No.: 50-280 Attachment Page 6 of 7
- g. The results of condition monitoring, including the results of tube pulls and in-situ testing.
The condition monitoring assessment of the EOC25/REOC20 structural and leakage integrity concluded that the Surry Unit 1 SGs, as indicated by the results of the primary and secondary side inspections performed during this outage, satisfy required structural and leakage integrity criteria. Therefore, there was no need to pull tubes or in-situ test.
- h. The primary to secondary LEAKAGE rate observed in each SG (if it is not practical to assign the LEAKAGE to an individual SG, the entire primary to secondary LEAKAGE should be conservatively assumed to be from one SG) during the cycle preceding the inspection which is the subject of the report.
Routine primary-to-secondary leak monitoring is conducted in accordance with station procedures. During the past operating cycle, no measurable primary-to-secondary leakage
(>1 GPD) was observed.
- i. The calculated accident induced LEAKAGE rate from the portion of the tubes below 17.89 inches from the top of the tubesheet for the most limiting accident in the most limiting SG.
In addition, if the calculated accident induced LEAKAGE rate from the most limiting accident is less than 1.80 times the maximum operational primary to secondary LEAKAGE rate, the report should describe how it was determined.
The permanent alternate repair criteria (PARC) requires that the component of operational leakage from the prior cycle from below the H-star distance be multiplied by a factor of 1.8, added to the total accident leakage from any other source, and compared to the allowable accident induced leakage limit.
Since there is reasonable assurance that no tube degradation identified during this outage would have resulted in leakage during an accident, the contribution to accident leakage from other sources is zero. Assuming that the prior cycle operational leakage of <1 GPD originated from below the H-star distance, and multiplying this leakage by a factor of 1.8 as required by the PARC, yields an accident induced leakage value of <1.8 GPD. This value is well below the 470 GPD limit for the limiting SG and provides reasonable assurance that the accident induced leakage performance criteria would not have been exceeded during a limiting design basis accident.
- j.
The results of the monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.
No indications of tube slippage were identified during the evaluation of bobbin probe examination data from SG B. No eddy current examinations were performed in SGs A or C during EOC25. The tubes in SGs A and C were screened for slippage during EOC24 with no slippage identified and will be screened again during EOC26.
Serial No.: 14-209 Docket No.: 50-280 Attachment Page 7 of 7 ACRONYMS AILPC Accident Induced Leakage Performance Criteria ARC Alternate Repair Criteria AVB Anti-Vibration Bar BET Bottom of Expansion Transition BOC Beginning of Cycle BPH Baffle Plate Hot CDS Computer Data Screening C/L Cold Leg CM Condition Monitoring Assessment DA Degradation Assessment DMT Deposit Minimization Treatment DNT Dent ECT Eddy Current Test EOC End of Cycle ETSS Examination Technique Specification Sheet FAC Flow Assisted Corrosion FDB Flow Distribution Baffle FK Foreign Object Identifier FOSAR Foreign Object Search and Retrieval GPD Gallons per Day H/L Hot Leg LAR Lead Analyst Review LPR Loose Part Removed (New Code)
MBH Manufacturing Brandishing Mark in History NQH Non Quantifiable History NSAL Nuclear Safety Advisory Letter NTE No Tube Expansion OA Operational Assessment OD Outer Diameter ODSCC Outer Diameter Stress Corrosion Cracking PDA Percent Degraded Area PLP Possible Loose Part POD Probability of Detection PTE Partial Tube Expansion PWSCC Primary Water Stress Corrosion Cracking QDA Qualified Data Analyst REOC Replacement End of Cycle RPC Rotatingl Pancake Coil (also a generic term for rotating probes of any kind)
SCC Stress Corrosion Cracking SG Steam Generator SIPC Structural Integrity Performance Criteria SSI Secondary Side Inspection TEC Tube End Cold TEH Tube End Hot TSC Tube Sheet Cold TSH Tube Sheet Hot TSP Tube Support Plate TTS Top of Tubesheet TW Through Wall UB U-Bend WAR Wear VLP Visually Confirmed Loose Part/Foreign Object (New Code)
VOL Volumetric
Serial No.: 14-209 Docket No.: 50-280 SPS 1 Fall 2013 RFO SG Tube Inspection Report bc page 1 of 1 bc:
(* paper copy; remainder electronic distribution)
Mr. D. C. Lawrence - SPS Mr. J. R. Daugherty - NAPS Ms. L. J. Armstrong - MPS Mr. J. T. Stafford - KPS Mr. B. A. Garber - SPS Mr. P. A. Kemp - NAPS Mr. W. D. Bartron - MPS Mr. R. P. Repshas - KPS Mr. J. Henderson - SPS Mr. E. J. Turko-SPS Mr. T. M. Mayer - SPS Mr. P. Aitken - IN3SE Ms. V. L. Armentrout - IN3SE Mr. D. A. Sommers - IN2SE Mr. G. D. Miller-IN2SE Ms. C. G. Lovett - SPS MSRC Coordinator - IN2SE Corporate Licensing File - Ms. V. Hull - IN2SE*
Records Management - c/o Ms. V. Hull - IN2SE*
CONCURRENCE See Station Correspondence Review and Approval Form VERIFICATION OF ACCURACY
- 1. 3/26/2014 8:10 AM e-mail from Todd Mayer to Candee Lovett, Ed Turko, and Viki Armentrout -
Subject:
SPS1-180 Day Report Fall 2013 Draft Corrected and attached file titled SPS1-180DayRpt Fall2013 Final.doc (attached)
- 2. 4/29/2014 7:35 AM e-mail to Candee Lovett -
Subject:
U1 RF025 120 [180] Day Report and attached file titled Long Term Plan 4-25-2014 AMB.docx (attached)
ACTION PLAN/COMMITMENTS (STATED OR IMPLIED)
None REQUIRED CHANGES TO THE UFSAR, ISFSI UFSAR OR THE TOPICAL REPORT None