ML16141A117

Inspection Report for the Fall 2015 Refueling Outage

ML16141A117
Person / Time
Site:	Surry
Issue date:	05/10/2016
From:	Lawrence D C Virginia Electric & Power Co (VEPCO)
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
16-196
Download: ML16141A117 (17)

Text

VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 May 10, 2016 United States Nuclear Regulatory Commission Attention:

Document Control Desk Washington, DC 20555-0001 VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNIT 2 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2015 REFUELING OUTAGE Serial No. SPS-LIC/CGL Docket No.

• License No.16-196 RO 50-281 DPR-37 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 T avg 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 Fall 2015 refueling outage. If you have any questions concerning this information, please contact Mrs. Candee G. Lovett at (757) 365-2178.

Douglas Lawrence Director S ation Safety & Licensing Surry Power Station

Attachment:

Surry Unit 2 Steam Generator Tube Inspection Report for the Fall 2015 Refueling Outage Commitments made in this letter: None 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.: 16-196 Docket No.: 50-281 Page 2 of 2 ATTACHMENT 1 SURRY UNIT 2 Serial No.: 16-196 Docket No.: 50-281 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2015 REFUELING OUTAGE VIRGINIA ELECTRIC AND POWER COMAPNY (DOMINION)

SURRY UNIT 2 Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 1 of 14 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2015 REFUELING OUTAGE The following satisfies the Surry Power Station Technical Specification (TS) reporting

• requirement section 6.6.A.3 .. During the Surry Unit 2 Fall 2015 refueling outage (RFO), steam generator (SG) inspections in accordance with TS 6.4.Q were completed for SG A and SG C. This was the third inspection in the 4th inspection period which has a duration of 72 effective full power months (EFPM). Surry Unit 2 exceeded 200°F on November 28, 2015; therefore, this report is required to be submitted by May 26, 2016. At the time of this inspection, the Unit 2 SGs had operated for 333.0 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 attac;;hed at the end of this report. " A report shall be submitted Within 180 days after Tavg exceeds following completion of an inspection performed in accordance with the Specification 6.4.Q, "Steam Generator (SG)Program.

11 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 in Table 1.

• The only scope expansions required in SG A and SG C were those ne.ce§sary.

to bound foreign objects and foreign object related degradation, *as well as to resolve ;;:imbig1,.1ous indications.

The inspection scope. was expanded into SG B based on the findil'.lg of circumferential primary water stress corrosion cracking (PWSCC) within the-hot leg tubesheet of SG C (see item e below for more detail). The eddy current scope in SG B was focused on the detection of stress corrosion cracking (SCC) in susceptible locations in the hot leg tubesheet; therefore, a 50% sample of the hot leg tubesheet locations with array probes was examined.

No bobbin inspections or cold leg tubesheet inspections were performed.

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 A, 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 abnormal or degraded conditions were identified from these examinations. ,}

Secondary Side Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 2 of 14 During the Surry Unit 2 Fall 2015 RFO , 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 A was performed.

This included all accessible steam drum components and structures , including the feedring exterior, the upper tube bundle, and ?'h tube support plate (TSP) via probe insert i ons through the primary moisture separators. No degradation or adverse conditions were noted during these inspections. Sludge lancing was performed in all three SGs. Foreign Object Search and Retrieval (FOSAR) examinations were performed in SGs A , B , and C at the top of t he tubesheet , in the annulus, and in the no-tube lane as necessary. Table 1 -Eddy Current Testing Examination Scope Scope Description Extent SGA SG SGC B Bobbin Coil Exams Full Length TEHTEC 2849 2831 H/L CandyCane (Row 3-5) 07CTEH 278 282 H/L Straight (R 1-2) 07HTEH 185 182 H/L Straiqht Restricted 07HTEH 1 C/L CandyCane Restricted 02HTEC 1 C/L Straight Restricted 07CTEC 1 2 C/L Straight (R1-5) 07CTEC 462 463 Array Exams H/L TSH Array (Non-Baffle Plate) TSH01H 834 444 843 H/L TSH A r ray (Baff l e Plate) T SHBPH 2478 1260 2453 C/L TSC Array (Non-Baffle Plate) TSC01C 834 842 C/L TSC Arra y (Baffle Pla t e) TSCBPC 2478 2453 MRPC Exams Ubend +Poin tŽ (Row 1-2) 07H07C 185 182 MRPC S pe c i a l Interes t H/L Previo u s I ndications Various 120 172 H/L Previous Restricted 02H03 1 C/L Previous Restricted Various 8 H/L Current Indications Various 97 7 92 Ubend Current Indications Various 2 1 C/L Previous Indications Various 8 7 C/L Current Indications Various 36 20 Indications For Mag8ias Probe Various 1 2 Additional RPC TEHTSH 2 Total 10848 1713 10838

b. Degradation mechanisms found Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 3 of 14 Degradation mechanisms targeted by the inspection plan included anti-vibration bar (AVB) wear, pitting, foreign object wear, tube support wear and sec at various locations within the steam generator tube bundle. AVB wear, foreign object wear, tube support plate wear, and PWSCC were detected during the current outage. c. Nondestructive examination techniques utilized for each degradation mechanism The inspection program focused on the degradation mechanisms listed in Table 2 and utilized the referenced eddy current techniques.

Table 2 -Inspection Method for Applicable Degradation Modes .. *Degradation

' Classification.'

Mechanism,

• Loi;ation Probe Type. .. ""' . . . . .. : '"

,,:.' "*-' ... Existing Tube Wear Anti-Vibration Bars Bobbin -Detection and Sizing Existing OD Pitting Top-of-Tubesheet Bobbin and +PointŽ-Detection

+PointŽ -Sizing Existing Tube Wear Tube Support Plate Bobbin -Detection

+PointŽ -Sizing Existing Tube Wear Freespan and TIS Bobbin and +PointŽ -Detection (foreign objects) +PointŽ -Sizing Potential ODSCC Hot Leg Top-of-Tubesheet

+PointŽ -Detection and Sizing PWSCC Potential PWSCC Tube Ends NIA* Potential Tube Wear Flow Distribution Baffle Bobbin -Detection

+PointŽ -Sizing Bulges, Dents, Manufacturing Potential ODSCC Anomalies, and Above-+PointŽ -Detection and Sizing PWSCC Tubesheet Overexpansions (OVR) Potential ODSCC Tubesheet Crevice in +PointŽ -Detection and Sizing Tubes With NTEs Potential Tube Slippage Within Tubesheet Bobbin Detection Potential PWSCC Tubesheet

+PointŽ -Detection and Sizing Overexpansions (OXP) Potential ODSCC Row 1 and 2 Li-bends +PointŽ -Detection and Sizing PWSCC Potential ODS CC Freespan and Tube Supports Bobbin -Detection

+PointŽ -Sizing *Inspection not required per technical specification alternate repair criteria.

Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 4of14 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 through 6 provide information regarding these indications.

Table 3 -AVB Indications for SG A SGA 25 57 AV2 16 21 SGA 26 ' 9 AV4 12 10 I SGA 26 ' 86 AV3 17 21 SGA 29 28 AV3 NR 13 SGA 29 70 AV2 11 11 SGA 30 12 AV1 10 10 , ,,;:-... $GA 30 64 AV2 7 8 ----* SGA 33 26 AV4 NR 12 SGA 36 62 AV2 24* 21 I SGA 36 62 AV3 14 16 SGA 36 62 AV4 27 31 SGA 36 66 AV2 12 16 I SGA 36 66 ' AV3 " 10 13 i *' *:.::* . . -..... -SGA 37 20 AV1 13 12 .. --* -SGA 37 20 AV4 12 10 SGA 38 57. AV1 13 13 SGA 38 70 AV3 NR 11 SGA 38 72 AV4 23 26 SGA 38 74 AV4 17 22 SGA 40 25 AV4 12 8. SGA 40 49 AV1 11 15 SGA 40 49 AV2 10 10 SGA 40 49 AV3 11 11 SGA 40 65 AV2 18 21 SGA 40 65 AV3 10 15 SGA 40 65 AV4 10 9 SGA 40 66 AV3. 9 14 " -**--.....

-*

-*-b

• tlli (°AT\IW ** '/i: *.eP.':* o* .... *:**** '* ETSS '96041':1

',*

*;)2012: ..

• 201,:s .. SGA 42 62 AV3 NR 10 SGA 44 35 AV1 NR 10 SGA 44 38 AV2 11 9 SGA 45 44 AV2 11 11 SGA 46 45 AV1 13 10 NR =Not Reported during the previous outage Table 4 -AVB Indications for SG C :::):*:: .....

j-r**"' .,, : J, ' "

(% TW).*. * **

L -,.SG.-. " -_;. ' .

ETSs,' 96041'..:l Row Col '\

' ' ' _,._-No. ' ': : ; ' ' . 20tf5'; . **;<<.*' ._: ..... *;**. SGC 24' 8 AV4 9 10 SGC 25 9 AV1 8 8 SGC 25 9 AV3 11 10 SGC 25 27 AV1 18 17 SGC . 25 27 AV2 32 32 SGC 25 27 AV3 13 12 SGC 25 29 AV2 12 8 -SGC 25 29 AV3 26 20 SGC 26 26 AV3 17 19 SGC 26 26 AV4 17 17 -SGC 26 39 AV3 20 15 SGC 27 84 AV4 11 7 SGC 31 65 AV2 17 13 SGC 31 69 AV2 26 19 SGC 31 69 AV3 20 17 SGC 31 75 AV3 11 13 SGC 31 75 AV4 16 13 SGC 33 59 AV3 21 19 SGC 33 59 AV4 11 12 SGC 33 67 AV3 NR 10 Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 5 of 14 T

---.... . ..;.....

,, " " ' ,"*" -**

\: . .Row **-Col . *,*. __ ,. -.*>< ' ,,_*No.*** . ' . ' *, :: . ': ' ' ' ,,, ,; '! ;:.'*:> .;.. SGC 33 68 AV1 SGC 33 68 AV2 SGC 33 69 AV1 SGC. 33 69 AV2 SGC 33 70 AV1 SGC 33 70 AV3 SGC 34 29 AV3 SGC 34 29 AV4 SGC 34 79 AV1 SGC 35 77 AV2 SGC 35 77 AV3 SGC 37 63 AV2 SGC 37 73 AV3 SGC 37 75 AV3

• SGC. 38 28 AV1 SGC 38 28 AV3 SGC 38 30 AV2 SGC 38 43 AV3 SGC *38 73 AV1 SGC 38 73 AV2 SGC 38 74 AV2 SGC 39 50 AV3 SGC 39 ' 53 AV3 SGC 39 55 AV3 SGC 39 55 AV3 SGC ' 39 55 AV4 SGC 39 71 AV3 SGC 39 72 AV4 SGC 40 33 AV2 SGC 40 33 AV3 SGC 40 63 AV2 SGC 40 63 AV3 SGC 40 63 AV4 ' . c:>ep111:4,(%

ffl):. *.

• ETSS. 9604 t .. * -: ; ,::2012 ,:, '20f5. 18 20 20 19 10 9 13 11 10 8 16 16 11 12 17 16 8 11 10 11 10 10 13 11 15 17 12 11 10 7 17 14 12 13 15 11 11 9 9 8* 8 8 14 13 30 28 27 25 18 12 26 25 12 8 5 10 23 24 23 25 9 9 19 15 19 16 Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 6of14 -ii

--Y.;,.:-, ....... *:-11. , .. .[., .... :;. .. :;;,; ('. -r;-

., .,.:.

.* AVB Depth (% TW) . **s8 Row Col No. ' E:TSS 96041.1 * ' ' ' . 201'2 2015 SGC 41 35 AV3 NR 11 SGC 41 64 AV1 11 9 SGC 41 . 66 AV3 12 14 SGC 41 68 AV4 10 10 SGC 43 39 AV2 16 13 SGC 43 61 AV1 25 22 SGC 43 63 AV1 14 15 SGC 44 61 AV1 11 10 SGC 45 58 AV3 NR 13 SGC 46 45 AV2 8 11 SGC 46 45 AV3 NR 10 SGC 46 46 AV1 NR 10 SGC 46 46 AV2 NR 12 SGC 46 46 AV3 NR 13 SGC 46 46 AV4 NR 10 NR = Not Reported du!"ing the previous outage Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 7 of 14

'

':.bi l.'.\ ',c-113; ,, c;:

' .* . . .. SG Row Col Location . . TSC+0.82 A 4 37 TSC+1.81 A 6 60 5H-0.59 A 11 45 TSH+0.96 A 15 16 TSH+0.23 A 17 16 TSH+0.04 A 18 16 TSH+0.02 A 32 27 TSC+0.02 A 33 27 TSC+0.12 A 39 24 TSH+0.45 A 42 52 TSC+0.26 A 43 61 BPH+0.56 A 43 64 BPH+0.62 Table 5 -Summary of Non-AVB Volumetric Degradation Identified

.* '" k . Signal Present prior to . . *

• Foreign ... ETSS Initially Cause Object {f,oTW) Repor;ted

• ,, Current Outage? Remaining?

I*, . ' .. *. ' ... 27901.1 20%TW 2015 Yes. No signal change Foreign No since 1995. Object 27901.1 27%TW 2015 Yes. No signal change Foreign No since 1995. Object 96910.1 13%TW 2009 Yes. No signal TSP Wear N/A change since 2002. 27901.1 27%TW 2012 Yes. No signal Foreign No change since 2006. Object 27901.1 25%TW 2012 No signal present Foreign No in 2006 exam. Object 27901.1 31 %TW 2002 Yes. No signal Foreign No change. Object 27901.1 30%TW 2002 Yes. No signal Foreign No change. Object 27901.1 20%TW 2006 Yes. No signal Foreign No change. Object 27901.1 25%TW 2006 Yes. No signal Foreign No change. Object 27901.1 20%TW 2009 Yes. No signal Foreign No change since 2006. Object 27901.1 20%TW 2009 Yes. No signal change Foreign No since 2009. Object 27901.1 23%TW 2009 Yes. No signal Foreign No change since 2002. Object .. Yes. Possible minor Foreign 27901.1 '24%TW 2009 sigriai'\;iiange 2002 to No 2009. No change since. Object Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 8of14 Plugged? ' No No No No No No No No No No No No 1.1 ' '*Max Depth SG Row Col Location ETSS Initially***

(%TW) ,

3C+0.47 96910.1 4%TW 2011 c 3 72 3C+0.48 96910.1 2%TW 2011 c 28 22 TSH+0.17 27901.1 29%TW 2014 TSH+0.52 27901.1 29%TW 2014 c 28 23 TSH+0.21 27901.1 29%TW 2014 c 28 71 TSH+0.27 27901.1 24%TW 2009 c 28 84 03H+0.50 96910.1 5%TW 2014 c 30 48 BPH+0.58 27901.1 20%TW 2015 c 30 74 TSH+6.47 27901.1 20%TW 2014 c 32 36 BPH+0.58 27901.1 19%TW 2009 c 33 17 TSH+2.69 27901.1 20%TW 2005 c 34 18 TSH+0.97 27901.1 22%TW 2005 c 34 20 TSH+0.91 27901.1 25%TW 2005 c 34 74 TSH+0.06 27901.1 27%TW 2005 ' .. c 35 19 TSH+0.32 27901.1 29%TW 2005 '. 'Signal*

Prior to ,, , '; ci:rrent Outage?. Yes, in 1996 bobbin data. No RPC. Yes. No change since initial detection.

Yes. No change since initial detection.

Yes. No change since initial detection.

Yes. No signal change since 1996. Yes, based on lookup. Unchanged since 1996. Yes. Present in 2014 X-Probe data with no change. Yes, based on lookup. Unchanged since 1996. Yes. No signal change. Yes. No signal change. Yes. No signal change. Yes. No signal change. Yes. No signal change. * ..

No signal change. Cause TSP Wear Foreign Object Foreign Object Foreign Object Foreign Object TSP Wear Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Object ,,. .

.. N/A No No No No N/A No No No No No No No No Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 9 of 14 " Plugged? No No No No No No No No No No No No No No

.SG Row Col " 'ErSS l.,ocation, ' .. c 35 22 TSH+1.03 27901.1 c 35 30 TSH+0.11 27901.1 c 36 32 BPH+0.55 27901.1 c 36 68 TSH+0.17 27902.1 c 37 31 TSH+0.09 27901.1 c 37 32 TSH+0.02 27901.1 c 37 33 TSH+0.04 27901.1 c 37 34 TSH-0.06 27901.1 c 37 35 BPH+0.60 27901.1 c 37 54 TSH+0.12 27901.1 7C-0.48 96910.1 c 37 73 7C-0.52 96910.1 c 38 32 BPH+0.60 27901.1 c 38 53 TSH+0.08 27901.1 BPH+0.61 27901.1 ,* .. c 39 32 BPH+0.60 27901.1 '. *,Max Depth I* Initially' Signal Present P.rior.,to

(%TW) k Reportecl

• 'Current Outage? '*,*"' << " 29%1W 2005 Yes. No signal change. 35%TW 2005 Yes. No signal change. 21 %1W 2015 Yes. No change since 2008. 26%1W 2005 Yes. No signal change. 26%1W 2011 Yes, in 1996 3-coil data. No change. 23%1W 2011 Yes, in 2005 +PointŽ data. No change. 26%1W 2011 Yes, in 1996 3-coil data. No change. 26%1W 2009 Yes. No signal change since 1996. 33%1W 2005 Yes. No signal change. 24%1W 2005 Yes. No signal change. 13%1W 2005 Yes. No change since initial detection.

6%1W 2011 26%1W 2011 Yes, present in 2005 bobbin data. No RPC. 22%1W 2005 Yes. No signal change. 22%1W 2011 ":-* Yes,:*1:i'resent in 2005 bobbin data. No RPC. 24%1W 2011 . \'*, ;_; . '. (;:,. '* ...... ,-*, *' Cause Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object TSP Wear Foreign Object Foreign Object Foreign Object Object Re1J1aining?

No No No No No No No No No No N/A No No No No Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 10 of 14 . Plugged? No No No No No No No No No No No No No No No

' *.i .. ' Maxbepth*

• Initially SG Row

• Co( Locatio*n ETSS (%TW) .Reported

• ,* ' .. '**'* . ' i* c 39 34 BPH+0.57 27901.1 24%TW 2011 c 40 34 BPH+0.60 27901.1 22%TW 2011 c 44 42 TSH+0.12 27901.1 24%TW 2005 c 44 43 TSH+0.19 27901.1 26%TW 2005 c 44 47 TSH+0.06 27901.1 26%TW 2005 c 44 60 BPH+0.17 96910.1 7%1W 2015 c 45 42 TSH+0.26 27901.1 19%TW 2015 TSH+0.23 27901.1 23%TW c 45 43 TSH+0.24 27901.1 24%TW 2005 TSH+0.72 27901.1 20%TW c 45 47 TSH+0.17 27901.1 23%TW 2005 *.*. .

Present Prior to' ' ,-Current Outage? . . ' . Yes, present in 2005 bobbin data. No RPC. Yes, present in 2005 bobbin data. No RPC. Yes. No signal change. Yes. No signal change. Yes. No signal change. Yes. Present in 2014 bobbin data with no change. Present in 2005 +PointŽ data with no change. Yes. No signal change. Yes. No signal change. '*

• l'i' .. "' Cause. .. Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object TSP Wear Foreign Object Foreign Object Foreign Object Foreign Object Remaining?

No No No No No N/A No No No Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 11of14 Plugged? . No No No No No No No No No Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 12 of 14 e. Number of tubes plugged during the inspection outage for each degradation mechanism Three tubes (see Table 6) required plugging as a result of circumferential cracks from PWSCC which was identified during the Fall 2015 RFO. One additional tube (SG C R20 C62) was preventatively plugged. This tube was inspected full length and determined to have no degradation.

The tube was plugged because the tube is dented at the th TSP making it difficult to inspect without examining the tube several times. Table 6 -Circumferential PWSCC Indications

><' : .+PointtM

'

• Max '* Arc: ; SG*,'.* Row *C.ol 'Ind* ' 1 l.ocatfon

• ' > >*' ,, '* .:J' , 1;:*t0r.9 tt\ * : 1 PD'1\, "' " ,*

• Volts. ( . SGC 6 41 SCI TEH +18.25" 0.88 65%TW 85° 15 SGC 7 46 SCI TEH +15.56" 0.78 50%TW 78° 11 SGC 27 65 SCI TEH +16.04" 1.30 60%TW 99° 17 f. The number and percentage of tubes plugged to date, and the effective plugging p,ercentage in each steam generator.

., * }, Table 7 provides the plugging totals and percentages to date. SGA SG B SGC Total Table 7 -Tube Plugging Summary 3,342 3,342 3,342 10,026 .Tube's Plugged, :., * *. To Date* .* , .. 30 (0.9%) 19 (0.6%) 50 (1.5%) 99 (1.0%) g. The results of condition monitoring, including the results of tube pulls and in-situ testing Based on the results of the primary and secondary side inspections performed during this outage, all degradation identified during the Fall 2015 inspection satisfied condition monitoring requirements for SG tube structural and leakage integrity.

Further, the results from the current outage inspection validate prior outage operational assessment assumptions.

Tube pulls and in-situ pressure testing were not required during the current outage.

Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 13of14 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 the Fall 2015 RFO, no measurable primary-to-secondary leakage (i.e., >1 GPO) 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 is zero. Assuming that the prior cycle operational leakage of <1 GPO originated from H-star distance, and multiplying this leakage by a factor of 1.8 as required by the PARC, yields a*ii accident induced leakage value of <1.8 GPO. This value is well below the 470 GPO 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 b.e provided.

No indications of tube slippage were identified during the evaluation of bobbin probe examjpation data 'j

• from SGs A or C. Note that no bobbin probe examinations were performed in SG B during tf.ie Fall 5 r-* 'y RFO. All tubes in SG B were screened for slippage during the Spring 2014 (no indications were . identified) and will again be screened during the Spring 2017 RFO.

AVB BPC BPH C/l ECT EFPM ETSS FOSAR GPD H/L MRPC NSAL NTE OD ODSCC OVR OXP PARC PLP PWSCC SC! SG SSC TEC TEH TSC TSH TSP TTS TW Acronyms Anti-Vibration Bar Baffle Plate Cold Baffle Plate Hot Cold Lea Eddy Current Testina Effective Full Power Month Eddy Current Technical Specification Sheets Foreiqn Obiect Search and Retrieval Gallons Per Dav Hot Lea Motorized Rotatina Pancake Coil Nuclear Safetv Advisory Letter No tube Exoansion Outer Diameter Outside Diameter Stress Corrosion Crackinq Over Roll Over Expansion Permanent Alternate Reoair Criteria Possible Loose Part Primary Water Stress Corrosion Crackina Single Circumferential Indication Steam Generator Stress Corrosion Crackina Tube End Cold-lea Tube End Hot-lea Top of Tube Sheet Cold-lea Top of Tube Sheet Hot-leq Tube Support Plate Top of Tube&heet Throuqh Wall Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 14 of 14

' '

VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 May 10, 2016 United States Nuclear Regulatory Commission Attention:

Document Control Desk Washington, DC 20555-0001 VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNIT 2 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2015 REFUELING OUTAGE Serial No. SPS-LIC/CGL Docket No.

• License No.16-196 RO 50-281 DPR-37 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 T avg 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 Fall 2015 refueling outage. If you have any questions concerning this information, please contact Mrs. Candee G. Lovett at (757) 365-2178.

Douglas Lawrence Director S ation Safety & Licensing Surry Power Station

Attachment:

Surry Unit 2 Steam Generator Tube Inspection Report for the Fall 2015 Refueling Outage Commitments made in this letter: None 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.: 16-196 Docket No.: 50-281 Page 2 of 2 ATTACHMENT 1 SURRY UNIT 2 Serial No.: 16-196 Docket No.: 50-281 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2015 REFUELING OUTAGE VIRGINIA ELECTRIC AND POWER COMAPNY (DOMINION)

SURRY UNIT 2 Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 1 of 14 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2015 REFUELING OUTAGE The following satisfies the Surry Power Station Technical Specification (TS) reporting

• requirement section 6.6.A.3 .. During the Surry Unit 2 Fall 2015 refueling outage (RFO), steam generator (SG) inspections in accordance with TS 6.4.Q were completed for SG A and SG C. This was the third inspection in the 4th inspection period which has a duration of 72 effective full power months (EFPM). Surry Unit 2 exceeded 200°F on November 28, 2015; therefore, this report is required to be submitted by May 26, 2016. At the time of this inspection, the Unit 2 SGs had operated for 333.0 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 attac;;hed at the end of this report. " A report shall be submitted Within 180 days after Tavg exceeds following completion of an inspection performed in accordance with the Specification 6.4.Q, "Steam Generator (SG)Program.

11 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 in Table 1.

• The only scope expansions required in SG A and SG C were those ne.ce§sary.

to bound foreign objects and foreign object related degradation, *as well as to resolve ;;:imbig1,.1ous indications.

The inspection scope. was expanded into SG B based on the findil'.lg of circumferential primary water stress corrosion cracking (PWSCC) within the-hot leg tubesheet of SG C (see item e below for more detail). The eddy current scope in SG B was focused on the detection of stress corrosion cracking (SCC) in susceptible locations in the hot leg tubesheet; therefore, a 50% sample of the hot leg tubesheet locations with array probes was examined.

No bobbin inspections or cold leg tubesheet inspections were performed.

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 A, 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 abnormal or degraded conditions were identified from these examinations. ,}

Secondary Side Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 2 of 14 During the Surry Unit 2 Fall 2015 RFO , 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 A was performed.

This included all accessible steam drum components and structures , including the feedring exterior, the upper tube bundle, and ?'h tube support plate (TSP) via probe insert i ons through the primary moisture separators. No degradation or adverse conditions were noted during these inspections. Sludge lancing was performed in all three SGs. Foreign Object Search and Retrieval (FOSAR) examinations were performed in SGs A , B , and C at the top of t he tubesheet , in the annulus, and in the no-tube lane as necessary. Table 1 -Eddy Current Testing Examination Scope Scope Description Extent SGA SG SGC B Bobbin Coil Exams Full Length TEHTEC 2849 2831 H/L CandyCane (Row 3-5) 07CTEH 278 282 H/L Straight (R 1-2) 07HTEH 185 182 H/L Straiqht Restricted 07HTEH 1 C/L CandyCane Restricted 02HTEC 1 C/L Straight Restricted 07CTEC 1 2 C/L Straight (R1-5) 07CTEC 462 463 Array Exams H/L TSH Array (Non-Baffle Plate) TSH01H 834 444 843 H/L TSH A r ray (Baff l e Plate) T SHBPH 2478 1260 2453 C/L TSC Array (Non-Baffle Plate) TSC01C 834 842 C/L TSC Arra y (Baffle Pla t e) TSCBPC 2478 2453 MRPC Exams Ubend +Poin tŽ (Row 1-2) 07H07C 185 182 MRPC S pe c i a l Interes t H/L Previo u s I ndications Various 120 172 H/L Previous Restricted 02H03 1 C/L Previous Restricted Various 8 H/L Current Indications Various 97 7 92 Ubend Current Indications Various 2 1 C/L Previous Indications Various 8 7 C/L Current Indications Various 36 20 Indications For Mag8ias Probe Various 1 2 Additional RPC TEHTSH 2 Total 10848 1713 10838

b. Degradation mechanisms found Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 3 of 14 Degradation mechanisms targeted by the inspection plan included anti-vibration bar (AVB) wear, pitting, foreign object wear, tube support wear and sec at various locations within the steam generator tube bundle. AVB wear, foreign object wear, tube support plate wear, and PWSCC were detected during the current outage. c. Nondestructive examination techniques utilized for each degradation mechanism The inspection program focused on the degradation mechanisms listed in Table 2 and utilized the referenced eddy current techniques.

Table 2 -Inspection Method for Applicable Degradation Modes .. *Degradation

' Classification.'

Mechanism,

• Loi;ation Probe Type. .. ""' . . . . .. : '"

,,:.' "*-' ... Existing Tube Wear Anti-Vibration Bars Bobbin -Detection and Sizing Existing OD Pitting Top-of-Tubesheet Bobbin and +PointŽ-Detection

+PointŽ -Sizing Existing Tube Wear Tube Support Plate Bobbin -Detection

+PointŽ -Sizing Existing Tube Wear Freespan and TIS Bobbin and +PointŽ -Detection (foreign objects) +PointŽ -Sizing Potential ODSCC Hot Leg Top-of-Tubesheet

+PointŽ -Detection and Sizing PWSCC Potential PWSCC Tube Ends NIA* Potential Tube Wear Flow Distribution Baffle Bobbin -Detection

+PointŽ -Sizing Bulges, Dents, Manufacturing Potential ODSCC Anomalies, and Above-+PointŽ -Detection and Sizing PWSCC Tubesheet Overexpansions (OVR) Potential ODSCC Tubesheet Crevice in +PointŽ -Detection and Sizing Tubes With NTEs Potential Tube Slippage Within Tubesheet Bobbin Detection Potential PWSCC Tubesheet

+PointŽ -Detection and Sizing Overexpansions (OXP) Potential ODSCC Row 1 and 2 Li-bends +PointŽ -Detection and Sizing PWSCC Potential ODS CC Freespan and Tube Supports Bobbin -Detection

+PointŽ -Sizing *Inspection not required per technical specification alternate repair criteria.

Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 4of14 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 through 6 provide information regarding these indications.

Table 3 -AVB Indications for SG A SGA 25 57 AV2 16 21 SGA 26 ' 9 AV4 12 10 I SGA 26 ' 86 AV3 17 21 SGA 29 28 AV3 NR 13 SGA 29 70 AV2 11 11 SGA 30 12 AV1 10 10 , ,,;:-... $GA 30 64 AV2 7 8 ----* SGA 33 26 AV4 NR 12 SGA 36 62 AV2 24* 21 I SGA 36 62 AV3 14 16 SGA 36 62 AV4 27 31 SGA 36 66 AV2 12 16 I SGA 36 66 ' AV3 " 10 13 i *' *:.::* . . -..... -SGA 37 20 AV1 13 12 .. --* -SGA 37 20 AV4 12 10 SGA 38 57. AV1 13 13 SGA 38 70 AV3 NR 11 SGA 38 72 AV4 23 26 SGA 38 74 AV4 17 22 SGA 40 25 AV4 12 8. SGA 40 49 AV1 11 15 SGA 40 49 AV2 10 10 SGA 40 49 AV3 11 11 SGA 40 65 AV2 18 21 SGA 40 65 AV3 10 15 SGA 40 65 AV4 10 9 SGA 40 66 AV3. 9 14 " -**--.....

-*

-*-b

• tlli (°AT\IW ** '/i: *.eP.':* o* .... *:**** '* ETSS '96041':1

',*

*;)2012: ..

• 201,:s .. SGA 42 62 AV3 NR 10 SGA 44 35 AV1 NR 10 SGA 44 38 AV2 11 9 SGA 45 44 AV2 11 11 SGA 46 45 AV1 13 10 NR =Not Reported during the previous outage Table 4 -AVB Indications for SG C :::):*:: .....

j-r**"' .,, : J, ' "

(% TW).*. * **

L -,.SG.-. " -_;. ' .

ETSs,' 96041'..:l Row Col '\

' ' ' _,._-No. ' ': : ; ' ' . 20tf5'; . **;<<.*' ._: ..... *;**. SGC 24' 8 AV4 9 10 SGC 25 9 AV1 8 8 SGC 25 9 AV3 11 10 SGC 25 27 AV1 18 17 SGC . 25 27 AV2 32 32 SGC 25 27 AV3 13 12 SGC 25 29 AV2 12 8 -SGC 25 29 AV3 26 20 SGC 26 26 AV3 17 19 SGC 26 26 AV4 17 17 -SGC 26 39 AV3 20 15 SGC 27 84 AV4 11 7 SGC 31 65 AV2 17 13 SGC 31 69 AV2 26 19 SGC 31 69 AV3 20 17 SGC 31 75 AV3 11 13 SGC 31 75 AV4 16 13 SGC 33 59 AV3 21 19 SGC 33 59 AV4 11 12 SGC 33 67 AV3 NR 10 Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 5 of 14 T

---.... . ..;.....

,, " " ' ,"*" -**

\: . .Row **-Col . *,*. __ ,. -.*>< ' ,,_*No.*** . ' . ' *, :: . ': ' ' ' ,,, ,; '! ;:.'*:> .;.. SGC 33 68 AV1 SGC 33 68 AV2 SGC 33 69 AV1 SGC. 33 69 AV2 SGC 33 70 AV1 SGC 33 70 AV3 SGC 34 29 AV3 SGC 34 29 AV4 SGC 34 79 AV1 SGC 35 77 AV2 SGC 35 77 AV3 SGC 37 63 AV2 SGC 37 73 AV3 SGC 37 75 AV3

• SGC. 38 28 AV1 SGC 38 28 AV3 SGC 38 30 AV2 SGC 38 43 AV3 SGC *38 73 AV1 SGC 38 73 AV2 SGC 38 74 AV2 SGC 39 50 AV3 SGC 39 ' 53 AV3 SGC 39 55 AV3 SGC 39 55 AV3 SGC ' 39 55 AV4 SGC 39 71 AV3 SGC 39 72 AV4 SGC 40 33 AV2 SGC 40 33 AV3 SGC 40 63 AV2 SGC 40 63 AV3 SGC 40 63 AV4 ' . c:>ep111:4,(%

ffl):. *.

• ETSS. 9604 t .. * -: ; ,::2012 ,:, '20f5. 18 20 20 19 10 9 13 11 10 8 16 16 11 12 17 16 8 11 10 11 10 10 13 11 15 17 12 11 10 7 17 14 12 13 15 11 11 9 9 8* 8 8 14 13 30 28 27 25 18 12 26 25 12 8 5 10 23 24 23 25 9 9 19 15 19 16 Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 6of14 -ii

--Y.;,.:-, ....... *:-11. , .. .[., .... :;. .. :;;,; ('. -r;-

., .,.:.

.* AVB Depth (% TW) . **s8 Row Col No. ' E:TSS 96041.1 * ' ' ' . 201'2 2015 SGC 41 35 AV3 NR 11 SGC 41 64 AV1 11 9 SGC 41 . 66 AV3 12 14 SGC 41 68 AV4 10 10 SGC 43 39 AV2 16 13 SGC 43 61 AV1 25 22 SGC 43 63 AV1 14 15 SGC 44 61 AV1 11 10 SGC 45 58 AV3 NR 13 SGC 46 45 AV2 8 11 SGC 46 45 AV3 NR 10 SGC 46 46 AV1 NR 10 SGC 46 46 AV2 NR 12 SGC 46 46 AV3 NR 13 SGC 46 46 AV4 NR 10 NR = Not Reported du!"ing the previous outage Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 7 of 14

'

':.bi l.'.\ ',c-113; ,, c;:

' .* . . .. SG Row Col Location . . TSC+0.82 A 4 37 TSC+1.81 A 6 60 5H-0.59 A 11 45 TSH+0.96 A 15 16 TSH+0.23 A 17 16 TSH+0.04 A 18 16 TSH+0.02 A 32 27 TSC+0.02 A 33 27 TSC+0.12 A 39 24 TSH+0.45 A 42 52 TSC+0.26 A 43 61 BPH+0.56 A 43 64 BPH+0.62 Table 5 -Summary of Non-AVB Volumetric Degradation Identified

.* '" k . Signal Present prior to . . *

• Foreign ... ETSS Initially Cause Object {f,oTW) Repor;ted

• ,, Current Outage? Remaining?

I*, . ' .. *. ' ... 27901.1 20%TW 2015 Yes. No signal change Foreign No since 1995. Object 27901.1 27%TW 2015 Yes. No signal change Foreign No since 1995. Object 96910.1 13%TW 2009 Yes. No signal TSP Wear N/A change since 2002. 27901.1 27%TW 2012 Yes. No signal Foreign No change since 2006. Object 27901.1 25%TW 2012 No signal present Foreign No in 2006 exam. Object 27901.1 31 %TW 2002 Yes. No signal Foreign No change. Object 27901.1 30%TW 2002 Yes. No signal Foreign No change. Object 27901.1 20%TW 2006 Yes. No signal Foreign No change. Object 27901.1 25%TW 2006 Yes. No signal Foreign No change. Object 27901.1 20%TW 2009 Yes. No signal Foreign No change since 2006. Object 27901.1 20%TW 2009 Yes. No signal change Foreign No since 2009. Object 27901.1 23%TW 2009 Yes. No signal Foreign No change since 2002. Object .. Yes. Possible minor Foreign 27901.1 '24%TW 2009 sigriai'\;iiange 2002 to No 2009. No change since. Object Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 8of14 Plugged? ' No No No No No No No No No No No No 1.1 ' '*Max Depth SG Row Col Location ETSS Initially***

(%TW) ,

3C+0.47 96910.1 4%TW 2011 c 3 72 3C+0.48 96910.1 2%TW 2011 c 28 22 TSH+0.17 27901.1 29%TW 2014 TSH+0.52 27901.1 29%TW 2014 c 28 23 TSH+0.21 27901.1 29%TW 2014 c 28 71 TSH+0.27 27901.1 24%TW 2009 c 28 84 03H+0.50 96910.1 5%TW 2014 c 30 48 BPH+0.58 27901.1 20%TW 2015 c 30 74 TSH+6.47 27901.1 20%TW 2014 c 32 36 BPH+0.58 27901.1 19%TW 2009 c 33 17 TSH+2.69 27901.1 20%TW 2005 c 34 18 TSH+0.97 27901.1 22%TW 2005 c 34 20 TSH+0.91 27901.1 25%TW 2005 c 34 74 TSH+0.06 27901.1 27%TW 2005 ' .. c 35 19 TSH+0.32 27901.1 29%TW 2005 '. 'Signal*

Prior to ,, , '; ci:rrent Outage?. Yes, in 1996 bobbin data. No RPC. Yes. No change since initial detection.

Yes. No change since initial detection.

Yes. No change since initial detection.

Yes. No signal change since 1996. Yes, based on lookup. Unchanged since 1996. Yes. Present in 2014 X-Probe data with no change. Yes, based on lookup. Unchanged since 1996. Yes. No signal change. Yes. No signal change. Yes. No signal change. Yes. No signal change. Yes. No signal change. * ..

No signal change. Cause TSP Wear Foreign Object Foreign Object Foreign Object Foreign Object TSP Wear Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Object ,,. .

.. N/A No No No No N/A No No No No No No No No Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 9 of 14 " Plugged? No No No No No No No No No No No No No No

.SG Row Col " 'ErSS l.,ocation, ' .. c 35 22 TSH+1.03 27901.1 c 35 30 TSH+0.11 27901.1 c 36 32 BPH+0.55 27901.1 c 36 68 TSH+0.17 27902.1 c 37 31 TSH+0.09 27901.1 c 37 32 TSH+0.02 27901.1 c 37 33 TSH+0.04 27901.1 c 37 34 TSH-0.06 27901.1 c 37 35 BPH+0.60 27901.1 c 37 54 TSH+0.12 27901.1 7C-0.48 96910.1 c 37 73 7C-0.52 96910.1 c 38 32 BPH+0.60 27901.1 c 38 53 TSH+0.08 27901.1 BPH+0.61 27901.1 ,* .. c 39 32 BPH+0.60 27901.1 '. *,Max Depth I* Initially' Signal Present P.rior.,to

(%TW) k Reportecl

• 'Current Outage? '*,*"' << " 29%1W 2005 Yes. No signal change. 35%TW 2005 Yes. No signal change. 21 %1W 2015 Yes. No change since 2008. 26%1W 2005 Yes. No signal change. 26%1W 2011 Yes, in 1996 3-coil data. No change. 23%1W 2011 Yes, in 2005 +PointŽ data. No change. 26%1W 2011 Yes, in 1996 3-coil data. No change. 26%1W 2009 Yes. No signal change since 1996. 33%1W 2005 Yes. No signal change. 24%1W 2005 Yes. No signal change. 13%1W 2005 Yes. No change since initial detection.

6%1W 2011 26%1W 2011 Yes, present in 2005 bobbin data. No RPC. 22%1W 2005 Yes. No signal change. 22%1W 2011 ":-* Yes,:*1:i'resent in 2005 bobbin data. No RPC. 24%1W 2011 . \'*, ;_; . '. (;:,. '* ...... ,-*, *' Cause Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object TSP Wear Foreign Object Foreign Object Foreign Object Object Re1J1aining?

No No No No No No No No No No N/A No No No No Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 10 of 14 . Plugged? No No No No No No No No No No No No No No No

' *.i .. ' Maxbepth*

• Initially SG Row

• Co( Locatio*n ETSS (%TW) .Reported

• ,* ' .. '**'* . ' i* c 39 34 BPH+0.57 27901.1 24%TW 2011 c 40 34 BPH+0.60 27901.1 22%TW 2011 c 44 42 TSH+0.12 27901.1 24%TW 2005 c 44 43 TSH+0.19 27901.1 26%TW 2005 c 44 47 TSH+0.06 27901.1 26%TW 2005 c 44 60 BPH+0.17 96910.1 7%1W 2015 c 45 42 TSH+0.26 27901.1 19%TW 2015 TSH+0.23 27901.1 23%TW c 45 43 TSH+0.24 27901.1 24%TW 2005 TSH+0.72 27901.1 20%TW c 45 47 TSH+0.17 27901.1 23%TW 2005 *.*. .

Present Prior to' ' ,-Current Outage? . . ' . Yes, present in 2005 bobbin data. No RPC. Yes, present in 2005 bobbin data. No RPC. Yes. No signal change. Yes. No signal change. Yes. No signal change. Yes. Present in 2014 bobbin data with no change. Present in 2005 +PointŽ data with no change. Yes. No signal change. Yes. No signal change. '*

• l'i' .. "' Cause. .. Foreign Object Foreign Object Foreign Object Foreign Object Foreign Object TSP Wear Foreign Object Foreign Object Foreign Object Foreign Object Remaining?

No No No No No N/A No No No Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 11of14 Plugged? . No No No No No No No No No Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 12 of 14 e. Number of tubes plugged during the inspection outage for each degradation mechanism Three tubes (see Table 6) required plugging as a result of circumferential cracks from PWSCC which was identified during the Fall 2015 RFO. One additional tube (SG C R20 C62) was preventatively plugged. This tube was inspected full length and determined to have no degradation.

The tube was plugged because the tube is dented at the th TSP making it difficult to inspect without examining the tube several times. Table 6 -Circumferential PWSCC Indications

><' : .+PointtM

'

• Max '* Arc: ; SG*,'.* Row *C.ol 'Ind* ' 1 l.ocatfon

• ' > >*' ,, '* .:J' , 1;:*t0r.9 tt\ * : 1 PD'1\, "' " ,*

• Volts. ( . SGC 6 41 SCI TEH +18.25" 0.88 65%TW 85° 15 SGC 7 46 SCI TEH +15.56" 0.78 50%TW 78° 11 SGC 27 65 SCI TEH +16.04" 1.30 60%TW 99° 17 f. The number and percentage of tubes plugged to date, and the effective plugging p,ercentage in each steam generator.

., * }, Table 7 provides the plugging totals and percentages to date. SGA SG B SGC Total Table 7 -Tube Plugging Summary 3,342 3,342 3,342 10,026 .Tube's Plugged, :., * *. To Date* .* , .. 30 (0.9%) 19 (0.6%) 50 (1.5%) 99 (1.0%) g. The results of condition monitoring, including the results of tube pulls and in-situ testing Based on the results of the primary and secondary side inspections performed during this outage, all degradation identified during the Fall 2015 inspection satisfied condition monitoring requirements for SG tube structural and leakage integrity.

Further, the results from the current outage inspection validate prior outage operational assessment assumptions.

Tube pulls and in-situ pressure testing were not required during the current outage.

Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 13of14 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 the Fall 2015 RFO, no measurable primary-to-secondary leakage (i.e., >1 GPO) 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 is zero. Assuming that the prior cycle operational leakage of <1 GPO originated from H-star distance, and multiplying this leakage by a factor of 1.8 as required by the PARC, yields a*ii accident induced leakage value of <1.8 GPO. This value is well below the 470 GPO 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 b.e provided.

No indications of tube slippage were identified during the evaluation of bobbin probe examjpation data 'j

• from SGs A or C. Note that no bobbin probe examinations were performed in SG B during tf.ie Fall 5 r-* 'y RFO. All tubes in SG B were screened for slippage during the Spring 2014 (no indications were . identified) and will again be screened during the Spring 2017 RFO.

AVB BPC BPH C/l ECT EFPM ETSS FOSAR GPD H/L MRPC NSAL NTE OD ODSCC OVR OXP PARC PLP PWSCC SC! SG SSC TEC TEH TSC TSH TSP TTS TW Acronyms Anti-Vibration Bar Baffle Plate Cold Baffle Plate Hot Cold Lea Eddy Current Testina Effective Full Power Month Eddy Current Technical Specification Sheets Foreiqn Obiect Search and Retrieval Gallons Per Dav Hot Lea Motorized Rotatina Pancake Coil Nuclear Safetv Advisory Letter No tube Exoansion Outer Diameter Outside Diameter Stress Corrosion Crackinq Over Roll Over Expansion Permanent Alternate Reoair Criteria Possible Loose Part Primary Water Stress Corrosion Crackina Single Circumferential Indication Steam Generator Stress Corrosion Crackina Tube End Cold-lea Tube End Hot-lea Top of Tube Sheet Cold-lea Top of Tube Sheet Hot-leq Tube Support Plate Top of Tube&heet Throuqh Wall Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 14 of 14

' '