CNS-17-002, End of Cycle 21 Refueling Outage, Inservice Inspection Report and Steam Generator Inservice Inspection Summary Report

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End of Cycle 21 Refueling Outage, Inservice Inspection Report and Steam Generator Inservice Inspection Summary Report
ML17010A282
Person / Time
Site: Catawba Duke Energy icon.png
Issue date: 01/06/2017
From: Simril T
Duke Energy Carolinas
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
CNS-17-002
Download: ML17010A282 (29)
v • d • e


Text

CNS-17-002 January 6, 2017 U.S. Nuclear Regulatory Commission Attention: Document Control Desk Washington, D.C. 20555-0001

Subject:

Duke Energy Carolinas, LLC (Duke Energy)

Catawba Nuclear Station, Unit 2 Docket Number 50-414 Unit 2 End of Cycle 21 Refueling Outage 1"i0m Simtll M.ce ~ttesid.emt

,Qatawba 1N.Juolear Siatiom

.O.uke ;Ener~y

\\C'~N.O~W'.P 1148!l0 Corncoro :~d v*.sc 29745

,a; $,03_7,Gt.3340 t :80.3.. WU221 11.om.. :Sim.l'll.@duk~nergy.. eom lnservice Inspection Report and Steam Generator lnservice Inspection Summary Report In accordance with Section XI of the ASME Code, please find attached the subject 90-day reports which provide the results of the inservice inspection and the steam generator inservice inspection associated with the subject outage. Note that the Steam Generator lnservice Inspection Summary Report includes all of the information required to be submitted in the 180-day report required by Catawba Technical Specification 5.6.8, "Steam Generator (SG) Tube Inspection Report." Therefore, no additional report is required to be submitted for this outage.

There are no regulatory commitments contained in this letter or its attachments.

If you have any questions concerning this material, please call Dustin Yang at (803) 701-3084.

Sincerely, Tom Simril Vice President, Catawba Nuclear Station Attachments

1. Catawba Unit.2 End of Cycle 21 lnservice Inspection Report
2. Catawba Unit 2 End of Cycle 21 Steam Generator lnservice Inspection Summary Report www.duke-energy.com

Document Control Desk Page 2 January 6, 2017 xc (with attachments):

C. Haney Region II Administrator U.S. Nuclear Regulatory Commission Marquis One Tower 245 Peachtree Center Avenue NE, Suite 1200 Atlanta, GA 30303-1257 J. D. Austin Senior Resident Inspector U.S. Nuclear Regulatory Commission Catawba Nuclear Station M. Mahoney (addressee only)

Project Manager U.S. Nuclear Regulatory Commission 11555 Rockville Pike Mailstop 0-8H4A Rockville, MD 20852 Catawba Unit 2 End of Cycle 21 lnservice Inspection Report

E

-532-5 ReportNwn'ber~--~~----~Ow.ne.r"--

.......... s---Acti!tli......._*~

  • w..__~_.._

fi~or~R~e~fue1i~-"!9---0ul.age...._..

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.......... 0C2~-1-------~~

Plant Ca1aWha ~

&alig 48.00 COOO!Wd Road,. YO!\\ SC W-45 Unit No.

2 Commell'dal seMo9 date 08/1911986 1tf~

~=----

Cwrent nspectlon in See Attachment - Page 2 CUtrentinspectlon period _See

.........._Attach.........,._._me_.....nt~*-P

..... ae.--..e __ 2 ___

-~__,,,....-------------

'1-. 2nd. ltd)

Edition and Addenda of Section XI applicable to the inspection plans See Attachment - Page 2 Date and revision of Inspection plans See Attachment

  • Pages 3 & 4

~---------------------------

Edi tl on and Addenda of Section XI applicable to repair/replacement activities, if different an the inspection plans

~

Code Cases used:

The fdlowing Code Cases are permitted by the ISi Plans:

3rd lnlelval: N-460, N-504-3 N-513-2, N*532*5, N-533-1, N-566-2, N-586-1 N-613-1. N-616, N-624, N-639 N-643-2, N-647, N-663, N-665, N-683, N-685, N*686, N-686-1, N-694-1, N-695, N-696, N-697, N-700, N-706, N-722*1, N-729-1, N-731, N-770-1 4th Interval: N-513-3, N-532*5, N-586-1, N-613*1, N-639, N-643-2, N-648-1, N-663, N*700..1, N*712, N-722-1 N-729-1 N-735 N-747 N-770..1 CERTIFICATE OF CONFORMANCE I certify that (a) the statements made in this report are correct; (b) the examinations and tests meet the Inspection Plan as required by the ASME Code,Section XI; and (c) the repair/replacement activities and evaluations supporting the completion of 2EOC21 conform to the requirements of Section XI.

(ttfueling ~*

tk#l1bet)

Signed AtOTZtJ C. /(ELLf P.

Date 12 /is I ~01<,

r I

CERTIFICATE OF INSERVICE INSPECTION I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State or Province of South Carolina and employed by Hartford Steam Boller Inspection and Insurance Companv of Connecticut have Inspected the items described in this Owner's Activity Report, and state that, to the best of my knowledge and belief, the Owner has performed all activities represented by this report in accordance with the requirements of Section XI.

By signing this certificate neither the Inspector nor his employer makes any warranty, expressed or Implied, concerning the repair/replacement activities and evaluation described in this report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this inspection.

Date 12 /( r U~

I s S!gna!Ufe 1of6 Commissions I > I 'r ' 7,.,.v,..,;.,.,:. r Nabonal Board. State, PrOYtnCe, and Endmements

CA\\SE

-532-5 Attac:ltment Tlh'e Ca'tawtba N11J~learr Sfaii©fll lUll11'i 2 llhim!I Tem Yeari linls'e~fo:e lrnspedf©n <<SE) Prarm coormpll~ wrnlhi 111JCFR50. 55a ~g),, wfiri~fill f11111prerme11T~s. l\\),)f rref.erielil'ce, tfile Ameriica1111 ~ciefy oi Meclillani~--a ll Eirrgfrneeris.

(ASME) Bcoileri and Priess11Jrie Vessell Co(!fe, Sedi©ll1l Xm,, 119*98 Edlftiorril wi~lhl 200'0 Addern:m.

n1e Catawba Nodearr Statf0111U1111it2 IF'011J*lf1!1hl Terril Ye'arr ~11serivfce lrnspedio1111 (ISi) Pl1a1111 c0mprfes witilhl 10CFR50.55a(g), wMd11 rmpfemernlts,, ti:iw rief.erieli1'ce, the American Society of Mechanrcall ErngJliTeeris (ASME) Boiler and Priess re Vessel C0<ife', Sectime XI, 2007 Edftico1111 with 2008 Addendal.

This summary report ~s being submitted pt1rrsuant to the reporting requirements of ASME Section XI a,s amended by ASME Code Case N-532-5, '"Repair/Replacement Activity Doc1Jme11tatton Requirementis allTd lnservice 111spectfon Summary Report Prepara~fon and Submission Section XI, Division 1",

Contained within thi:s summary report are the form OAR-1 (Owner's Activity Report) and labl'es. 1and2 of Code Case N'-532-5 for Catawba Nuclear Station during Cycfe 22 and Refueling Outag:e 22 (2EOC21).

2EOC21 is the third and Jast outage of the third period in the third inspection interval and includes the Repair/Replacement acUvities from April 5, 2015 through October 9,. 2016. Additi.onally, 2EOC21 i*s the first outage of the first period in the fourth inspection interval.

2 of 6

CASE

-532-5 Catawba l\\Jniit 2 E11t<ill of Cycre 21 llnsen1ice lnspec:tion Re:poll1:

t.

Third fntel'iVat fnsewice f111spediollll Plans.

1. The followirrtg docamrein1is compirtse fhe Ca1iaw!iJa N dear Station 3r~ Interval llilsew i.ce losp-ecfii*ol!ll Plan for Unit 2 {C,ass 1, 2, andl 3 Cmmpolil'elil~S}:
a. Third lmerval lnsewice llll1spectroli1 Plan CataiWba Nuclear Station Units 1 and 2 Geneiral Requirements, IJocument #CISl-141.62'.10-0030-GEN RIEO, Rev. 1, dated 06!2612008, including the following adderTdia:
i. CllS!-1462.10-0030-3CNS-021 through CllSf-1462.10-0030-JCNS-038
b. Catawba Nuclear Station Uniif 2-Thirdl Inspection Interval lnservice Inspection NDE Plan, Document #CISl-1462.10-0030-UNIT 2, Rev. 1, dated 06/26/2008, including the following addenda:
i.

CISl-1462.10-0030-3CNS2-028 through CISl-1462.10-0030-3CNS2-090

2. The following documents comprise the Catawba Nuclear Station 3rd Interval lnservice Inspection Pressure Test Plan for Unit 2:
a.

Third Inspection Interval lnservice Inspection Pressure Test Plan for Catawba Unit 2, Document #CISl-1462.20-0020-U2PTPLAN, Rev. 0, dated 02/21/2006, including the following addenda:

i.

CISl-1462.20-0020-C2-PT-024 through CISl-1462.20-0020-C2-PT-046 II.

Fourth Interval lnservice Inspection Plans

1. The following documents comprise the Catawba Nuclear Station 41h Interval lnservice Inspection Plan for Unit 2 (Class 1, 2, and 3 Components):
a. Catawba Nuclear Station Unit 1 and Unit 2 - Fourth Interval lnservice Inspection Plan, Document #CISl-1462.10-0040-ISI PLAN, Rev. 1, dated 08/12/2015.
b. Catawba Nuclear Station Unit 2-Fourth Inspection Interval lnservice Inspection Outage Schedule Catawba Nuclear Station, Document #CISl-1462.10-0040-UNIT 2, Rev. 0, dated 08/13/2015 including the following addenda:
i. CISl-1462.10-0040-4CNS2-001 through CISl-1462.10-0040-4CNS2-004
2. The following documents comprise the Catawba Nuclear Station 4th Interval lnservice Inspection Pressure Test Plan for Unit 2:
a. Fourth Inspection Interval lnservice Inspection Pressure Test Plan for Catawba Unit 2, Document #CISl-1462.20-0040 - PTPlan, Rev. 0, dated 06/24/2015 including the following addenda.
i.

CISl-1462.20-0040-C2-PT-001 3 of 6

CASE N-532-5 If ~

Cc!Jmtafn*emt fns'ewi~e nspe:c-.n Pa il. Tlhe ftl)fl.©.wi llTg d({t<e1\\J rrmelilt ct\\lf!11Tl!Jrrf ses lillte C:a:ta~lb"ai ~111cl~rr S:tai!i~lill 3'""

1 Erit:te.lf'IPafi Colffit'ai 111'1iiil'elitl1t

~111'Self'ilice Elil:sl!)edfo:tn1 Platni ffoir l\\.JJ111'ifi 2 <<Clgss; l\\\\AXC):.

a.

Cata~ Noclearr Sfatii'o'l!ll l\\.JJ111'ils; ii allTdl 2-lllrirrdl ltn~etr11al Con~aiorrmern tt tn!Serr~fo:'e hts~ectf({tlill Pfal!l\\. Docl\\Jlme111111:#C:N-ESEC:3l-i1©14l2-©XD©lil,, Re.'¥. 4l. dialfecdl il2Jll1'5J2l0lil6_

4 of 6

CASE:

N-532-5 Cattawba IN:UJ<i:fearr lUrni:ti: 'l IF<crlim OAR-1 Owmerrs Ad~itw Rep<Drrt lablei 1 Items wi!ttlhl IF aws orr Rere.v.ant Corn:drrtf ©n:s that Reqjuf rredl 1Ewarua1tfon foli Conrtiintued Service Exiamf 1i1'a'1ifo1111 I

tC'ateg~q alildl Item Descnptro1111 Evaruation Desc:riptron ltemN11Jmber VE e'X'ami'lif<<lfi©lili ire'ilealed ewid 1e11tce <ilf' ccno.si'<illili AUG f IB\\11~. S©l C.Z.B15.. 8@0mn / 2RP'V-BMll-NOZZllES a1111!fi s~filifg

©li'I l'ower itead.

Erngi'neeril'l'gl Eval\\uati'©lili fol!Jllfdl to be ac<eepfable.. ReforeliTl:e' N'.CR# 2'©'606112..

Vf-3 e%amill1'ati©li!I ie'Ve'a'Fed tite i1anger* rod was F-/HIF11.W C2.F1.2HJ027 I Z-R-ND-01401

!©ose. WO# 2011110941 tigi1tened li1e loose rod.

Engi111eerlll1'9 E\\1a fl!la~ i01"1 fo1tmd to be acc:epfable.

Reference NCR# 2002327.

vr~3 e%amfnation reveafed a missing snap ring F'-AfF1.W CZ.F1.. 20.0070 I 2-R-NV-H W at Ule re'ar braclk.el pin1. WO# 20110520 replaced lite sl'l'ap ring..

Engineering Evaluation found to be acceptable. Reference NCR# 2061153.

Vf-3' examination' revealed tile middle bolt on the pipe clamp had a loose lock nut. WO# 20110940 F-A I F1.22 C2.F1.220013 / 2-R-ND-0025 lightened the loose rock nut.

Engineering I

Evaluation found to be acceptable. Reference NCR# 2002329*.

VT-3 examination revealed loose lock nuts and tack of full thread engagement associated with the turnbuckle assembly.

WO# 20032426 F-A I F1.40 C2.F1.40.0092 / 2RPV-CRDM tightened the loose lock nuts and verified full thread engagement for the turnbuckle assembly.

Engineering Evaluation found to be acceptable.

Reference NCR# 2060571.

VT-2 examination revealed boric acid residue on B-P/815.1 0 ISi Class A Bolted Connection - IWA-5241 (f) valve 2Nl-157. Engineering Evaluation found to be acceptable. Reference NCR# 2060504.

VT*2 examination revealed boric acid residue on NC Pump 2A Seal Housing and lncore B-P/815.1 0 C2.B15. 10.0001 / 2NC-001 L-A Instrumentation Tubing. Engineering Evaluation found to be acceptable. Reference NCR#

2068192.

VT-2 examination revealed boric acid residue on C-H/C7.10 C2.C7. 10.0013 / 2ND-002L-B inlet flange of valve 2ND-38 and 2B ND Seal Housing. Engineering Evaluation found to be acceptable Reference NCR# 2060511.

VT-2 examination revealed boric acid residue C-H/C7.10 C2.C7.10.0028 / 2NV-001 L-B valve 2NV-11A Engineering Evaluation found to be acceotable. Reference NCR# 2068192.

5 of 6

CASE N-532-5 Catawba IU'ccfearr UITTi 2 Farrm O.AR-1 OWrreirs Adi~i'ti.Sf Repcirrt Tabfe2

.Abstraccl' cifi Repai*irJR.ep~acement.Activi~tes Re<q; 11red Farr C©'ntinl!Jed Sewrce Code Item Descripfio1111 Description of WOtrfl.

Date Compfetedl I Repair I Repfaument CFass PFan Number*

2' React0r C'00ranfi System flbw Repair leak o" f11Jbin91 f<ill ID9'm'IZ~116l 02111279-01 hal!!Smitte ~ tuli1frTGI 2NCFT5080 2

Steam Gene~ato~ Blowd'ow ReJi!l'ac:e vai\\Je 112" 288-12' and!

1!19t2'11/2(1)1tl&

I 20011859-01 Rec;:vde ~stem Vall.re 288-12' ofoirto assemblv: dl!Je to leak 6 of 6 Catawba Unit 2 End of Cycle 21 Steam Generator lnservice Inspection Summary Report

Steam Generator In-service Inspection Summary Report Catawba Nuclear Stati.on Unit2EOC21 September 2016 Location: 4800 Concord Road, Yorlc South Carolina 29745 NRC Docket No. 50414 National Board No. 173 Commercial Service Date: August 19, 1986 Owner: Duke Energy Corporation 526 South Church St.

Charlotte, N.C. 28201-1006 Revision 0 Prepared By: Chuck Cauthen _j/1 ~Date: It -~ - ~f)/ (p

(

Reviewed By: Dan Mayes {:;) ~ f'h1 ~"" Date: rz! b( 'ZO Jl.

Approved By: E!ienl!!! FQn1!2n@

Date:

\\ -Z.' 8.. 2..0\\ lo Page 1 of 19

FORM OAR-1 OvVNER'S ACTIVITY REPORT CA~E N-532-5 Report Number ____

o_w_n_e_r_s_A_c~t_iv~ity~

.. _R_e~p~o_rt_~~or_S~t~e~a_m~G~e_n~e~ra~t~o~r~ln~s~p~ec~t~io~n_O~u~ta~g~e~2_E~O~*~c_2_1-,-__ _

Plant Catawba Nuclear Station, 4800 Concord Road; York, SC 29745 I

Unit No.

Commercial service date -------

Refueling outage no.

2EOC21 2

08/19/1986 (If applicable)

Current inspection interval _Fo_u_rt_h_ln_te_rv_a_l ______ __,.,...,..,,.--=-=...,..,,,,--.,,......,------------

11st 2nd. 3rd, 4th, other)

Edition and Addenda of Section XI applicable to the inspection plans 2007 Edition through 2008 Addendum Date and revision ofi,nspection plans August 19, 2015, Revision 0 (Documerit#C-ISIG-0169.030.0040)

Edition and Addenda of Section XI applicable to repair/replacement activities, if differei:it than the inspection plans Same as Plan CodeCasesused: ---'N~*~53~2~*5.__ __________ =-....,,......,..,..,__ ________________ _

(if applicable)

CERTIFICATE OF CONFORMANCE I certify that (a) the statements made in this report are correct; (b) the examinations and tests meet the Inspection Plan as required by the ASME Code,Section XI; and (c) the repair/repl~cement activiti.es and evaluations supporting the completion of 2EOC21 conform to the requirements of Section XI.

(refueling outage number)

Signed Date 1z-1.z-_,z&I?

CERTIFICATE OF INSERVICE INSPECTION I, the undersigned, holding a valid commission issued by the National Board of.Boiler and Pressure Vessel Inspectors and the State or Province of South Carolina and employed by Hartford Steam Boiler Inspection and Insurance Company of Connecticut have inspected the items described in this owner's Activity Report, and state that, to the best of my knowledge and belief, the Owner has performed all activities represented by this report in accordance with the requirements of Section XI.

By signing this certificate neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the repair/replacement activities and evaluation described in this report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this Inspection.

~

~--?-

Commissions IS ti lo, 'I. N, A, 1. S

-c:-:::::=-=-----E~=::=~;:::pect::::;::or';:-~~gnta=tu=re_________

National Boa'rd, Staie, Province, and Endorsements Date IZ/fs {Jb Page 2of19

CASE N-532-5 Catawba Nuclear Unit 1 Form OAR-1 Owner's Activity Report Table 1 Items with Flaws or Relevant Conditions that Required Evaluation for Continued Service Examination Category and Item Description Evaluation Description Item Number No ASME Section XI Category 8-Q Steam Generator Tubing in U-Tube Design Acceptance Requirement 816.20 Exceeded (Reference Attached Inspection Report)

Catawba Nuclear Unit 1 Form OAR-1 Owner's Activity Report Table 2 Abstract of Repair/Replacement Activities Required For Continued Service Code Item Description Description of Work Date Completed Repair I Replacement Class Plan Number Steam Generator 2A Plugged and stabilized 16 1

(2 NC HXA) tubes via rolled plug and wire 10/09/2016 20032784-07 rope stabilizer Steam Generator 28 Plugged and stabilized 13 1

(2 NCHX 8) tubes via rolled plug and wire 10/07/2016 20032783-07 rope stabilizer Steam Generator 2C Plugged and stabilized 12 1

(2 NC HX C) tubes via rolled plug and wire 10/07/2016 20032782-07 rope stabilizer Steam Generator 20 Plugged and stabilized 6 tubes 1

(2 NC HX D) via rolled plug and wire rope 10/07/2016 20032781-07 stabilizer Page 3of19

Catawba 2 EOC21 Steam Generator Tube Inspection Report (reference Catawba technical Specification 5.6.8)

Summary of inspections and inspection results:

a) The scope of inspections performed on each SG The inspection scope for all four steam generators was as follows:

Bobbin Inspection

  • 100%/ull length (except Row 1-5 U-bend region)
  • Row 1-5 hot leg straight section
  • Row 1-5 cold leg straight section
  • Tubes surrounding plugged tubes full length Array Inspection 100% TTS hot leg (I'EH to TSH + 3 ")

TTS hot leg two tubes deep periphery, including the T-slot and open lane (I'EH to OlH or 02Hfor the baffle cutout)

TTS cold leg two tubes deep periphery, including the T-slot and open lane (I'EC to l 8C

+3.)

50% Row 1-5 U-bends (includes any tubes not examined in 2EOC19 or 2EOC20) 08H to 09C 20% Row 10 U-bends-08H to 09C Hot and cold leg straights for all tubes screened as 2 Sigma

  • Expanded baffles at TSP l 7C and l 8C with extent of+/- 3" at each support plate (20%

sample of expanded baffles not examined in 2EOC17 - 2EOC20)

  • 100% DNT sample Array Special Interest
  • All tube locations with indication calls that required Array sizing from 2EOC20
  • Tubes with PLP calls as well as a bounding inspection of one tube deep. For PLP indications with tube degradation bounding inspection of two tube deep
  • Bounding inspection 2 tubes deep surrounding known foreign object locations
  • New wear indications
  • All bobbin I-codes
  • New DNT calls Page 4of19.

Visual Inspection Previously installed plugs Bowl cladding inspection Foreign object search and retrieval (FOSAR) of the tubesheet in all 4 steam generators.

b.

Degradation mechanisms found Degradation found included wear at support structures; wear from foreign objects and crack-like indications near the tube ends.

c.

Non-destructive examination techniques utilized for each degradation mechanism The bobbin probe was utilized for the detection of wear at support structures and freespan locations and to size wear at support structures. The array probe was used for detection of indications within the tubesheet, U-bend regions, and the 2 sigma high stress tubes. The array probe was used to size the foreign object wear.

d. Location, orientation (iflinear), and measured sizes (if available) of service induced indications.

The complete listing for service induced indications is attached.

Tubes with anti-vibration bar wear indications SG 2A - 81 tubes/153 indications SG 2B-25 tubes/38 indications SG 2C - 54 tubes/79 indications SG 2D - 72 tubes/] 09 indications Total-232 tubes/379 indications Tubes with tube support plate wear indications SG 2A - 5 tubes/5 indications SG 2B - 8 tubes/8 indications SG 2C - 2 tubes/2 indications SG 2D - 1 tubes/I indications Total-16 tubes/16 indications 15 broached TSP wear-I baffle plate wear Tubes with tube presumed foreign object wear indications SG 2A - 8 tubes/8 indications SG 2B - 17 tubes/18 indications SG 2C-2 tubes/2 indications SG 2D - 6 tubes/6 indications Total-33 tubes/35 indications Page 5of19

Tubes with crack like indications within the tubesheet at the tube end SG 2A - 18 tubes/19 indications SG 2B - 215 tubes/221 indications SG 2C - 22 tubes/22 indications SG 2D - 45 tubes/47 indications Total-300 tubes/309 indications

e.

Number of tubes plugged during the inspection outage for each degradation mechanism Steam Generator 2A:

There were sixteen (I 6) tubes plugged. Four tubes were plugged due to a foreign object The remaining tubes were high stress tubes or two sigma tubes. The tubes plugged were as follows:

2ASG Count Row Tube Reason I

11 83 Hi?;h stress tube 2

11 84 Hi2h stress tube 3

11 78 Hi?;h stress tube 4

12 99 Hi2h stress tube 5

12 107 Hi2h stress tube 6

13 109 Hi2h stress tube 7

16 44 Hi2h stress tube 8

16 105 High stress tube 9

17 27 Hi2h stress tube JO 21 51 Hi?;h stress tube 11 35 50 Hi2h stress tube 12 48 67 High stress tube 13 48 81 Downstream of the forei2n object 14 48 82 Downstream of theforeif!,n object 15 49 81 Foreif!n object 16 49 82 Foreign object with wear Page 6of19

Steam Generator 2B:

There were thirteen (13) tubes plugged. All were high stress tubes or two sigma tubes.

The tubes plugged were as follows:

2BSG Count Row Tube 1

23 104 2

24 50 3

24 55 4

24 53 5

24 45 6

26 78 7

26 79 8

28 77 9

30 76 10 32 89 11 34 68 12 36 52 13 36 48 Steam Generator 2C:

There were twelve (12) tubes plugged. All were high stress tubes or two sigma tubes.

The tubes plugged were as follows:

2CSG Count Row Tube 1

17 87 2

17 17 3

20 94 4

21 93 5

24 36 6

24 40 7

24 26 8

27 45 9

27 26 10 29 41 11 36 96 12 36 98 13 36 48 Steam Generator 2D:

There were six(6) tubes plugged. All were high stress tubes or two sigma tubes.

The tubes plugged were as follows:

2DSG Count Row Tube 1

24 26 2

25 25 3

29 19 4

38 59 5

39 82 6

41 53 Page 7of19

f.

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

Steam A

B c

D Total Generator1 Prior to 69 118 65 91 343 EOC21 EOC21 16 13 12 6

47 Total 85 131 77 97 390

%Plugged 1.86 2.86 1.68 2.13 2.13 1= There are 4578 tubes per steam generator

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

The cumulative EFPYfor EOC-18 was 21.5, EOC-19 was 22.89 and EOC-20 was 24.24 and EOC-21was25.67.

Condition monitoring was met for all degradation. All structural performance criteria were met for wear with more than adequate margin projected through the next planned inspection at EOC2 3. All structural performance criteria requirements were met for possible new ODSCC indications at TSP locations with margin projected through the next planned inspection at EOC23.

No new foreign objects were identified. All historical foreign objects that were not removed have a technical evaluation demonstrating that tube integrity will be met through the next scheduled inspection of this region at EOC23.

An upper bundle visual inspection was performed in the steam generator 2A, no degradation was detected.

No degradation was detected in the plug visual.

Bowl cladding inspections did identifY an area of missing stainless steel cladding in the Catawba Unit 2 D SG hot leg channel head. It was located over the nozzle on the channel head JO 112 inches/ram the divider plate and 8 112 inches/ram the tubesheet, 4 112 inches from the tubesheet lip at the interface of the machined cladding and as-welded cladding. The area was 5 118 inches long and 15/16 inches wide and irregular in shape.

Base metal is present in the area but no evidence of significant wastage. The maximum depth (from the cladding surface to the exposed base material) identified was 0.234 inch.

No repair is planned. Analysis supports operation until the next planned inspection at EOC 23. There was no degradation detected in any of the other bowl cladding inspections.

No in-situ tests or tube pulls were performed.

Page 8of19

h. For Unit 2, the primary to secondary LEAKAGE rate observed in each SG (if it is not practical to assign 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.

There was no primary to secondary leakage above detection limits during the preceding Cycle 21 operation.

1.

For Unit 2, the calculated leakage rate from the portion of the tubes below 14.01 inches from the top of the tubesheet for the most limiting accident in the most limiting SG. In addition, if the calculated accident leakage rate from the most limiting accident is less than 3.27 times the maximum primary to secondary LEAKAGE rate, the report shall describe how it was determined.

There was no calculated leakage from the portion of the tubes more than 14. OJ inches from the top of the tubesheet, for the most limiting accident in the most limiting SG.

J.

For Unit 2, the results of monitoring for tube axial displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.

No indications of slippage were detected.

Page 9of19

List of Service Induced Indications Catawba 2, EOC-21 The complete listings of service induced indications are on the following pages. The codes and their descriptions used in the inspection data base are provided here to assist in review of these lists.

Indication Code MAI MCI PCT SAI SCI SVI WAR Description Multiple Axial Indication Multiple Circumferential Indication Percent Indication Single Axial Indication Single Circumferential Indication Single Volumetric Indication Wear Page 10of19

Catawba Nuclear Station 2 2EOC21 DDP 20160901 11/02/2016 16' 11, 02

+-----------+----+----+---------+----+----+----+-----+----+---------+----+---------+---------+---------+-------+-------+----+----+------+------+------+--+-----+

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Catawba Nuclear Station 2 2EOC21 DDP 20160901 11/02/2016 16: 11: 02

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Tubes: 93 Records: 169 ST Max Page 13of19

eatawba Nuclear Station 2 2EOC21 DDP 20160901 11/02/2016 16: 11: 01

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ST Max Page 14of19

Catawba Nuclear Station 2 2EOC21 DDP 20160901 11/02/2016 16' 11, 01

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2 Tubes: 50 Records: 64 ST Max Page 15of19

Catawba Nuclear Station 2 2EOC21 DDP 20160901 11/02/2016 16: 11: 01

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  • catawba Nuclear Station 2 2EOC21 DDP 20160901 11/02/2016 16' 11, 01

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2 Tubes: 58 Records: 83 ST Max Page 17of19

Catawba Nuclear Station 2 2EOC21 DDP 20160901 11/02/2016 16: 11: 02

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Tubes: 79 Records: 116 ST Max Page 19of19

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