ML13329A424
| ML13329A424 | |
| Person / Time | |
|---|---|
| Site: | Indian Point  |
| Issue date: | 10/30/2013 |
| From: | Lo K Entergy Nuclear Operations |
| To: | Office of Nuclear Reactor Regulation |
| Shared Package | |
| ML13329A422 | List: |
| References | |
| NL-13-147 IP-CALC-13-00062, Rev 1 | |
| Download: ML13329A424 (23) | |
Text
ENCLOSURE 1 TO NL-13-147 IP-CALC-13-00062, Ri EVALUATION OF LEAK AT LINE 1093 IN UNIT 3 MOAT ENTERGY NUCLEAR OPERATIONS, INC INDIAN POINT NUCLEAR GENERATING UNIT NO. 3 DOCKET NO. 50-286
ATTACHMENT 9.2 ENGINEERING CALCULATION COVER PAGE Sheet 1 of 2 El ANO-1 LI ANO-2 LI GGNS LI IP-2 E IP-3 E3 PLP El JAF El PNPS El RBS El VY i]W3 EL NP-GGNS-3 EI NP-RBS-3 CALCULATION (1)EC # 4-1 ";A (21Page 1 of 7 COVER PAGE (3)Design Basis Caic. El YES H NO (4) Ej CALCULATION El EC Markup (5) Calculation No: IP-CALC-13-00062 Revision: I (7)
Title:
Evaluation of Leak at Line 1093 in Unit 3 Moat Editorial EL YES Z NO 9 System(s): SW (10) Review Org (Department): Civil/Structural (ii) Safety Class: (12) Component/Equipment/Structure Type/Number:
Related
[ Safety / Quality Line 1093 El Augmented Quality Program E- Non-Safety Related (13) Document Type: CALC (14) Keywords (Description/Topical Codes):
SW REVIEWS (15) Name/Signature/Date (16) Name/Signature/Date. * (7) Name/Sntre/ e Kai Lo 10-30-2013 /e*7 G. Bhalla 10-30-2013 4A,=.w R. Drake Responsible Engineer El Design Verifier "j02') Supeliisor/ApprQv4 I El Reviewer El Comments Attached El Comments Attached EN-DC-126 REV 4
ATTACHMENT 9.3 CALCULATION REFERENCE SHEET Page 2 of 7 CALCULATION CALCULATION NO: IP-CALC-13-00062 REFERENCE SHEET REVISION: 1 I. EC Markups Incorporated (N/A to NP calculations) 1.
2.
3.
4.
5.
II. Relationships: Sht Rev Input Output Impact Tracking Doc Doc Y/N No.
- 1. 0_
0
- 2. 0 0[]
- 3. 0 0
- 4. ]0 0_
- 5. 0 0]
Ill. CROSS
REFERENCES:
- 1. ENN-DC-1 85, 'Through-Wall Leaks in ASME Section XI Class 3 Moderate Energy Piping Systems"
- 2. EN-CS-S-008-MULTI Rev. 0, "Pipe Wall Thinning Structural Evaluation"
- 3. ASME Code Case N513-3
- 4. USAS 831.1, Power Piping Code, 1967 & 1973
- 8. UT report IP3-UT-13-058
- 9. VT report IP3-VT-13-021 IV. SOFTWARE USED:
Title:
Version/Release: Disk/CD No.
V. DISK/CDS INCLUDED:
Title:
Version/Release Disk/CD No.
VI. OTHER CHANGES:
EN-DC-126 REV 4
ArrACHMENT 9.4 RECORD OF REVISION Page 3 of 7 Revision Redordof Revision Initial issue.
0 Revised cover page 1, through 5 based on VT report IP3-VT-13-021.
Revised Attachment A, page 4 and 5.
EN-DC-126 REV 4
LIST OF EFFECTIVE PAGES Page 4 of 7 Calculation Number: IP-CALC-13-00062 Revision Number: 1 PAGE REV. PAGE REV. PAGE REV.
All 0 1 to 5 0 6,7 1 Att. A p.1 to 3 Att. A p.4, 5 0 Att B p. 1 to 7 0 1
Att B p. 8, 9 1 EN-DC-126 REV 4
TABLE OF CONTENTS PAGE 5 OF 7 Towic Page No.
1 Calculation Cover Page .................................................................. 1 2 Calculation Reference Sheet ................................................................ 2 3 Record of Revisions .................................................................. 3 4 List of Effective Pages ................................................................. 4 5 Table of Contents .................................................................. 5 6 Calculation Section ................................................................ 6 6.1 Background ...................................................... 6 6.2 Purpose. . ...... I............................ ................... 6 6.3 Method of Analysis ........................................................ 6 6.4 Assumptions ............................................................... 6 6.5 Design Input ................................................................. 6 6.6 References ........................................................ 6 6.7 Calculation ......................................................... 6 6.8 Results/Conclusions ................................................................ 7 Attachment A: Calculation (5 pages)
Attachment B: Miscellaneous (9 pages)
Total number of pages: 23 pages EN-DC-126 REV 4
6.0 Calculation Section Page 6 of 7
6.1 Background
On October 3, a through wall weeping leak was identified and later determined not to be an active leak on the 10"-
1093 pipe in the Unit 3 moat in the transformer yard. An area was identified of missing metal of the pipe wall thickness approximately equals to 3/4" x 3". The degraded pipe location is in the ISI code boundary.(See CR-IP3-2013-04174). There are two other areas approximately 20 feet away that show evidence of external corrosion.
Structural operability evaluation is needed.
On October 29, after the removal of the support and coating on the pipe to facilitate the installation of a temporary repair clamp (EC-47124), the portion of the defect that is close to the bottom of pipe became more accessible.
The length of the defect along the circumferential direction was found to be 8.25" (IP3-VT-13-021) instead of 4.75" (IP3-UT-13-058).
6.2 Purpose The purpose of this calculation is twofold:
- 1. To determine the allowable through wall flaw length per ASME CC N-513-3. If the actual flaw including the leak is less than the allowable flaw length, then the pipe will be structurally adequate and operable.
- 2. To determine the minimum required pipe wall thickness per EN-CS-S-008-MULTI for the two areas that show external corrosion.
6.3 Method of analysis
- 1. The pipe is typically buried but is temporary supported every 8 feet. The pipe's bending stress is based on the 8 feet pipe span. The equivalent static method using the peak seismic acceleration from the ground response spectra is used in the determination of the pipe stress.
- 2. The pipe wall thickness around the 2" by 8.5" defect is based on 0.319", 87.5% of the nominal pipe wall thickness basing on the UT and VT report. The lowest of the five UT readings is 0.378" and visually the pipe surface around the defective area is in good, un-corroded condition.
- 3. For the through wall indication location, the allowable flaw length in the circumferential and axial direction are determined per CC-N513-3.
- 4. The minimum pipe wall thickness is determined based on EN-CS-S-008-MULTI. The lowest UT thickness from the two externally corroded locations is compared to the minimum required pipe wall thickness and the remaining service life is determined.
6.4 Assumption.
- 1. For the through wall indication location (area#3), the adjusted wall thickness is the average value of the five UT readings around the defective area (2.5" by 4.75"), namely 0.382". The calculation conservatively uses 0.319". This value is judged to be conservative for the good, non-corroded metal surface around the newly found, lengthened defect area identified in the IP3-VT-13-00021.
- 2. For the average circumferential pipe wall thickness at the leak location area #3, 80% of the pipe's nominal wall thickness is used. This is conservative because the wall thinning is externally induced by failed coating and is usually localized around the damaged coating location.
6.5 Design Input
- 1. Pipe Specification TS-MS-027
- 2. USAS B31.1, Power Piping Code, 1967 & 1973
- 3. Drawing 9321 -F-22363 EN-DC-126 REV 4
Page 7 of 7
- 4. UT report IP3-UT-13-058
- 5. VT report IP3-VT-13-021 6.6 Reference
- 1. EN-CS-S-008-MULTI Rev. 0, "Pipe Wall Thinning Structural Evaluation"
- 2. ASME Code Case N513-3
- 3. USAS B31.1, Power Piping Code, 1967 & 1973
- 4. ASME B & PV Code,Section XI, 2001 edition
- 7. UT report IP3-UT-13-058
- 8. VT report IP3-VT-13-021
- 9. EC 47127 6.7 Calculation See Attachment A.
6.8 Conclusion
- 1. Based on CC-N513-3, with an adjusted pipe wall thickness of 0.319", the allowable thorough wall flaw length in the circumferential direction is 9", greater than the measured 8.25"; the allowable thorough wall flaw length in the axial direction is 4.7", greater than the measured 2.5". The pipe is structurally adequate and operable. For 1.5 year of service until the outage, with an estimated average corrosion rate of 12 mils per year, the estimate flaw will be 2.54" axially and 8.29" circumferentially.
- 2. The minimum pipe wall thickness per EN-CS-S-008-MULTI is 0.073", less than the UT measured lowest reading of 0.109" at area #2 & 3. The remaining service life is 4.6 years unless if damaged coating is not repaired.
- 3. The original CR has identified occasional intermittent weepage at location area 1 at node point 4 on the weld. This has been identified as a pin hole leak with the entire area above the minimum wall thickness.
This area is enveloped by the previous CCN513-3 evaluation for area 3.
EN-DC-126 REV 4
Attachment A EN-DC-126 REV 4
IP-CALC-13-00062 Rev. 0 Page -/ of 5, P = design pressure = .150-' psi D outside diameter = .10.75 :in t nominal wall thickness = 0.365,jl in S =section modulus= 29 .9ý'l- in3 L = pipe span = 8t5! ft = 96 in w uniformn weight of pipe, water & cement lining= 844,2 plf 7.017 #/inich Conservatively consider the pipe as simple support Ma = moment due to DW = wL 2/8 = 8083 in-lb Ma/S = 270 psi For P + DW:
the leak section is at a straight pipe 0.75i.
PD/4t = 1104 psi PD/(4t) + 0.75i(Ma/S) = 1375 psi < Sh =15000; . psi Using the peak G from DBE ground response spectra for 0.5% damping MRM = multi modal response multiplier = ,It.
Gh = horizontal seismic acceleration -04...
Gv = vertical seismic acceleration =,2. 42*'.
Gr = [Gh2 + Gv 2]0-5 = 0.769 MRM(Gr) = 1.154 Mb = seismic moment = MRM(Gr)(Ma) = 9326 in-lb Ma+Mb= 17409 in-lb PD/(4t) + 0.75i(Ma + Mb)/S = 1687 psi < 1.8Sh 2 700 Ipsi For OBE MRM = multi modal response multiplier ---....-.,............. ;* !
Gh horizontal seismic acceleration= ,.427,-:
Gv vertical seismic acceleration - .284 Gr =[Gh2 + Gv2 jI' = 0.513 MRM(Gr) = 0.769 Mb = seismic moment = MRM(Gr)(Ma) = 6217 in-lb Ma+Mb= 14301 in-lb PD/(4t) + 0.75i(Ma + Mb)/S = 1583 psi < 1.2Sh 8000: psi
IP-CALC-13-00062 Rev. 0 Page Zo__of
- 1. Design Parameters (Boxed values are input)
D.: Outside Diameter, (in) 10.75 t.om.,: Nominal Thickness, (in) 0.365 Material A53 Gr B P: Design Pressure, (psi) 150 T : Design Temperature, (OF) 160 S*: Allowable Stress at Design Temperature, (psi) (See App. A of B31.1) 15000 SA: Thermal Expansion Allowable Stress, (psi) 22500 A : An additional thickness per Section 104.1 of B31.1, (in) 0
- 2. Prediction of Min. Thickness at Next Inspection, tp t,,,,: Measured thickness of latest inspection, (in) lowest Wr: Wear Rate (in/yr)
Y : Service years between the latest and next inspections, (yr)
SF : Safety factor (1)
Projected thermal cycles between the latest and next inspections tp = tmas - SF*Wr*Y, (in) 0.0973 RJtp < 50, "OK"; or > 50, "Buckling Evaluation Required" R,/t, 55 Buckling Eval Req b = estimate width of thinned section = 2 12.30 Based on clamp support at 4 edges, allowable buckling stress = 8.46E(tp/b) 14760 psi < Sh Actual compressive stress= [S or- PD/(4tnom)I(tnom/t'p)T('li) 1014 psi, o.k. 15000 2
Actual compressive stress = [S1, - PD/(4tnorn)](tnoD/t'p)(l'/i) 1795 psi, o.k.< 1. Sh = 18000 Actual compressive stress = [Semg - PD/(4tmom)](tnom/t'p)(r/i) 2185 psi, o.k.< 1.8Sh z 27000
- 3. Screening Rules for Pipe Wall Thinning Rule 1: Acceptance Standard = 0.875*thor. 0.319 Rule 2: Minimum Required Thickness (2),(3) 0.3*tnor for Class 1 0.110 0.2*t,,. for Class 2 or 3 0.073 Rule 3: Between the above two limits, wall thinning can be accepted by a structural evaluation Action required based on the above screening rules for the inspected thinned pipe Class 1 piping Replace or repair Class 2 or 3 piping Structural Evaluation Req'd
- 4. Structural Evaluation
- a. Minimum Thickness for Hoop Stress i trin = P*Do/[2(Sh+.4*P)] + A , (in) 0.054 (4)
- b. Minimum Thickness for Axial Stress :
Is the thermal expansion stress required to be evaluated? Yes
( No for tp > 0.75*t,~, and cycles < 150; Yes for otherwise)
KNor : Allowable stress increase factor for Normal Condition KL, Allowable stress increase factor for Upset Condition KErgn: Allowable stress increase factor for Emergency Condition y: Allowable stress increase factor for CC-N-597
IP-CALC-13-00062 Rev. 0 Page _____of S Original Piping Stresses SNo: Normal Condition Stress, (psi) 1375 Sups: Upset Condition Stress, (psi) 1583 SErng : Emergency Condition Stress, (psi) 1687 SThe: Thermal Expansion Stress, (psi) 0 Let tan ).
- (5) iV/ = 1.000 4 4 ZiZ' = .4 - (Do-2tnom) /(Do 4 - (DO-2tar") ] (6) 11.45 Allowable Stress - Axial Stress > 0 Normal conditions: y*KNor*Sh - [ P*Do/4tamin + ("'/i) (SNor - P*DJ4tom)*(Z/Z')] > 0 148 Upset conditions: y*Kups*Sh - [ P*DoI4t1mi, + (i'ii)*(Sups - P*Do/4tnom)*(Z/Z')] > 0 1195 Emergency conditions: y*KEIme*Se - [ P*Dd/4ta,. + (i'i)(SEmg - P*DI4t,ý,)*(ZJZ')] 0 10291 Normal and Ther. Expansion conditions: 7'(Sh + SA) - P*Do/4tamin + (i'I)*(SNo, - P*DJ4trm + SThJ)(Z/Z')] a 0 25865
- c. Minimum Required Thickness Class 1: Gin = Max. [ trfin, tnnin, 0.3*tnor,, (in); Acceptable if tp " t',in 0.110 No Class 2 & 3: t'min = Max. [ tmin, tarnin, 0.2tnom], (in); Acceptable if tp . t'Gn 0.073 Yes
- 5. Remaining Service Life (RSL)
Class 1: RSL = [ t... - t nn ]/(SF*Wr), (yr) -0.1 Class 2 & 3: RSL = [ tm... - r*,], (SF*Wr), (yr) 4.6 Notes:
(1) The wear rate will be obtained from Responsible FAC Engineer or based on the Attachment 7.7.
(2) The acceptance standard (0,875tnom) can not be applied to:
- 1. Class 1 short radius elbows,
- 2. Reinforcement area of a tee or branch connection, and
- 3. For regions of piping designed to specific wall thickness requirements, such as counterbores or weld attachments.
(3) For the small end of reducers, the standard shall be based on the t,- of the pipe size at the small end. For the large end, the large end transition and the conical portion, it shall be based on the tnm of the pipe size at the larger end.
(4) The formula is applicable for straight pipes, bends, and elbows.
For reducers, tmi, at each end shall be equal to trni of straight pipe of the same nominal size as the reducer end.
For the conical portion and transition at larger end of reducers, tmin,shall be that of the large diameter pipe end.
For branch connections and tees, the reinforcement area of the opening shall be based on the B31.1 code.
(5) tarni can be obtained by the "Trial and Error" method until the "Allowable Stress - Axial Stress" due to Normal, Upset, Emergency, and combined Normal and Thermal Expansion conditions are all positive and one of them shall be close to zero.
(6) (i) can be calculated from Appendix D of ANSI 831.1. (i') needs to be adjusted for the pipe wall thinning.
It is suggested that the average thickness or 2 times of the original value be used for the i' ca(culation,
IP-CALC-13-00062 Rev. 1 Page 4 of d A. Pipe Parameters DO = Pipe OD (in) 10.75 tdj = Pipe wall thickness at flaw location (in) lowest of 4 readings is 0.378", used 0.875thorn = 0.319 taro average wall thickness of pipe circumference based on UT report (in) cons. use 0,8tnom 0.290 tm= nominal pipe wall thickness (in) 0.365 pd = Design Pressure (psi) 150 p0 = Operational Pressure (psi) (< 275 psig) 90 T Metal Temperature at evaluation(0 F) (< 2000 F) 70 E = elastic modulus at T (ksi) 27800 v = poison ratio 0.3 J1c = material toughness (lb/in) 7161.6 45 S = allowable stress for pipe (ksi) 1104 15 i = SIF = stress intensification factor used in the stress analysis 1.00 Service Level A B C D 1.10 E
1.10 1.10 p0 DoI( 4 tnom) or from stress summary: Axial stress due to design pressure (ksi)
S = P*Do/(4tnom) + (0.75i)(Y, : Piping Axial Stress (ksi, from stress output)
SFm: Level A = 2.7; Level B = 2.4; Level c = 1.8; Level D = 1.3 [C- 2621& 2622]
1.37 I1.58 2.7 2.4
] 1.10 1.69 1.8 1.69 1.3 SFb : Level A = 2.3; Level B = 2.0; Level c = 1.6; Level D = 1.4 [C- 2621] 2.3 2.0 1.6 1.4 Rm = pipe mean radius (in) = (DO - t)/2 5.216 E'= E/(1 _v2) 30549 Ktc = material critical stress intensity factor =J,*E/1000)0 5 (ksi(in)°-s) 37.08 B. Evaluate as a planar flaw in axial direction (Based on LEFM C-7400 & N513-2, 1-3.0)
Service Level A B C D c = e12 = Half axial flaw length (in) , try "c" to make Kc - K, >= 0.01 3.,21 I2.35 I 2.96 3.82 p = pressure for the service level condition 90 150 150 150 Oh = p"DJ(2t)/1000 (ksi) 1.52 2.53 2.53 2.53 Forthrough wall flaw, a = c:
05 X = c/(tRm) ° 2.49 1.82 2.29 2.96 5
+CX 3 +D 2 4 F= 1 +AX+B, +EX 2.85 2.25 2.67 3.26 Where A= 0.0724 B= 0.6486 C= -0.2327 D= 0.0382 E= -0.0023 Kic - K,= Kic" Ktm = (SFm)FO1, (xlc) 05' (ksi(in)°') 0.00 0.00 0.00 0.00 flaw length "2c" 6.42 4.70 5.91 7.64 Allowable Axial Flaw Length = Smaller "2c" of four service levels (in.) =
C. Evaluate as a planar flaw in circumferential direction Service Level A B C D (0.75i) >= 1.0 1.00 1.00 1.00 1.00
='b(s- Pd4 o/(4tno.)/(0.75i) (ksi) 0.27 0.48 0.58 0.58 4 4 4 0b =Ob[Do 4- (D." 2tom) 11[0o " (D. - 2tare) ] (ksi) 0.334 0.590 0.718 0.718 p = pressure at the service level 90 150 150 150 O3m = pDo(4tave): Axial stress due to service pressure (ksi) 0.83 1.39 1.39 1.39 37.1 37.1 37.1 37.1 For through wall flaw, based on a = c I I I I [ i I I c: Half circumferential flaw length try Vc"to make KI, - K, > 0.0 L 6.32 1 4.81 ] 5.65 I 6.68 I
a = c/(Rt,,) 0.386 0.293 0.345 0.407 16.3 16.3 16.3 16.3 i= 0 1 2 3 Am= Ar,) + Amj*r + A, 2"r2 + Am.3r 3
Aml -2.0292 1.6776 -0.0799 0.0018 11.7 11.7 11.7 11.7 2 3 Bm= Brn0 + Bm,"r + Bm2.r + Bm,3r Bin 7.0999 -4.4239 0.2104 -0.0046 -29 -29 -29 -29 2 3 Cm= Cm, + Cmlr + C,,-r + C, 3 "r CmI 7.7966 5.1668 -0.2458 0.0054 50.2 50.2 50.2 50.2 2 3 Ab= Abo + Ab1lr + Ab2*r + Ab 3'r Ab. -3.2654 1.5278 -0.0727 0.0016 9.3 9.3 9.3 9.3 2 3 Bb= Bbo + B1bt*r + B2* 1 r + Bb ,3"r BbI 11.363 -3.9141 0.1862 -0.0041 -21 -21 -21 -21 2 3 Ct,= Cbo + C,, ,*r + C) 2*r + Cb 1, *r CW, -3.1861 3.8476 -0.1830 0.0040 28.4 28.4 28.4 28.4 2 5 35 Fmo= 1+ A rnal 5+Bm* , . +Cm* Ca 2.90 2.19 2.55 3.12 F,= 1 Ab-Oi "5+-ba25,*'(Z3.5 2.32 1.89 2.11 2.44 0
Kl, - K, K=c" [(SFj)(rrc)°'5(0mF,) + SF ,(itC) 5(qb'Fb 1,)] > 0.0 0.0 0.0 0.0 0.0 Flaw length (2r) = 12.65 9.61 11.30 13.35 Allowable Circumferential Crack Length = Smaller "2c" of 4 service levels (in.) =
IP-CALC-13-00062 Rev. 1 Page S Of .
D. Determine the flaw length from the UT report using the adjusted wall thickness, tadf Laxiai length of through wall flaw in the axial direction of the pipe (inch) 2.5"+1,5(2)(.012) =2 . < allow flaw, O.K Lrc = length of through wall flaw in the circumferential direction of the pipe (inch) 8.25" + 1.5(2)(.012)=F .29I < allow flaw, O.K E. Minimum remaining ligament thickness requirement [N-513-3, 3.2(d)]
tm.n = Pd*Dd[2(S+.4*Pd)] + A, (in), A= 0 0.054 dd, = 1.5[Rmta~i]Ntad,- /tmt, (in) r use .0 Mininum remaining ligament thickness requirement = 0.353dadi(P/S)0 5 (in) 0.318 Minimum remaining ligament thickness Is less than adjusted thickness used in Section A, O.K.
ErT ter y CONDITION REPORT ICR-IP3-2013-04416 Originator: Alien 11,Robert E Originator Phone: 6774 Originator Site Group: IP3 P&C Eng Codes Staff [P3 Operability Required: Y Super,.isor Name: Azevedo,Nclson F Reportability Required: Y Discovered Date: 10/30/2013 09:39 Initiated Date: 10/30/2013 09:48 Condition
Description:
Further visual examination of Line No. 1093 in the 32 MI" moat excavation revealed that the corroded area originally found (ref. CR-1P3-2013-04174) extended underneath the pipe to the area that was resting on the wood support. The area now measures 8-I/4" circumferentially and 2" wide in the axial direction. The remainder of the exposed pipe in that area was in good condition with no corrosion.
Immediate Action
Description:
The pipe surface was cleaned up and pipe clamp installed over the corroded area.
Suggested Action
Description:
Engineering to evaluate this information.
EQUIPMENT:
Tag Name Tag Suffix Name Component Code Process System Code 10 LINE 1093 PIPE SW REFERENCE ITEMS:
Type Code Itemn Desc DOC VT report IP3-VT-13-021-DWG 932 1-F-22363 WON 00350692-31
Attachment B EN-DC-126 REV 4.
aJEntergy UT Erosion/Corrosion Examination Site/Unit: IP3 / 3 Procedure: CEP-NDE-0505 Outage No.: N/A Summary No.: 10" Line # 1093 Procedure Rev.: 4 Report No.: IP3-UT-13-058 Workscope: BOP Work Order No.: 00350692-17 Page: 1 of 7 Code: ANSI B31.1, '67 Ed. - '69 Ad. Cal./Item: Location: YD - 5' Drawing No.: 9321 -F-22363
Description:
Characterize (3) areas of corrosion found in the MT Moat excavation System ID: Service Water Component ID: 10" Line # 1093 Size/Length: 10" Sch 40 Thickness/Diameter: 0.365" Limitations: None Component File No.: N/A Start Time: 1418 Finish Time: 1455 Calibration Information Partitioning Information Component Information Calibration Thickness (In) Calibration Times Initials Component Begin/Col/Row Ending/Col/Row Component Geometry: Pipe Actual Measured M. UPST Ext. N/A Outside Diameter: 10" Grid Size: N/A 0.040" 0.500" Start: 1418 REA Main UPST. N/A Max. Thickness: 0.394" Min. Thickness: 0.109" 0.100" N/A Verify: 1425 REA Main N/A Nominal Thickness: 0.365" Tmin.: 0.319" 0.200" NIA Verify: N/A Main DNST. N/A N nT es .r.: 3 REA M.Min. Thickness Location: Area 1 0.300" N/A Verify: 1440 0.400" N/A Final: 1455 REA Branch N/A Max. Thickness Location: Area 1 & 2 Branch Ext. NIA Surface Condition: As preped Instrument: Transducer: Reference/Simulator Block: Temp. Tool:
Manufacturer: Panametrics Manufacturer: Panametrics Serial No.: 99-7437 Manufacturer: Control Co., Inc Model: 37-DL Plus Serial No.: 536066 Type: C/S 0.04"-0.5" Serial No.: QS-97 Serial No.: 031110106 Size. 0.283" Freq.: 7.5 MHz Couplant:
Gain:50 dBRef.ISimulator Block Temp.: 76.1 °FCupat Gain: 50 dB Model: D798 Type: Ultragel II Range: 1.00"' # of Elements: Dual Material/Component Temp.: 74.2 *F Batch No.: 12125 Comments/Obstructions: The coating was removed and the pipe prepped prior to this exam.
Results: Accept E Reject Ei Info D Tmin = 87.5% Nominal Thickness. Reference CR-IP3-2013-04174 Examiner Level III EOI 7 .ig~ture Date Revie er Signature Date Allen, Robert E.
Examiner Level N/A Signature 4,-,.*'.;*'
_ 10/3/2013,----,
Date Site lReview a.Sinature Date Other Level N/A Signature Date ANII lRview . Signature Date N/A
Supplemental Report Enitergy Report No.: IP3-UT-13-058 Page: 2 of 7 Summary No.- 10" Line # 1093
,. Date:
Level: IIl EOI Reviewer: ?./,*
Examiner: Allen, Robert E.
Level: NIA Site Review: Date:
Examiner: N/A Level: NIA ANII Review-- WIAL Other N/A in the moat. Photo right below showing the UTT locations.
Comments: Photo left below of Area 1, North end of the pipe
\\Client\Y$\Iddeal Ver 8\IddealServer\IDDEAL-IP3\Graphics-Pictures\Service Sketch or Photo: \\Client\Y$\Iddea1 Ver 8\ ddeaiServer\IDDEAL-lP3\Graphics-Pictures\Service Water\10 Line 1093 area lb.jpg Water\10 Line 1093 area la.jpg
Supplemental Report Report No.: IP3-UT-13-058 Entergy Page: 3 of 7 Summary No.: 10" Line # 1093 Examiner: Allen, Robert E. LA tý. Level: III EOI Reviewer: Date:
Examiner: N/A Level: N/A Site Review Date:,,_______ ,
Date:
Other: N/A Level: N/A ANII Re¶vieW:'~A Comments: Area 1 UTT readings.
Sketch or Photo: \\Client\YSlddeal Ver 8\lddealServer\IDDEAL IP3\Graphics-Pictures\Service Water\10 in Line 1093 Area 1.TIF A 0ci-rti A f'kI
\
50 V -r
'1 ti. - .V I Z-
-75 5!5 - - jq
Supplemental Report Eutegy IP3-UT-13-058 Report No-.
Page: 4 of 7 Summaiy No. 10" Line# 1093 Level: III E0I Reviewer: NI _ Date:
Examiner: Allen, Robert E.
Level: N/A Site Review', Date:
Examiner: NIA Level: NIA Date:
Other. N/A i -
below showing the UTT locations.
Comments: Photo left below of Area 2, North end of the pipe in the moat just South of Area 1. Photo right
\\Client\Y$\lddeal Ver 8\lddealServer\IDDEAL_ P3\Graphics-Pictures\Service Sketch or Photo. \\Chent\Y$\lddeal Ver 8\lddeal_Server\IDDEAL-IP3\Graphics-Pictures\Service Water\10 Line 1093 area 2b.jpg Water\10 Line 1093 area 2alpg
b -Entergy Supplemental Report Report No.: IP3-UT-13-058 Page: 5 of 7 Summary No.: 10" Line # 1093 Examiner: Allen, Robert E. Level: III E0I Date:
-'.9 Examiner: NIA Level: NIA Other: N/A Level: N/A Date:
Comments: Area 2 UTT readings.
Sketch or Photo: \\Client\Y$\lddeal Ver 8\lddealServer\IDDEAL IP3\Graphics-Pictures\Service Water\10 in Line 1093 Area 2.TIF 4,2 AZ-Q,0 r,,.T.-&4 IS'& j - H Fý Le (-QJ L
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a -Entergy Supplemental Report Report No.: IP3-UT-13-058 Page: 6 of 7 Summary No.. 10" Line # 1093 .. ,
III EOI Reviewer: Date:
, Level:
Examiner: Allen, Robert E.
Level: NIA Site Review:
Examiner N/A Other NIA Level: NIA ANII Rev . /~ : Date:
where pit gage readings in the moat South of areas I & 2. Line I and line 2 are the locations Comments: Photo left below of area 3, mid span of the pipe of 3/8".
below showing the pit gage at maximum depth were taken 1W4" apart across the area of thinning. Photo right
\\Client\Y$\lddeal Ver 8\lddealServer\IDDEAL_lP3\Graphics-Pictures\Service Sketch or Photoi \\Ctient\Y$\Iddeal Ver 8\IddealServer\IDDEALJlP3\Graphics-Pictures\Service Water\1 0 Line 1093 area 3b.jpg Water\10 Line 1093 area 3a.jpg
Supplemental Report Report No.: IP3-UT-13-058 Entergy Page: 7 of 7 Summary No.: 10" Line # 1093 _
Examiner: Allen, Robert E. - Level: III EOI Reviewer: ,. Date:
Examiner: NIA Level: NIA Site Review: Date: -ý7',-
Other: N/A Level: NIA ANII Reviaýý 'i/, - Date: _____
Comments: Area 3 UTT and pit gage readings.
Sketch or Photo: k\Clien\Y$\fddeal Vet 81lddealServer\iDDEAL1 P3\Graphics-Pictures\Service Water\10 in Line 1093 Area 3.TIF
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