ML16141A117
| ML16141A117 | |
| Person / Time | |
|---|---|
| Site: | Surry  |
| Issue date: | 05/10/2016 |
| From: | Lawrence D 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 Serial No.16-196 Attention: Document Control Desk SPS-LIC/CGL RO Washington, DC 20555-0001 Docket No. 50-281
- License No. DPR-37 VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNIT 2 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2015 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 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
Serial No.: 16-196 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.: 16-196 Docket No.: 50-281 ATTACHMENT 1 SURRY UNIT 2 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2015 REFUELING OUTAGE VIRGINIA ELECTRIC AND POWER COMAPNY (DOMINION)
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 1 of 14 SURRY UNIT 2 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 -~JJ0 9F: 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 RfOY,id~d 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.
Serial No. : 16-196 Docket No.: 50-281 Attachment 1 Page 2 of 14 Secondary Side 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 insertions 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 the tubesheet, in the annulus, and in the no-tube lane as necessary.
Table 1 - Eddy Current Testing Examination Scope SG Scope Description Extent SGA 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 Array (Baffle Plate) TSHBPH 2478 1260 2453 C/L TSC Array (Non-Baffle Plate) TSC01C 834 842 C/L TSC Array (Baffle Plate) TSCBPC 2478 2453 MRPC Exams Ubend +Point' (Row 1-2) 07H07C 185 182 MRPC Special Interest H/L Previous Indications 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
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 3 of 14
- 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 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 Bobbin and +Point'- Detection Existing OD Pitting Top-of-Tubesheet
+Point' - Sizing Bobbin - Detection Existing Tube Wear Tube Support Plate
+Point' - Sizing Tube Wear Bobbin and +Point' - Detection Existing Freespan and TIS (foreign objects) +Point' - Sizing ODSCC Potential Hot Leg Top-of-Tubesheet +Point' - Detection and Sizing PWSCC Potential PWSCC Tube Ends NIA*
Bobbin - Detection Potential Tube Wear Flow Distribution Baffle
+Point' - Sizing Bulges, Dents, Manufacturing ODSCC Anomalies, and Above-Potential +Point' - Detection and Sizing PWSCC Tubesheet Overexpansions (OVR)
Tubesheet Crevice in Potential ODSCC +Point' - Detection and Sizing Tubes With NTEs Potential Tube Slippage Within Tubesheet Bobbin Detection Tubesheet Potential PWSCC +Point' - Detection and Sizing Overexpansions (OXP)
ODSCC Potential Row 1 and 2 Li-bends +Point' - Detection and Sizing PWSCC Bobbin - Detection Potential ODS CC Freespan and Tube Supports
+Point' - 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 26 ' I "
SGA 9 AV4 12 10 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 -~v 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
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 5 of 14
-*-b*.eP.':*
'/i:
- tlli (°AT\IW o* .... *:******
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- ~: .
- 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
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SGC 24' 8 AV4 9 10 SGC 25 9 AV1 8 8
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SGC 25 9 AV3 11 10 ~ ~
SGC 25 27 AV1 18 17 SGC . 25 27 AV2 32 32
- ~
SGC 25 27 AV3 13 12 :.,---
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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 6of14 I~: ,"*" ,,
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SGC 33 68 AV1 18 20 SGC 33 68 AV2 20 19 SGC 33 69 AV1 10 9 SGC. 33 69 AV2 13 11 SGC 33 70 AV1 10 8 SGC 33 70 AV3 16 16 SGC 34 29 AV3 11 12 SGC 34 29 AV4 17 16 SGC 34 79 AV1 8 11 SGC 35 77 AV2 10 11 SGC 35 77 AV3 10 10 SGC 37 63 AV2 13 11 SGC 37 73 AV3 15 17
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SGC 37 75 AV3 12 11 .... :;.
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SGC 38 30 AV2 12 13
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SGC 38 43 AV3 15 11
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SGC *38 73 AV1 11 9 --Y.;,.:-, ::~:~
SGC 38 73 AV2 9 8* ....... -~--r:_
- -11.
SGC 38 74 AV2 8 8 .,
SGC 39 50 AV3 14 13 SGC 39 ' 53 AV3 30 28 SGC 39 55 AV3 27 25 SGC 39 55 AV3 18 12 SGC ' 39 55 AV4 26 25 SGC 39 71 AV3 12 8 SGC 39 72 AV4 5 10 SGC 40 33 AV2 23 24 SGC 40 33 AV3 23 25 SGC 40 63 AV2 9 9 SGC 40 63 AV3 19 15 SGC 40 63 AV4 19 16
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 7 of 14 Depth (% TW) .
- s8 Row Col .* AVB ' E:TSS 96041.1
- No.
' ' . 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
.)~1 SGC 46 46 AV2 NR 12
' ~,;:;'.. l.'.\
SGC 46 46 AV3 NR 13
':.bi ',c-113; SGC 46 46 AV4 NR 10 ,,
c;:
NR = Not Reported du!"ing the previous outage
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 8of14 Table 5 - Summary of Non-AVB Volumetric Degradation Identified
. . .* .. .* '" k .
M~Depth Initially Signal Present prior to
. . *
- Foreign ...
SG Row Col Location ETSS Cause Object Plugged?
~
.. I*, .'
{f,oTW) Repor;ted
- ,, Current Outage?
.. Remaining?
Yes. No signal change Foreign TSC+0.82 27901.1 20%TW 2015 No No since 1995. Object A 4 37 Yes. No signal change Foreign TSC+1.81 27901.1 27%TW 2015 No No since 1995. Object Yes. No signal A 6 60 5H-0.59 96910.1 13%TW 2009 TSP Wear N/A No change since 2002.
Yes. No signal Foreign A 11 45 TSH+0.96 27901.1 27%TW 2012 No No change since 2006. Object No signal present Foreign A 15 16 TSH+0.23 27901.1 25%TW 2012 No No in 2006 exam. Object Yes. No signal Foreign A 17 16 TSH+0.04 27901.1 31 %TW 2002 No No change. Object Yes. No signal Foreign A 18 16 TSH+0.02 27901.1 30%TW 2002 No ~No change. Object Yes. No signal Foreign A 32 27 TSC+0.02 27901.1 20%TW 2006 No No change. Object Yes. No signal Foreign A 33 27 TSC+0.12 27901.1 25%TW 2006 No No change. Object Yes. No signal Foreign A 39 24 TSH+0.45 27901.1 20%TW 2009 No No change since 2006. Object Yes. No signal change Foreign A 42 52 TSC+0.26 27901.1 20%TW 2009 No No since 2009. Object Yes. No signal Foreign A 43 61 BPH+0.56 27901.1 23%TW 2009 No No change since 2002. Object
.. Yes. Possible minor Foreign A 43 64 BPH+0.62 27901.1 '24%TW 2009 sigriai'\;iiange 2002 to No No Object 2009. No change since.
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 9 of 14 1.1 ' For~ign
'*Max Depth Initially*** 'Signal* Pres~nf Prior to ,, , ,,.
SG Row Col Location ETSS Cause Object Plugged?
(%TW) , Reporte~ ci:rrent Outage?.
'; ~
. R~maining? ..
3C+0.47 96910.1 4%TW 2011 Yes, in TSP c 3 72 1996 bobbin data. N/A No Wear 3C+0.48 96910.1 2%TW 2011 No RPC.
Yes. No change since Foreign c 28 22 TSH+0.17 27901.1 29%TW 2014 No No initial detection. Object Yes. No change since Foreign TSH+0.52 27901.1 29%TW 2014 No No initial detection. Object c 28 23 Yes. No change since Foreign TSH+0.21 27901.1 29%TW 2014 No No initial detection. Object Yes. No signal Foreign c 28 71 TSH+0.27 27901.1 24%TW 2009 No No change since 1996. Object Yes, based on lookup. TSP c 28 84 03H+0.50 96910.1 5%TW 2014 Unchanged since 1996. Wear N/A No Yes. Present in 2014 Foreign c 30 48 BPH+0.58 27901.1 20%TW 2015 X-Probe data with no Object No No change.
Yes, based on lookup. Foreign c 30 74 TSH+6.47 27901.1 20%TW 2014 No No Unchanged since 1996. Object Yes. No signal Foreign c 32 36 BPH+0.58 27901.1 19%TW 2009 change. Object No No Yes. No signal Foreign c 33 17 TSH+2.69 27901.1 20%TW 2005 change. Object No No Yes. No signal Foreign c 34 18 TSH+0.97 27901.1 22%TW 2005 change. Object No No Yes. No signal Foreign c 34 20 TSH+0.91 27901.1 25%TW 2005 change. Object No No Yes. No signal Foreign c 34 74 TSH+0.06 27901.1 27%TW 2005 change. Object No No
' ~ .. *. '<yej'~<< No signal Foreign c 35 19 TSH+0.32 27901.1 29%TW 2005 change. Object No No
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 10 of 14
" *,Max Depth I* Initially' Signal Present P.rior.,to
- t=or~ign
.SG Row Col l.,ocation, 'ErSS Cause Object Plugged?
(%TW) k Reportecl * 'Current Outage?
Re1J1aining?
Yes. No signal Foreign c 35 22 TSH+1.03 27901.1 29%1W 2005 change. Object No No Foreign c 35 30 TSH+0.11 27901.1 35%TW 2005 Yes. No signal change.
Object No No Yes. No change since Foreign c 36 32 BPH+0.55 27901.1 21 %1W 2015 2008. Object No No Yes. No signal Foreign c 36 68 TSH+0.17 27902.1 26%1W 2005 change. Object No No Yes, in 1996 3-coil data. Foreign c 37 31 TSH+0.09 27901.1 26%1W 2011 No change. Object No No Yes, in 2005 +Point' Foreign c 37 32 TSH+0.02 27901.1 23%1W 2011 data. No change. Object No No Yes, in 1996 3-coil data. Foreign c 37 33 TSH+0.04 27901.1 26%1W 2011 No change. Object No No Yes. No signal Foreign c 37 34 TSH-0.06 27901.1 26%1W 2009 change since 1996. Object No No Yes. No signal Foreign c 37 35 BPH+0.60 27901.1 33%1W 2005 change. Object No No Yes. No signal Foreign c 37 54 TSH+0.12 27901.1 24%1W 2005 change. Object No No 7C-0.48 96910.1 13%1W 2005 Yes. No change since TSP c 37 73 initial detection. Wear N/A No 7C-0.52 96910.1 6%1W 2011 Yes, present in 2005 Foreign c 38 32 BPH+0.60 27901.1 26%1W 2011 bobbin data. No RPC. Object No No Yes. No signal Foreign c 38 53 TSH+0.08 27901.1 22%1W 2005 change. Object No No BPH+0.61 27901.1 22%1W 2011 No No
..,* ":-* Yes,:*1:i'resent in 2005 Foreign c 39 32 bobbin data. No RPC. Object BPH+0.60 27901.1 24%1W 2011 No No
. \'*, ?~ ;_; . '. (;:,. '* ,~ . . . ,-
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 11of14 SG
' Row*.i* Co(
Locatio*n ETSS Maxbepth* *Initially . ~ignat. Present Prior to' ' ,- "'
Cause.
Foreign Object Plugged?
(%TW) .Reported Current Outage? .
- ,* ' ~ .. '**'* . ' i* . . '
.. Remaining?
Yes, present in 2005 Foreign c 39 34 BPH+0.57 27901.1 24%TW 2011 bobbin data. No RPC. Object No No Yes, present in 2005 Foreign c 40 34 BPH+0.60 27901.1 22%TW 2011 bobbin data. No RPC. Object No No Yes. No signal Foreign c 44 42 TSH+0.12 27901.1 24%TW 2005 change. Object No No Yes. No signal Foreign c 44 43 TSH+0.19 27901.1 26%TW 2005 change. Object No No Yes. No signal Foreign c 44 47 TSH+0.06 27901.1 26%TW 2005 change. Object No No Yes. Present in 2014 c 44 60 BPH+0.17 96910.1 7%1W 2015 bobbin data with no TSP Wear N/A No change.
Present in 2005 +Point' Foreign c 45 42 TSH+0.26 27901.1 19%TW 2015 data with no change. Object No No TSH+0.23 27901.1 23%TW Yes. No signal Foreign c 45 43 TSH+0.24 27901.1 24%TW 2005 change. Object No No TSH+0.72 27901.1 20%TW Yes. No signal Foreign c 45 47 TSH+0.17 27901.1 23%TW 2005 change. Object No No
- .*. ~ '*
- l'i' ..
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* ' 1l.ocatfon * ,*' >* Volts.
>*' ,, '* .:J'
~ ,:*.DE{~th'1** 1;:*t0r. 9 tt\ *:
1
~
PD'1\,
(
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.
Table 7 - Tube Plugging Summary
.Tube's Plugged, :., *
- . To Date* .* ,. ~
SGA 3,342 30 (0.9%)
SG B 3,342 19 (0.6%)
SGC 3,342 50 (1.5%)
Total 10,026 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 other~.sources is zero. Assuming that the prior cycle operational leakage of <1 GPO originated from belo~(the 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 20~ 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.
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 14 of 14 Acronyms AVB Anti-Vibration Bar BPC Baffle Plate Cold BPH Baffle Plate Hot C/l Cold Lea ECT Eddy Current Testina EFPM Effective Full Power Month ETSS Eddy Current Technical Specification Sheets FOSAR Foreiqn Obiect Search and Retrieval GPD Gallons Per Dav H/L Hot Lea MRPC Motorized Rotatina Pancake Coil NSAL Nuclear Safetv Advisory Letter NTE No tube Exoansion OD Outer Diameter ODSCC Outside Diameter Stress Corrosion Crackinq OVR Over Roll OXP Over Expansion PARC Permanent Alternate Reoair Criteria PLP Possible Loose Part PWSCC Primary Water Stress Corrosion Crackina ?:.~
SC! Single Circumferential Indication
SG Steam Generator SSC Stress Corrosion Crackina TEC Tube End Cold-lea TEH Tube End Hot-lea TSC Top of Tube Sheet Cold-lea TSH Top of Tube Sheet Hot-leq TSP Tube Support Plate TTS Top of Tube&heet TW Throuqh Wall
VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 May 10, 2016 United States Nuclear Regulatory Commission Serial No.16-196 Attention: Document Control Desk SPS-LIC/CGL RO Washington, DC 20555-0001 Docket No. 50-281
- License No. DPR-37 VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNIT 2 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2015 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 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
Serial No.: 16-196 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.: 16-196 Docket No.: 50-281 ATTACHMENT 1 SURRY UNIT 2 STEAM GENERATOR TUBE INSPECTION REPORT FOR THE FALL 2015 REFUELING OUTAGE VIRGINIA ELECTRIC AND POWER COMAPNY (DOMINION)
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 1 of 14 SURRY UNIT 2 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 -~JJ0 9F: 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 RfOY,id~d 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.
Serial No. : 16-196 Docket No.: 50-281 Attachment 1 Page 2 of 14 Secondary Side 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 insertions 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 the tubesheet, in the annulus, and in the no-tube lane as necessary.
Table 1 - Eddy Current Testing Examination Scope SG Scope Description Extent SGA 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 Array (Baffle Plate) TSHBPH 2478 1260 2453 C/L TSC Array (Non-Baffle Plate) TSC01C 834 842 C/L TSC Array (Baffle Plate) TSCBPC 2478 2453 MRPC Exams Ubend +Point' (Row 1-2) 07H07C 185 182 MRPC Special Interest H/L Previous Indications 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
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 3 of 14
- 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 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 Bobbin and +Point'- Detection Existing OD Pitting Top-of-Tubesheet
+Point' - Sizing Bobbin - Detection Existing Tube Wear Tube Support Plate
+Point' - Sizing Tube Wear Bobbin and +Point' - Detection Existing Freespan and TIS (foreign objects) +Point' - Sizing ODSCC Potential Hot Leg Top-of-Tubesheet +Point' - Detection and Sizing PWSCC Potential PWSCC Tube Ends NIA*
Bobbin - Detection Potential Tube Wear Flow Distribution Baffle
+Point' - Sizing Bulges, Dents, Manufacturing ODSCC Anomalies, and Above-Potential +Point' - Detection and Sizing PWSCC Tubesheet Overexpansions (OVR)
Tubesheet Crevice in Potential ODSCC +Point' - Detection and Sizing Tubes With NTEs Potential Tube Slippage Within Tubesheet Bobbin Detection Tubesheet Potential PWSCC +Point' - Detection and Sizing Overexpansions (OXP)
ODSCC Potential Row 1 and 2 Li-bends +Point' - Detection and Sizing PWSCC Bobbin - Detection Potential ODS CC Freespan and Tube Supports
+Point' - 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 26 ' I "
SGA 9 AV4 12 10 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 -~v 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
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 5 of 14
-*-b*.eP.':*
'/i:
- tlli (°AT\IW 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
- ):*::..... {~ii j-r**"' .,,
- ,.SG.- .
" -_;. '
- ~'"~~"'"' ~ J,
'-'!;'~:,"':: ;
L
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- r'*.~~bepM; (% TW).*. ***
.: ETSs,' 96041'..:l
'\**;<<.*' "-,~:.*,
~ "'~ '~1 '~ '
._:..... *;**. ':
Row
- .;~
- ' '
Col
'>~:~\:;._
_,._-No.
' ' ' ~~~~A' ~-t ~":*201.2.,~:- . 20tf5'; .
T J~~
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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 6of14 I~: ,"*" ,,
~'! .~"~~J* \: . -:~VB:
c:>ep111:4,(%ffl):. *. *
- ,*..;_*s~:~:*:
__ ,. .Row **-Col . ,,_*No.***
ETSS.; 9604 t ..:~ *
- : ~*
. ' . ~<~- ' ' ,,, ,; ' ! *, :: . ': ' ;:.'*:> .;.. ,::2012 ,:, '20f5.
~ ' ~'
SGC 33 68 AV1 18 20 SGC 33 68 AV2 20 19 SGC 33 69 AV1 10 9 SGC. 33 69 AV2 13 11 SGC 33 70 AV1 10 8 SGC 33 70 AV3 16 16 SGC 34 29 AV3 11 12 SGC 34 29 AV4 17 16 SGC 34 79 AV1 8 11 SGC 35 77 AV2 10 11 SGC 35 77 AV3 10 10 SGC 37 63 AV2 13 11 SGC 37 73 AV3 15 17
-ii , ..
- ~
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SGC 37 75 AV3 12 11 .... :;.
':~i .. :;;,;
- SGC. 38 28 AV1 10 7 ('.
-r;- ~-=J~~
SGC 38 28 AV3 17 14 ~~
SGC 38 30 AV2 12 13
~'
SGC 38 43 AV3 15 11
- ,~Hr'.~
SGC *38 73 AV1 11 9 --Y.;,.:-, ::~:~
SGC 38 73 AV2 9 8* ....... -~--r:_
- -11.
SGC 38 74 AV2 8 8 .,
SGC 39 50 AV3 14 13 SGC 39 ' 53 AV3 30 28 SGC 39 55 AV3 27 25 SGC 39 55 AV3 18 12 SGC ' 39 55 AV4 26 25 SGC 39 71 AV3 12 8 SGC 39 72 AV4 5 10 SGC 40 33 AV2 23 24 SGC 40 33 AV3 23 25 SGC 40 63 AV2 9 9 SGC 40 63 AV3 19 15 SGC 40 63 AV4 19 16
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 7 of 14 Depth (% TW) .
- s8 Row Col .* AVB ' E:TSS 96041.1
- No.
' ' . 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
.)~1 SGC 46 46 AV2 NR 12
' ~,;:;'.. l.'.\
SGC 46 46 AV3 NR 13
':.bi ',c-113; SGC 46 46 AV4 NR 10 ,,
c;:
NR = Not Reported du!"ing the previous outage
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 8of14 Table 5 - Summary of Non-AVB Volumetric Degradation Identified
. . .* .. .* '" k .
M~Depth Initially Signal Present prior to
. . *
- Foreign ...
SG Row Col Location ETSS Cause Object Plugged?
~
.. I*, .'
{f,oTW) Repor;ted
- ,, Current Outage?
.. Remaining?
Yes. No signal change Foreign TSC+0.82 27901.1 20%TW 2015 No No since 1995. Object A 4 37 Yes. No signal change Foreign TSC+1.81 27901.1 27%TW 2015 No No since 1995. Object Yes. No signal A 6 60 5H-0.59 96910.1 13%TW 2009 TSP Wear N/A No change since 2002.
Yes. No signal Foreign A 11 45 TSH+0.96 27901.1 27%TW 2012 No No change since 2006. Object No signal present Foreign A 15 16 TSH+0.23 27901.1 25%TW 2012 No No in 2006 exam. Object Yes. No signal Foreign A 17 16 TSH+0.04 27901.1 31 %TW 2002 No No change. Object Yes. No signal Foreign A 18 16 TSH+0.02 27901.1 30%TW 2002 No ~No change. Object Yes. No signal Foreign A 32 27 TSC+0.02 27901.1 20%TW 2006 No No change. Object Yes. No signal Foreign A 33 27 TSC+0.12 27901.1 25%TW 2006 No No change. Object Yes. No signal Foreign A 39 24 TSH+0.45 27901.1 20%TW 2009 No No change since 2006. Object Yes. No signal change Foreign A 42 52 TSC+0.26 27901.1 20%TW 2009 No No since 2009. Object Yes. No signal Foreign A 43 61 BPH+0.56 27901.1 23%TW 2009 No No change since 2002. Object
.. Yes. Possible minor Foreign A 43 64 BPH+0.62 27901.1 '24%TW 2009 sigriai'\;iiange 2002 to No No Object 2009. No change since.
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 9 of 14 1.1 ' For~ign
'*Max Depth Initially*** 'Signal* Pres~nf Prior to ,, , ,,.
SG Row Col Location ETSS Cause Object Plugged?
(%TW) , Reporte~ ci:rrent Outage?.
'; ~
. R~maining? ..
3C+0.47 96910.1 4%TW 2011 Yes, in TSP c 3 72 1996 bobbin data. N/A No Wear 3C+0.48 96910.1 2%TW 2011 No RPC.
Yes. No change since Foreign c 28 22 TSH+0.17 27901.1 29%TW 2014 No No initial detection. Object Yes. No change since Foreign TSH+0.52 27901.1 29%TW 2014 No No initial detection. Object c 28 23 Yes. No change since Foreign TSH+0.21 27901.1 29%TW 2014 No No initial detection. Object Yes. No signal Foreign c 28 71 TSH+0.27 27901.1 24%TW 2009 No No change since 1996. Object Yes, based on lookup. TSP c 28 84 03H+0.50 96910.1 5%TW 2014 Unchanged since 1996. Wear N/A No Yes. Present in 2014 Foreign c 30 48 BPH+0.58 27901.1 20%TW 2015 X-Probe data with no Object No No change.
Yes, based on lookup. Foreign c 30 74 TSH+6.47 27901.1 20%TW 2014 No No Unchanged since 1996. Object Yes. No signal Foreign c 32 36 BPH+0.58 27901.1 19%TW 2009 change. Object No No Yes. No signal Foreign c 33 17 TSH+2.69 27901.1 20%TW 2005 change. Object No No Yes. No signal Foreign c 34 18 TSH+0.97 27901.1 22%TW 2005 change. Object No No Yes. No signal Foreign c 34 20 TSH+0.91 27901.1 25%TW 2005 change. Object No No Yes. No signal Foreign c 34 74 TSH+0.06 27901.1 27%TW 2005 change. Object No No
' ~ .. *. '<yej'~<< No signal Foreign c 35 19 TSH+0.32 27901.1 29%TW 2005 change. Object No No
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 10 of 14
" *,Max Depth I* Initially' Signal Present P.rior.,to
- t=or~ign
.SG Row Col l.,ocation, 'ErSS Cause Object Plugged?
(%TW) k Reportecl * 'Current Outage?
Re1J1aining?
Yes. No signal Foreign c 35 22 TSH+1.03 27901.1 29%1W 2005 change. Object No No Foreign c 35 30 TSH+0.11 27901.1 35%TW 2005 Yes. No signal change.
Object No No Yes. No change since Foreign c 36 32 BPH+0.55 27901.1 21 %1W 2015 2008. Object No No Yes. No signal Foreign c 36 68 TSH+0.17 27902.1 26%1W 2005 change. Object No No Yes, in 1996 3-coil data. Foreign c 37 31 TSH+0.09 27901.1 26%1W 2011 No change. Object No No Yes, in 2005 +Point' Foreign c 37 32 TSH+0.02 27901.1 23%1W 2011 data. No change. Object No No Yes, in 1996 3-coil data. Foreign c 37 33 TSH+0.04 27901.1 26%1W 2011 No change. Object No No Yes. No signal Foreign c 37 34 TSH-0.06 27901.1 26%1W 2009 change since 1996. Object No No Yes. No signal Foreign c 37 35 BPH+0.60 27901.1 33%1W 2005 change. Object No No Yes. No signal Foreign c 37 54 TSH+0.12 27901.1 24%1W 2005 change. Object No No 7C-0.48 96910.1 13%1W 2005 Yes. No change since TSP c 37 73 initial detection. Wear N/A No 7C-0.52 96910.1 6%1W 2011 Yes, present in 2005 Foreign c 38 32 BPH+0.60 27901.1 26%1W 2011 bobbin data. No RPC. Object No No Yes. No signal Foreign c 38 53 TSH+0.08 27901.1 22%1W 2005 change. Object No No BPH+0.61 27901.1 22%1W 2011 No No
..,* ":-* Yes,:*1:i'resent in 2005 Foreign c 39 32 bobbin data. No RPC. Object BPH+0.60 27901.1 24%1W 2011 No No
. \'*, ?~ ;_; . '. (;:,. '* ,~ . . . ,-
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 11of14 SG
' Row*.i* Co(
Locatio*n ETSS Maxbepth* *Initially . ~ignat. Present Prior to' ' ,- "'
Cause.
Foreign Object Plugged?
(%TW) .Reported Current Outage? .
- ,* ' ~ .. '**'* . ' i* . . '
.. Remaining?
Yes, present in 2005 Foreign c 39 34 BPH+0.57 27901.1 24%TW 2011 bobbin data. No RPC. Object No No Yes, present in 2005 Foreign c 40 34 BPH+0.60 27901.1 22%TW 2011 bobbin data. No RPC. Object No No Yes. No signal Foreign c 44 42 TSH+0.12 27901.1 24%TW 2005 change. Object No No Yes. No signal Foreign c 44 43 TSH+0.19 27901.1 26%TW 2005 change. Object No No Yes. No signal Foreign c 44 47 TSH+0.06 27901.1 26%TW 2005 change. Object No No Yes. Present in 2014 c 44 60 BPH+0.17 96910.1 7%1W 2015 bobbin data with no TSP Wear N/A No change.
Present in 2005 +Point' Foreign c 45 42 TSH+0.26 27901.1 19%TW 2015 data with no change. Object No No TSH+0.23 27901.1 23%TW Yes. No signal Foreign c 45 43 TSH+0.24 27901.1 24%TW 2005 change. Object No No TSH+0.72 27901.1 20%TW Yes. No signal Foreign c 45 47 TSH+0.17 27901.1 23%TW 2005 change. Object No No
- .*. ~ '*
- l'i' ..
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* ' 1l.ocatfon * ,*' >* Volts.
>*' ,, '* .:J'
~ ,:*.DE{~th'1** 1;:*t0r. 9 tt\ *:
1
~
PD'1\,
(
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.
Table 7 - Tube Plugging Summary
.Tube's Plugged, :., *
- . To Date* .* ,. ~
SGA 3,342 30 (0.9%)
SG B 3,342 19 (0.6%)
SGC 3,342 50 (1.5%)
Total 10,026 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 other~.sources is zero. Assuming that the prior cycle operational leakage of <1 GPO originated from belo~(the 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 20~ 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.
Serial No.: 16-196 Docket No.: 50-281 Attachment 1 Page 14 of 14 Acronyms AVB Anti-Vibration Bar BPC Baffle Plate Cold BPH Baffle Plate Hot C/l Cold Lea ECT Eddy Current Testina EFPM Effective Full Power Month ETSS Eddy Current Technical Specification Sheets FOSAR Foreiqn Obiect Search and Retrieval GPD Gallons Per Dav H/L Hot Lea MRPC Motorized Rotatina Pancake Coil NSAL Nuclear Safetv Advisory Letter NTE No tube Exoansion OD Outer Diameter ODSCC Outside Diameter Stress Corrosion Crackinq OVR Over Roll OXP Over Expansion PARC Permanent Alternate Reoair Criteria PLP Possible Loose Part PWSCC Primary Water Stress Corrosion Crackina ?:.~
SC! Single Circumferential Indication
SG Steam Generator SSC Stress Corrosion Crackina TEC Tube End Cold-lea TEH Tube End Hot-lea TSC Top of Tube Sheet Cold-lea TSH Top of Tube Sheet Hot-leq TSP Tube Support Plate TTS Top of Tube&heet TW Throuqh Wall