ML14294A449

Steam Generator Tube Inservice Inspection Report for the Spring 2014 Refueling Outage

ML14294A449
Person / Time
Site:	Surry
Issue date:	10/16/2014
From:	Lane N Virginia Electric & Power Co (VEPCO)
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
14-508, SPS-LIC/CGL
Download: ML14294A449 (12)

Text

VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 October 16, 2014 United States Nuclear Regulatory Commission Attention: Document Control Desk Washington, DC 20555-0001 Serial No.

SPS-LIC/CGL Docket No.

License No.14-508 RO 50-281 DPR-37 VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNIT 2 STEAM GENERATOR TUBE INSERVICE INSPECTION REPORT FOR THE SPRING 2014 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 2 report for the Spring 2014 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 2 Steam Generator Tube Spring 2014 Refueling Outage Inspection Report for the Commitments made in this letter: None

Serial No.: 14-508 Docket No.: 50-281 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 Ms. K. R. Cotton Gross NRC Project Manager - Surry U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 08 G-9A 11555 Rockville Pike Rockville, Maryland 20852-2738 Dr. V. Sreenivas NRC Project Manager -North Anna U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 08 G-9A 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.: 14-508 Docket No.: 50-281 ATTACHMENT SURRY UNIT 2 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE SPRING 2014 REFUELING OUTAGE VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)

Serial No.: 14-508 Docket No.: 50-281 Attachment Page 1 of 9 SURRY UNIT 2 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE SPRING 2014 REFUELING OUTAGE The following satisfies the Surry Power Station Technical Specification (TS) reporting requirement section 6.6.A.3. During the Surry Unit 2 Spring 2014 End-Of-Cycle 25 (EOC25) refueling outage, Steam Generator (SG) inspections in accordance with TS 6.4.Q were completed for SG B and SG C.

The Unit 2 SGs are in the 4th inspection period which has a duration of 72 Effective Full Power Months (EFPM). The Spring 2014 outage was the second outage of the 4th period.

Unit 2 exceeded 200°F on May 18, 2014; therefore, this report is required to be submitted by November 14, 2014. At the time of this inspection, the current SGs had operated for 316.7 EFPM since the first inservice inspection.

In the discussion below, bold Italicized wording represents TS verbiage and the required information is provided directly below each reporting requirement. A list of acronyms is included at the end of this report.

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, Primary Side A summary of the eddy current tube examinations performed during the outage is provided in Table 1. The only scope expansions required were those necessary to bound foreign objects and foreign object related degradation, as well as to resolve indications.

The primary side work scope also included as-found and as-left visual examinations in the hot and cold leg primary side channel heads in SGs B and C. The examination included the divider plate, welds, cladding, the "mouse-hole" region per NSAL-12-1, previously installed plugs, and manway flanges.

No anomalous conditions associated with these inspections were observed.

Serial No.: 14-508 Docket No.: 50-281 Attachment Page 2 of 9 Table 1 - EOC25 Actual ECT Examination Scope Scope Description Extent SG B SG C Acquired Acquired Bobbin Coil Exams Full Length TEHTEC 3044 3019 H/L CandyCane (Row 3) 07CTEH 94 94 H/L Straight (Row 1-2) 07HTEH 186 182 H/L Straight Restricted 07HTEH 1

C/L CandyCane Restricted 03HTEC 1

C/L Straight Restricted 07CTEC 1

C/L Straight (Row 1-3) 07CTEC 280 275 Array Exams H/L TSH Array (Non-Baffle Plate)

TSH01 H

/ 848 843 H/L TSH Array (Baffle Plate)

TSHBPH

/ 2474 2453 C/L TSC Array (Non-Baffle Plate)

TSCO1.C-848 843 C/L TSC Array (Baffle Plate)

TSCBPC 2474 2453 Full Length Array Exams TECTEH 2

MRPC Exams Ubend +PT (Row 1-2) 07H07C 186 182 MRPC Special Interest

/

H/L Previous Indications

/Various 158 182 H/L Current Indications Various 30 91 Ubend Current Indications Various 0

4 C/L Previous Indications Various 19 8

C/L Current Indications Various 9

44 Indications For MagBias Probe Various 1

2 PLP Bounding 03C 03C03C 23 Bound TSC TSCTSC 8

Bound 03H 03H03H 5

Bound TSH TSHTSH 10 Total 10684 10693 Secondary Side During the Surry Unit 2 EOC25 outage, a visual inspection of upper steam drum moisture separator components, feedring components, and top of bundle U-bend region components through the secondary manway in SG B was performed.

This included all accessible steam drum components and structures, including the feedring exterior, the upper tube bundle, and the 7th tube support plate (TSP) via probe insertions through the primary moisture separators. No adverse conditions were noted during these inspections. Sludge lancing was not performed.

Foreign Object Search and Retrieval (FOSAR) examinations were performed in the SG B and C at the top of the tubesheet, in the annulus, and in the no-tube lane, as necessary.

Serial No.: 14-508 Docket No.: 50-281 Attachment Page 3 of 9

b. Degradation mechanisms found, Degradation mechanisms targeted by the inspection plan included anti-vibration bar (AVB) wear, pitting, foreign object wear, tube support wear, as well as stress corrosion cracking (SCC) at various locations within the steam generator tube bundle. Only AVB wear, foreign object wear, and tube support plate wear were detected during the current outage.

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 Degradation Classification Mechanism Location Probe Type Existing Tube Wear Anti-Vibration Bars Bobbin - Detection and Sizing Bobbin and +PointTM-Detection Existing OD Pitting Top-of-Tubesheet TM-Sizing Bobbin - Detection Existing Tube Wear Tube Support Plate BointTM -

Sion

+Pointm - Sizing Tube Wear Bobbin and +PointTM - Detection Existing (foreign objects)

Freespan and TTS

+PointTM-Sizing Potential ODSCC Hot Leg Top-of-Tubesheet

+PointTM - Detection and Sizing PotetialPWSCC Potential PWSCC Tube Ends N/A*

Bobbin - Detection Potential Tube Wear Flow Distribution Baffle

+PointTMe Sizing Bulges, Dents, Manufacturing ODSCC Anomalies, and Above-

+PointTM - Detection and Sizing Potential PWSCC Tubesheet Overexpansions (OVR)

Potential ODSCC Tubesheet Crevice in TM Tubes With NTEs

+Point

- Detection and Sizing Potential Tube Slippage Within Tubesheet Bobbin Detection Tubesheet Potential PWSCC Overexpansions (OXP)

+PointTM - Detection and Sizing Potential PWSCC Row 1 and 2 U-bends

+PointTM - Detection and Sizing Potential ODSCC Freespan and Tube Supports

+Point

- Sizing

• Inspection not required per technical specification alternate repair criteria.

Serial No: 14-508 Docket No: 50-281 Attachment Page 4 of 9

d. Location, orientation (if linear), and measured sizes (if available) of service induced indications, As stated in item (b) above, service induced indications were identified. Tables 3 and 4 provide the required information.

Table 3 - AVB Indications Depth (%TW)

SG Row Col AVB (ETSS 96004.1)

No.

2011 2014 B

24 57 AVW 17 19 B

31 58 AV2 15 12 B

32 69 AV2 10 7

B 33 60 AV3 12 12 B

35 78 AV3 10 B

37 71 AV3 11 7

B 38 51 AV4 12 15 B

38 74 AV1 10 13 B

38 74 AV2 12 15 B

38 74 AV4 18 B

44 60 AV2 7

7 B

45 57 AV1 9

8 C

24 8

AV4 10 9

C 25 9

AVW 10 8

C 25 9

AV3 10 11 C

25 27 AVW 17 18 C

25 27 AV2 33 32 C

25 27 AV3 12 13 C

25 29 AV2 12 12 C

25 29 AV3 23 26 C

26 26 AV3 18 17 C

26 26 AV4 17 17 C

26 39 AV3 15 20 C

27 84 AV4 11 C

31 65 AV2 10 17 C

31 69 AV2 18 26 C

31 69 AV3 12 20 c

31 75 AV3 12 11 C

31 75 AV4 13 16 C

33 59 AV3 16 21 C

33 59 AV4 10 11 C

33 68 AVI 19 18 C

33 68 AV2 20 20 c

33 69 AV1 10 C

33 68 AV2 13 C

33 70 AVl 10 10 C

33 70 AV3 18 16 Depth (%TW)

SG Row Col AVB (ETSS 96004.1)

No.

2011 2014 C

34 29 AV3 14 11 C

34 29 AV4 18 17 C

34 79 AV1 12 8

C 35 77 AV2 10 10 C

35 77 AV3 10 C

37 63 AV2 11 13 C

37 73 AV3 15 15 C

37 75 AV3 12 12 C

38 28 AVW 11 10 C

38 28 AV3 15 17 C

38 30 AV2 15 12 C

38 43 AV3 11 15 C

38 73 AVW 12 11 C

38 73 AV2 12 9

C 38 74 AV2 12 8

C 39 50 AV3 13 14 C

39 53 AV3 28 30 C

39 55 AV3 13 18 C

39 55 AV3 22 27 C

39 55 AV4 22 26 C

39 71 AV3 12 C

39 72 AV4 10 5

C 40 33 AV2 24 23 C

40 33 AV3 25 23 C

40 63 AV2 11 9

C 40 63 AV3 20 19 C

40 63 AV4 18 19 C

41 64 AV 11 C

41 66 AV3 16 12 C

41 68 AV4 15 10 C

43 39 AV2 13 16 C

43 61 AV1 22 25 C

43 63 AVW 11 14 C

44 61 AVW 10 11 C

46 45 AV2 10 8

Serial No.: 14-508 Docket No.: 50-281 Attachment Page 5 of 9 Table 3 Notes:

Not reported during that outage.

ETSS 96004.1, Rev. 13 sizing parameters:

1)

Total Random Sizing Uncertainty at 95/50:

13.3 %TW

2)

Upper Bound 2014 Depth:

[0.98] x [Field Call] + [2.89] + [13.3]

3)

Spring 2017 Projected Depth:

[Upper Bound 2014 Depth] + [(7.0%TW/Cycle) x 2 Cycles]

Table 4 - Summary of Non-AVB Volumetric Deciradation Identified Max Signal Present Foreign SG Row Col Location ETSS Depth Initially Prior to Current Cause Object Plugged SG Rw Cl Loatin ETS Dpth Reported

(%TW)

Outage?

Remaining Yes, based on lookup.

Foreign B

11 88 03C+0.64 27901.1 26 %TW 2014 Small change since Yes Yes 2011.

Object B

23 82 TSH+0.08 27901.1 21 %TW 2003 Yes. No signal Foreign No No change.

Object B

36 26 TSC+0.04 27905.1 26 %TW 2008 Yes. No signal Foreign No No change.

Object B

37 27 TSC+0.20 27901.1 25 %TVV 2008 Yes. No signal Foreign No No change.

Object Yes. No signal Foreign 42 42 TSC-0.04 27901.1 30 %TW 2014 change based on ObjectNo No lookup.

Object 3C+0.49 96910.1 12 %TW 2011 Yes, in TSP c

3 72 1996 bobbin data.

Wear n/a No 3C+0.50 96910.1 8 %TW 2011 No RPC.

c 28 22 TSH+0.15 27905.1 29 %TW 2014 No wear signal in Foreign No No 2011.

Object TSH+0.51 27901.1 28 %TW 2014 No wear signal in Foreign No No 2011.

Object c

28 23 TSH+0.19 27901.1 28 %TW 2014 No wear signal in Foreign No No 2011.

Object c

28 71 TSH+0.26 27901.1 23 %TW 2009 Yes. No signal Foreign No No change since 1996.

Object Yes, based on lookup.

TSP c

28 84 03H+0.49 96910.1 8 %TW 2014 Unchanged since Wear n/a No 1996.

Yes, based on lookup.

Foreign C

30 74 TSH+6.34 27901.1 20 %TW 2014 Unchanged since ObjectNo No 1996.

Object c

32 36 BPH+0.50 27901.1 19 %TW 2009 Yes. No signal Foreign No No change.

Object

Serial No.: 14-508 Docket No.: 50-281 Attachment Page 6 of 9 Max Initially Signal Present Foreign SG Row Col Location ETSS Depth Reported Prior to Current Cause Object Plugged

(%TW)

Outage?

Remaining C

33 17 TSH+2.65 27901.1 20 %TW 2005 Yes. No signal Foreign No No change.

Object C

34 18 TSH+1.07 27901.1 21 %TW 2005 Yes. No signal Foreign No No change.

Object C

34 20 TSH+0.89 27901.1 26 %TW 2005 Yes. No signal Foreign No No change.

Object C

34 74 TSH+0.14 27901.1 28 %TW 2005 Yes. No signal Foreign No No change.

Object C

35 19 TSH+0.30 27901.1 29 %TW 2005 Yes. No signal Foreign No No change.

Object C

35 22 TSH+0.97 27901.1 28 %TW 2005 Yes. No signal Foreign No No change.

Object C

35 30 TSH+0.12 27901.1 35 %TW 2005 Yes. No signal Foreign No No change.

Object C

36 68 TSH+0.12 27902.1 26 %TW 2005 Yes. No signal Foreign No No change.

Object C

37 31 TSH+0.06 27901.1 25 %TW 2011 Yes, in 1996 3-coil Foreign No No data. No change.

Object C

37 32 TSH+0.03 27901.1 22 %TW 2011 Yes, in 2005 +Point Foreign No No data. No change.

Object C

37 33 TSH+0.01 27901.1 26 %TW 2011 Yes, in 1996 3-coil Foreign No No data. No change.

Object C

37 34 TSH+0.04 27901.1 26 %TW 2009 Yes. No signal Foreign No No change since 1996.

Object C

37 35 BPH+0.60 27901.1 33 %TW 2005 Yes. No signal Foreign No No change.

Object C

37 54 TSH+0.14 27901.1 24 %TW 2005 Yes. No signal Foreign No No change.

Object 7C-0.46 96910.1 20 %TW 2005 C 37 73

_Yes.

Possible TSP C

37 73 signal change.

Wear n/a No 7C-0.55 96910.1 10 %TW 2011 C

38 32 BPH+0.61 27901.1 25 %TW 2011 Yes, present in 2005 Foreign No No bobbin data. No RPC.

Object C

38 53 TSH+0.06 27901.1 22 %TW 2005 Yes. No signal Foreign No No change.

Object BPH+0.64 27901.1 21 %TW 2011 No No C

39 32 Yes, present in 2005 Foreign bobbin data. No RPC.

Object BPH+0.62 27901.1 24 %TW 2011 No No

Serial No.: 14-508 Docket No.: 50-281 Attachment Page 7 of 9 Signal Present Foreign Max Initially Prior to Current Cause Object Plugged SG Row Col Location ETSS Depth Reported o

utae?

(%TW)

Outage?

Remaining Yes, present in 2005 C

39 34 BPH+0.59 27901.1 25 %TW 2011 bobbin data. No RPC.

Foreign No No Object C

40 34 BPH+0.64 27901.1 23 %TW 2011 Yes, present in 2005 Foreign No No bobbin data. No RPC.

Object C

44 42 TSH+0.16 27901.1 24 %TW 2005 Yes. No signal Foreign No No change.

Object C

44 43 TSH+0.23 27901.1 23 %TW 2005 Yes. No signal Foreign No No change.

Object c

44 47 TSH+0.07 27901.1 27 %TW 2005 Yes. No signal Foreign No No change.

Object TSH+0.16 27901.1 23 %TW c

45 43 TSH+0.28 27901.1 24 %TW 2005 Yes. No signal Foreign No No change.

Object TSH+0.73 27901.1 19 %TW C

45 47 TSH+0.16 27901.1 23 %TW 2005 Yes. No signal Foreign No No change.

Object

e. Number of tubes plugged during the mechanism, inspection outage for each degradation One tube was plugged in SG B at Row 11 Column 88 as a result of an eddy current indication of a foreign object with wear at a location that was inaccessible for FOSAR during EOC25.

f. The number and percentage of tubes plugged to date, and the effective plugging percentage in each steam generator.

Table 5 provides the plugging totals and percentages to date.

Table 5 - Tube Plugging Summary Tubes Installed Tubes Plugged To-Date SG A 3,342 30 (0.9%)

SG B 3,342 19(0.6%)

SG C 3,342 46 (1.4%)

Total 10,026 95 (0.9%)

Serial No.: 14-508 Docket No.: 50-281 Attachment Page 8 of 9

g. The results of condition monitoring, including the results of tube pulls and in-situ

testing, None of the tube degradation identified in the Surry Unit 2 SGs during the EOC25 outage violated the structural performance criteria, thereby providing reasonable assurance that none of these flaws would have leaked during a limiting design basis accident.

All degradation identified during the Spring 2014 inspection satisfied condition monitoring requirements for SG tube structural and leakage integrity. Therefore, tube pulls and in-situ pressure testing were not necessary.

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 cycle preceding EOC25, no measurable primary-to-secondary leakage (i.e., >1 GPD) was observed in any Unit 2 SG.

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 and 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 'alue 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 SGs B or C. Note that no bobbin probe examinations were performed in SG A during EOC25. All tubes in SG A were screened for slippage during EOC24 with no indications identified, and the SG A tubes will again be screened during EOC26.

Serial No.: 14-508 Docket No.: 50-281 Attachment Page 9 of 9 ACRONYMS AILPC Accident Induced Leakage Performance Criteria ARC Alternate Repair Criteria AVB Anti-Vibration Bar BET Bottom of Expansion Transition BOC Beginning of Cycle BPC Baffle Plate Cold 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 EFPM Effective Full Power Month 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 MRPC Motorized Rotating Pancake Coil 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 OVR Over Roll OXP Over Expansion 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 Rotating 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