ML20234F590

From kanterella
Jump to navigation Jump to search
Rev 6 to NDE Procedure N-UT-26, Ultrasonic Exam for Detection of I.D. Pitting,Erosion & Corrosion. Related Info Encl
ML20234F590
Person / Time
Site: 05000000, Browns Ferry
Issue date: 07/22/1987
From: Hemby W
TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML082420107 List:
References
N-UT-26, NUDOCS 8709230178
Download: ML20234F590 (32)
v • d • e


Text

{{#Wiki_filter:_ _ _ _ -._- l _( c SQN l Procedure No. l- 'll ~ NONDESTRUCTIVE EXAMINATION PRO ( TI-51 7 N-UT-26 Rev'sion - TVA. OFFICE OF NUCLEAR POWE Page 48O i ' Revision 37 .6..., C. ~. '.s.<+.u I w.. T.... ~ -...... 3,, l- -- - c. ::. 1 \\ ..-9. .,.y :* f-., .-.G i.<.. ...g j,,,. - . ? . v... , y.,e,

a. 4. :, :

,..o;3 !'.;;. 9.. I.

itgys
?:..n -

L 4 e ig. A.n,.?;".. ' . ?;.n.n.,...... 7. l ~ s. ULTRASONIC EXAMINATION c ,...s FOR THE DETECTION OF I.D.. I' PITTING, EROSION, AND CORROSION ( f -u... .p %- . ;ro,.v,5 ' qpgE.':. - '.7..a.,:.., ....r a.

  • a im

. z.:7.;.4.* 9' Pr: pared by AkIM6db ~ Date 8 ~/ Approval

  1. 8 TVA Level lit, Date f-*N-F')

A/ M anils, Date A L Acceptance / 4

  • 6.:

~ w e e e ~ M ..,. ~..... 8709230178 870910

,,;,,,-s,...p.j,,,j, x gyg..

PDR ADOCK 0500 9 .=.. mva. ' N.?kW.s($:$5.u.~.r. H $*.,'?.'-lj &.9 a > ~ ' - k d~ i%-

NONDESTRUCTIVE EXAMINATION PRCCID ~ -51 TVA. OlVISION OF NUCLEAR POWER Page 480a l Revision 37 WA 7/22/37 Ps9e i o r, 5 REVISION HISTORY L , gg 7g7 j s-h I ev. j Date Paoe Description { i 01/03/83 All' Initial Issue 02/28/83 1 Changed paragraph 3.1 to incorporate ~ PCR #10, which permits the use of different size transducers. 03/11/85. 1&2 Change paragraphs 1.0, 4.1, 4.2, and 6.1 to incorporate PCR #24. PCR 24 removed the 1/2 inch maximum wall thickness. 12/03/85 All (1-3) Change paragraph 3.1 to allow the use of single element transducer. - Add paragraph 4.3 to allow j calibration for materials up to-2 inches in thickness. This revision incorporates PCR numbers 85-10 and 85-15. 06/10/86 All (1-4 Issued)- Pages 2-4 revised. Add Cali-Pages 2-4 bration Data Sheet. Add Revised paragraph 6.3. (re: SQ-DR-86-04-086R) (165 860523 668) 07/21/86-General Revision Added paragraphs 3. 4, 5.4, 5.5, (1-5 issued) and 6.1 to incorporate PCR No. 85-20 Pages 1-3 re-(L65 860715 530). yised, page integrity necessary. rj($30 /~7 S N-UT-26 '9 A 6*,78E (ONP.841). NCE Revision Historv t.oo

Procedura No-N-UT-26 NONDESTRUCTIVE EXAMINATION PRO SQN TI~*El - '~ TVA - DIVISION OF NUCLEAR POW Page:481 ... ~.. Revision 37 Page REVISION HISTORY LOG 11 of 5. ~.-i +.;4 i- --. - ..t- - m.m.;; W u.. _.. :- ...,m

y. p g

,w I . Det 7 'Page Description '~.{j j< 5/27/86 1 and,3 (All, 1-5) issued Revised paragraph 3.1. Revised. V list-of data in paragraph 6, referenced Figure-1, and added. Paragraph 6.3. (Reference L65 870324 261) 2 e d aat ach ~. j l L 1 iT t L1 3. 1 ls en is i .y.-. ..u',.: n.;..a,. A :.iR "2 a

a., -

... -? ..,.f.,. .:,.:. > 3,LI.dr. '.*.1l' $l'4.(.h h,;....w,..f.#.fj. .m !N*-.8 }).NDEgevision History Lo@ MM' MLashfL I ~

SQN 7 Procecure No. 3 ,, g (, TI-51 NONDESTRUCTIVE EXAMINATION PROCED Page 482a Revision 6 TVA-OlVISION OF NUCLEAR POWER Revision 37 d, 2 of 5 a o 4.2 For thicknesses up - to 1 inch, repeat 4.1 above except adjust the sweep.ind delay controla so that the first back reflection from the 0.1-and 0.5-inch graduations appear at 1 and 5 major screen divisions, respectively. ~ 4.3 For thicknesses.up-to 2 inches, ' adjust the sweep and delay. controls so that each division represents 0.2-inch per major screen division. From a l-inch th'.ek rompus or!IIW block,. position the first back reflection on the 5th screen division and the first multiple at 10 screen divisions. Using a step. wedge, position the transducer on-the 0.5-inch step and adju:t the first reflection at - C;.' ~ 2.5 divisions and the third multiple a.10 divisions, respectively., When calibrating using dual-element transd'ucer, multiple back NOTE: reflections cannot be used. 5.0 EIAMDTATION PROCEDURE 5.1 The er==*nsf. ion surface shall be free of any roughness that interferes with. sound transmission or transducer movement. Conduct the general scanning with the instrument adjustment that will-produce a first reflection from the I.D. surface of a defect-free area of the component to one hundred percent full screen height. Several areas of the component should be checked to ensure a defect-free area is located. Y. ~ 5.2 When scanning curved surfaces,. the acoustic barrier between the - r transducers shall be orienced parallel to the longitudinal axis of the component and scanning shall' be,in the circumferential direction. g \\ ,5.3, Areas of suspected pitting, erosion, and corrosion shall be examined over the entire area. Each pass of the search unit shall overlap a J minimum of ten percent of the transducer dimension. The rate of the transducer movement shall not exceed six inches per second. "5.4 System calibration checks shall be performed when any of the u. .following occurs: (a) At the start of a grid examination (b) With the substitution of any examination parameters, i.e.', transducers, cables, power supply, couplant (c) At'least every two hours during the examination ~ (d) At the finish of the grid examination * (e) Whenever the validity of the calibration is in doubt ~ If a system calibration check reveals any deviations from the original calibration, a new calibration shall be performed and the preceding examination area shall be reexamined. ~ ~ ~ ~ g.UT-26 3 \\ 9"A ssuo ton 9 ~ .p. NO F p e .c. O

  • Precedura No.

N-UT-26 I 1 SQN NONDESTRUCTIVE EXAMINATION PROCE. TI-51 .'6...'.'- ? TVA - DIVISION OF NUCLEAR POWEF ' ~ ~' Page 483 j l Revision 37 Page C-of,,ee..y g m i 3,- 5-=.=e j ? 5.5 The location of the areas to be examined shall be designated by the . _ w. I applicable work instruction. ,. _,,,f

6. 0, RECORDS

'*6.1 Theminform,at'on. recorded on the data sheet (Figure 1) shall include. i as a minimum:- (a) USL-38 serial' number ,,7 (b). Transducer frequency, size, and serial number I .A (c) Calibration time, including time calibration checks were made (d) Surface temperature ~ --' (e) Type couplant (f) Personnel performing examination and level (g) Reference standard (s) serial number 6.2 Areas that produce a shift,in 'back reflection on the CRT horizontal sweep scale shall be recorded to the nearest one-hundredth of screen ( division 'on a grid form depicting the area examined (see attached form). 6.3 Records produced as a result of examinations performed in accordance with this procedure shall be forwarded to the cognizant engineer for disposition. 'Y. m J.-x,, c. .N;.." l-I b i i ? l ~* Revision ~ ~ ~~' ~~ i a , _ }';- . - %i ..:( N-UT-26 . ;'.s ; ...'-.i- +L. 4,9 -Tseg;y $..,gt r..',,.$r8.:.- ~' .s . R .^

a
w
s a 2 - a R________

^ 7-.Proceuure No. y TI-51 Rem on . NONDESTRUCTIVE EXAMINATION PROCED Page.483a" TVA. OlVISION OF NUCLEAR POWER Reviston-37 6 2 Q 37, 7 4 of 5 ~ vv Attachment . Examination Procedura # Rev. Date MR # SI #- Plant /Unic Grid Locacion-System Examiner Level Transoucer Size-and Frequency. - n x t

h. -

N N N L \\ l--. \\ L. N l e. 1 (- F, ~ N-UT-26 i 4 ~ ~ pn e or:vwan c>c n ero m__ _ _ _.. _ _ om - -

-{ Procedure No. N-UT-26 * ) ) " ~ i,. SQN ~ NONDESTRUCTIVE EXAMINATION PRC' - TI-51 Revision n g~ # ~~ ~ ~. TVA. DIVISION OF NUCLEAG POV Page-484 I, ~ C. Revision 37 Page ~ .c: ;;,.. - 5 or. 5_, %,m n

  • ** 7 ""

,3;.' ~ ~. n .-.. -s b .o feONOESTRUCTIVE EXAMINATION = PROCEDURE : cAuenario= =o TVA.OlvstlON Ol' >80Ct. EAR POWER FHeAL E AL. TIWW Auftecostre esegeec?o. OATC l l ULTRA 5oNIC CAL 18MATION CATA SHEET l twAnesesteArvel CNAueNtartVfL ~t peecteunt eso. stv. agy,tw&tvtL. E INSTRUMENT SM O CA8LE ~~ u RECOROEA 5.W 1 f TRANSOUCEA '5m SIZE ,mtO. AssoLg j cAi_.wex - 5.= .u..En no,. n n u.ea.OCn s.u - sv.nuu-nu r T CourLAseT SATCM *se. SunFACE THEuoutTem $m Tvet EXAuteeATsoes. AescLestAu C LONCITUDIN A(. SASEMETAL wtLOutyAg,h .L wantieas 8- - ( se s.. mas a 100 90 l 40 l20 l GO 50 0 1 30 20 l10 l a $0 t 1 i 1 'l R- . ~ > ~. y Artassume.. ) enne.ase. SET l 4 att $CT +82 lStf +4 7. =- ... n... i..... ,2. i.. o e. E C= ea.a., une a e.e. c eem s sa e.e e e c'e* * * * * ' * 'e e n t =e OtSTANCE Ate 8L87 DOE CU Avt toestauurwv tr? up e OAC rACQUENCY 2' O 5 a O== 0 aT Ea-90' l SENSITIVff'Y/ GAIN F1NC/gt i 40 = => I COARSCMe to i l 80, l SWEEP <.O A A SE - 50 l SwtEPFfNC e l SWttP.OCLAY as ,30 OAnapteeg gg, OUAL/f tenu O s,~ci.c rei O $'actr. O - 1 le mLJECT ' ' ~ ' I e 0 4 2 3 4 S 6 7 8 9 10 JACM CR QT OUAL 0 PACC Or,, TV A 647s A (Oma.54n i a 1 Figure 1 s o e - u h'o ' - ~. > - N-UT-26. r . ;. r:@.. %nm ~ z. -.6' in Mrated..I se.< ;,p. ;..,U. M. 4* 7: TS* T" it'-*, t."* '< ?;a-ca

  • r.e DAh{

__ _ AM.

  • =-

n cvy s mm n _ srega_

I i l I i ATTACHMENT 3 Design Study Report i Results and Recommendations 1 l l k \\ i

vvp u i:s. es UMTED STATES COVERNMLNT l Memorandum TENNESSEE VALLEY AUTHORITY MEB '84 M O S 011 ) '70 J. P. Darling, Manager of Nuclear Power,1750 CST 2-C { l THOM R. W. Cantrell, Manager of Engineering, W11A9 C-K ] DATE

ho b1984

SUBJECT:

SEQUOYAH, WATTS BAR, AND BROWNS FERRY NUCLEAR PLANTS - MOISTURE SEPARATOR REHEATER (MSR) LOW PRESSURE DRAIN PIPE FAILURE DESIGN STUDY REQUEST (DSR) NO. S-028 - RESULTS AND RECOMMENDATIONS Please refer to H. J. Green's memorandum to M. N. Sprouse dated May 4, 1983 (DES 830505 010). Attached per your request in reference 1 are our recommendations concerning erosion-corrosion problems for BFN, SQN, and WBN. We understand that you are currently developing an erosion-corrosion inspection program for TVA's. nuclear plants and, accordingly, we have included inspection, inspection frequency, and material replacement recommendations for input into your program as part of the abo've attachment. As noted in the attachment under Reconsnendations, calculated minimum allowable wall thickness for specific pipes are considered critical input data which, upon your request, may be evaluated by OE and provided for your.use. l On BLN, we have only reviewed a few cases as part of our routine design review of new additions or modifications and have verified or ensured proper design for those cases. However, if you desire a list for BLN similar to those attached, we need your concurrence to proceed. Please advise. Od;in:1 Signed Bf

11. W. Contrell l

R. W. Cantrell l l CAC:TBG:SDW l Attachments "cc ( Attachments): N. R. Beasley, 6204 MIB-K C. Bonine, Jr., 12-108 SB-K D. B. Bowen, W11A8 C-K W. R. Brown, 102 ESTA-K ( C. A. Chandley, W7C126 C-K G. F. Dilworth, W11 A12 C-K R. M. Hodges,1117 IBM-K MEDS, WSB63 C-K J. A. Nicholls, Sequoyah OC (3) R. M. Pierce, 104 ESTA-K i s J. C. Standifer, P-104 SB-K J. P. Vineyard, AB Sequoyah ENG G. Wadewitz, Watts Bar Nuclear OC (3) b Principally Prepared By: T. B. Gideon. Extension 4581 j W t om-m - / I

ATTACHMENT i DESIGN STUDY REQUEST (DSR) NO. S-028 - EVALUATION I Prepared By T. B. Gideon, OE/MEB, Extension 4581 i

References:

1. H. J. Green's memorandum te M. N. Sprouse dated ] May 4, 1983 (DES 830505 01J) 1 2. M. N. Sprouse's memoranduu to H. J. Green dated i August 8,1983 (MEB 830809 005) ) l 3 Allis-Chalmers Power Systems, Incorporated, 4 Engineering Report No. ER-604, " Erosion-Corrosion Caused by Saturated Steam" 5 4 SQN ECNs L-5988 and -5581 ) a 5. BFN ECN P0648 l 6. INPO Report No. 82-11 7. Letter to Alabama Power Company from Southern Company-Services dated December 22, 1982 (attached) We were requested by.the reference 1 memorandum to evaluate the implications of the throughwall pipe failure in-the MSR low ~ pressure reheater drain pipe caused by erosion-corrosion (EC), and also to evaluate other related pipe failures and the corrective actions to be implemented. Our study included the valves and piping listed in attachment D of reference 1, as well as other areas which we determined have conditions which could cause various degrees of erosion or oavitation (see attachments 3 and 4). According to reference 3, EC can occur in carbon-steel in the temperature range of 100-5000F (severest effect at 3500F) with saturated steam in turbines, valves, moisture separator-reheaters and piping systems. Factors that influence the rate of EC, in addition to material, are temperature, steam velocity, moisture content, and flow path configuration. To determine whether the above piping arrangements were susceptible to erosion-oorrosior., we employed the method outlined in reference 3, witn minor modifications. We contacted the author of the paper, Heinz Turnuehlen, regarding the use of the flow configuration factor. He advised i l

l . that the maximum configuration factor be used downstream of. valves since ) the flowpath configuration cannot be asoortained. Also, the temperature 1 factor for the range of 4000-4500F was assumed constant since the slope is j very steep for this relatively small temperature range (reference 3, figure 2). Although only the effect of EC was requested to be examined, the potential for oavitation erosion was also investigated. There have been many oavitation erosion problems. For instance, a 12-inch condensate short cycle recirculation line recently failed at WBN after relatively few hours of preop operation and.the damage mechanism was identified as cavitation erosion. Although we have -been unable to obtain= a standard method for predicting the rate of cavitation erosion on affected piping, and the above EC method is not applicable, we were able to' predict areas where cavitation is expected to occur based upon previous experience. Generally, our study involved reviewing areas where steam or water flow went from high-pressure regions to low-pressure regions (e.g., downstream of high pressure drop control valves and bypass lines to the condenser), reviewing piping systems with 2-phase flow at high velocities, and reviewing low-point piping for adequate drains to minimize entrainment of. the moisture in the steam. Based upon discussions between our Terry Gideon and your Terry Woods, we understand that you are in the process of preparing an inspection program to determine the rate of erosion-corrosion ocourring at the subject plants. We agree with developing such a program. Also, we have attached a copy of an inspection plan prepared by Southern Company Services (reference 7) for your use (attachment 1). ~ We have included pertinent excerpts from the reference 6 INPO report for your use (attachment 2). Based on the above, and 'in conclusion, we ' recommend the following action plan. Recommendations: 1. Develop reliable ultrasonic testing inspection methods using the guidelines presented in attachments 1 and 2. 2. Develop a specific listing of piping, by plant, to be included in the program, consisting of those items identified in attachments 3 (SQN/WBN) and 4 (BFN) as a minimum. 3 Establish frequency of inspection guidelines for various categories of piping using attachment 3 and 4 guidelines. 4. Determine the minimum allowable (calculated) wall thickness for specific piping to be included in the program. OE/ NEB will evaluate and provide this data if requested. i 5. Develop stringent guidelines to be used in determining when to i replace eroded piping. These guidelines saould include the following factors: I a. The measured wall thickness at time of inspection and the minimum allowable thickness G84296.01 J

Attachment. Continued 'b. Predicted / calculated erosion rates c. Time intervals between inspections, and d. Leadtime for material procurement 'A sufficient number of inspection points should be established for a given run of. piping and these locations match marked for future inspections such that realistic calculated erosion rates can be determined. I In general, replacement piping should be fabricated from type 304L ss. However, as noted in attachments 3 and 4, carbon steel may suffice based on the accumulated hours of service at time of failure and the remaining plant life. Type 304L ssT is highly resistant to erosion-corrosion and has good welding properties. Type 304L is also readily available and relatively inexpensive when compared to more exotic materials. We also note that the reference 4 and 5 ECNs have authorized use of SST piping for eroded carbon i steel piping. However, even 304L ssT will arode under very severe conditions. Consequently, 304L SST replacement piping which was previously_, listed in attachments 3 or 4 as requiring immediate inspections and possible replacements or inspections every refueling outage should be periodically inspected and monitored to verify 304L SST material has adequately corrected the problem. I G84296.01 1

,e A%uk L PRODECURE FOR DETE MINING PIPE WALL THINNING PURPOSE The purpose of this inspection program is to detect severe erosion in high and low pressure turbine extraction lines, moisture separator reheater drain lines, and main steam drain lines thereby reducing the probability of a rupture in these lines. This goal will be accomplished by taking ultrasonic thickness measurements of a representative sample of elbows, tees and other fittings in each system. This inspection will indicate generic pipe thinning problems in these lines; however, it is not intended to be a comprehensive test of all possible erosion

sites, i

M PREPARATION Preparation to take the ultrasonic test data will require that insulation be G removed at least one foot either side of where the data will be taken. ) Scaffolding will also be required to allow access for the test team and ultrasonic testing equipment. DATA ACQUISITION The ul'trasonic thickness measurements will be taken frcr,m one fcot upstream of the fitting to one foot downstream of the fitting, i:n approximately four inch increments. Reac;ings will also be taken in 90 degree sectors clockwise (when looking downstream) around the pipe or fitting at. each four inch incre-ment. If there are significant differences in the four readings; measurements should also be take at 30', 60',120',150*, 210*, 240',, 300* and 330'. The first reading, Number 1/0*, will be one foot upstream of the fitting and on the top side of the pipe if horizontal, north side of the pipe if vertical. The second reading will be Number 1/90', 90' clockwise around the pipe from l reading Number 1/0', and so forth until readings have been taken all the way l around the pipe. The second set of readings will start with Number 2/0*, four inches downstream of the first set. This pattern should continue until readings have been taken one foot downstream of the fitting. Data will be entered on data sheets, such as the one attached. l l

I l Page 2 's PROCEDURE FOR DETERMINING PIPE WACL THINNING ) \\ (continued) I ANALYSIS OF DATA-Af ter the actual' thickness of the pipe wall' has been determir.ed, a comparison j will be made to the nominal wall and minimum wall thickness.. Based on this comparison, a determination can be made that either: (1) The system in que'stion shows no severe erosion damage and should. be re-tested only routinely. (2) The system shows some signs of severe erosion damage and further 1 action must be taken to insure the integrity of the system and similar systems. x P APPENDICES ?. ( Sample Data Sheet. 5 ' Marked up drawings showing location of data points to be tested as a i minimu'm. 3 h - e. ... i e i

\\i'3jll1I a,. I ? I W~ n, r M [ 1 .":=.". 1 - /. e F C 6 r O /

  • 4 ;, e,

. W o *s 0 O r I. A E i &r ( A C O wL f 1) j s ~ t / e r. E 9 -c. X* a ** V *% f-4 T D t / y 'f R a ~ h. t A 1

  • s E

o w'M s i Ta N*. t r t

  • f b e s

5-

  • i S

l . W. s. i B '/

m. N ^ :u f' s^4 1

s t C s r X u. rC" O ~- CmO d r C E t tr L l.

  • 7 s

6 CrX O e C. 0 I 3 l 1; fJ O L s U "S ( 3 D r. 's 0 t E O L 1 f

u. l s

t T O 9 7.ql A m / 'n J f / L n A f L f ~- l V C O. T:k o o

  • a.

S N ^c l E W 'U. u A r k C l t l / (" l k . AI 5 d f e:. O t. df 1 i

  • r t!

o N! faA A F A c 7 f f E A t /- sf \\ 1 v/A Mf 4 e" r. ( I 3 C f \\ s t ? ( C ci t ( C W R

  • r 1

o t L Rr Gr f t. t> O % A n r (N ' s-m

  • 1

/p/ a e U A 1 L o/k e 5 s L > L5 M t/ f r I A "f N 'o 7 [ / v E f ( a ] L. l L ' T T lA t t f 1 sI R[ N . U . 1 f I A 'an T rMU tv O T 3 (0 2 J I l r Y o 8 o o ut w r^ t r n '0 t v 3 n C ~ r n 3 ~ 'D( T 3 I E W 2 A Y i d A O E .I^ n M d i A l N l 4' A'

  • o f

X B E I f 6 T 5 C 1 E J BU S o z i c = n $n I S 6 [M N L ,s '] e

e, c ic c c i

i v l t 'o i i r f r e c Sl Tf ~ y# t f t 'I n P aT 0 l p!* 3 l % w-l mU ^ ) C- 'o 1 M o 1 t 'r t/ 1 'r ~f V. mP 11 s._ *v J 1 t-ss e *- 9 L ,* f 9 0i 21 n 9 7 u f-on

  • i&

I ywi

1) ' _ [r n1 U'.

3 hA a l Y 5 c _8 Z __ 3 2 )* 2* 2 2 t

  • I I

t ~.. u* 1 L +Yf3'.).\\ a }.4% So 's r. J ~ D.. 1' i. e

l A_ttachment 2-l l l EXCERPTS FROM INPO REPORT NO. 82 ULTRASONIC TESTING INSPECTION RECO M NDATIONS For those pipe sections identified as susceptible to significant erosion, a planned inspection program should be implemented to verify adequate wall thickness. Smaller diameter piping--(where erosion due to flashing may' be-probable) should be-inspected to a minimum, distance of SD '(D Pipe Diameter) downstream of valves, reducers, etc. These periodic inspections should be established to detect the onset of piping. erosion as well as the rate of pipe wall degradation. Thinning of piping walls can be detected and measured using ultrasonic measurement techniques. The most likely location for erosion is on the downstream side of an elbow on the long radius surface. It should be noted that accelerated general corrosion of the downstream section of the short radius surface on elbows can be expected, particularly in pipe fittings where erosion is taking place. The geometry of the erosion will probably be of a nonlinear continuous shape although there have been reports of localized eroded areas. In either case detection of the eroded' piping will require detailed ultrasonic test mapping of the suspect area. Limitations of the ultrasonic test instrument saast be known. Well trained technicians'are essential for a valid and thorough test program. One utility found instances where erroneous readings were given at thicknesses below 100 mils on some of the instrument types used. This was due to the signal rebounding several times creating a longer time delay. Thus, the instrument reading could be interpreted to give incorrect readings showing the pipe to have sufficient thickness. ~? The grid spacing for locations selected for wall thickness in scans should be smaller in regions of changing direction or steam velocity than in staight runs of piping. At one plant, an elbow failed that was in the scope of an ongoing inspection program. It was later determined that the grid spacing used to cover the inspection area wa's too large to find the actual thinning of the piping that ruptured in the wastage area. G84296.01 u f.-

RECOMMENDATIONS - SEQUOYAH AND WATTS BAR NUCLEAR PLANTS EC Study I. Inspect isusediately (at earliest opportunity - decision on when to replace to be based on criteria identified above). 1. LCV-6-4A, 28A, 50A,. Low pressure-reheater drain tank drain to 72A, 81A, 90A No. 2 heaters valves, 1-1/2" piping and fittings and 1-1/2" x 4" reducer downstream of valves 2. LCV 6-15A, 35A, 58A Hester 1 drain to heater 2 drain cooler: 4" piping and fittings and 4" x 8" reducer ) downstream of the valves 1 3. LCV 6-21, 43, 66 Bester 2 drain to No. 3 heater drain tank: 6" pipings and fittings and 6" x 10" reducer i downstream of valves 4 4. FCV 3-70, 84 Feedwater recirculation: valves and downstream piping and fittings for at least 5 Diameters length 5. FCV 3-544, 545, 546, Bypass valves. for the manual feedwater and 547 isolation valves: valves and 1" piping and fittings II. Inspect every refueling outage (replace with SS components as required based on criteria defined above). 1. LCV 6-13A, 33A, 56A, Hp reheater drain tank drain to No. I heater: 76A, 85A, 94A valves, 1-1/2" piping and fittings and 1-1/2" x 4" reducer downstream of valves. 2. LCV 6-105A, 105B No. 3 heater drain tank bypass to condenser: For SQN, the 8", 12", and 16" piping and l fittings downstream of the valves to the condenser. For WBN, the 8", 10", 12", and 16" piping and fittings downstream of the valves to the condenser G84296.01

4 l I i, Continued i 3. FCV 1-212 SGBD regulating valve: valve and 2" piping and fittings for at least SD downstream of the valve j i 4. LCV 6-4B, 28B, 50B, Low pressure rehester drain tank drain j 728, 81B, 90B bypass to condenser: valves, 1-1/2" piping i and fittings and 4" piping and fittings ) downstream of the valves to the condenser 1 5. LCV 6-135, 33B, 56B, High pressure rehester drain tank drain bypass 76B, 85B, 94B to condenser: valves, 1-1/2" piping and fittings and 4" piping and fittings downstream of the valves to the condenser 6. LCV 6-15B, 35B, and Heater 1 drain bypass to condenser: piping 58B and fittings downstream of the valves to the condenser 7. LCV 6-9B, 31B, 52B, MSR drain tank drain bypass to condenser: I 74B, 83B, 92B valves, 6" piping and fittings downstream of valves to condenser ~ 8. LCV 6-1278, 147B, No. 4 heater drain bypass to condenser: 166B valves, 3" and 4" piping and fittings downstream of valves to condenser 9. FCV 7-1, 2, 3, 4 Main steam pipe drain to condenser: valves, piping and fittings downstream of valves to the condenser 10. FCV 7-5 Lapulse chamber drain to condenser

valve, piping and fittings downstream of valve to l

the condenser 11. FCV 7-6, 7, 8, 9 Crossunder pipe to MSR drain to condenser: valves, piping and fittings downstream of valve to the condenser 12. FCV 7-10, 11 Steam vent MS to condenser: valves, piping (WBN'only) and fittings downstream of valves to the condenser AJ. FCV 5-94, 95, 96, Low point drain on extraction steam line 97, 98 valves, piping and fittings downstream of valves to the condenser G84296.01 l l.

-_ ___-__ __, Continued i 14. Piping downsteam of MB drain traps to drain destination.

15..FCV 3-602 Long cycle recirculation manual control valve:

(WBN only) valve, piping and fittings to at least 5D downstream of valve. 16.. FCV 1-103, 104, Turbine bypass (main. steam dump): valves, 105, 106, 107, piping and fittlage. downstream of valves to - 108, 109, 110, condenser 111,-112, 113, 114 17. LCV 6-190B No. 7 HDT bypass to condenser (WBN). On WBN (WBN only) only, the 10" and 14" piping and fittings to the condenser III. Inspect every third refueling outage (decision on type of replacement material to be based on accumulated service life at time of replacement. and remaining plantlife).

1. - LCV 6-9A, 31A, 52A MSR drain to No. 3 RDT: valves, 6" piping and-74A, 83A, 92A fittings to at-least 5D downstream of' valve 2.

LCV 6-127A, 147A, Heater 4 drain to heater 5 drain cooler: 166A valves, 3" piping and fittings to at - least SD downstream.of valve 3. LCV 6-133, 153, 172-Heater.5 drain co heater 6 drain coolers valves, 6" piping and fittings to at least SD downstream of valve 4. LCV 6-138, 158, 177 Heater 6 drain to No. 7 heater drain tank: l valves, 8" piping and fittings to at least SD downstream of valve -5. Low-Pressure Extraction From low pressure turbine to feedwater Lines Nos. 5, 6, and 7 heaters, especially elbows, tees, etc., and downstream of elbows 6. MS to MFPT All piping and fittings 7. FCV 2-35A NWP recirculation (gland seal exhauster): valve, 8" piping and fittings to at least SD downstream of valve G84296.01 l l

i t

8. - FCV ' 2-604, 605, 606 CBP recirculation: valves, piping and-fittings to at least SD downstream of valve 9.' FCV 2-3298 Blowdown heat exchangers valve and downstream piping to heat exchanger. Also, header inside j

at the flash tank. High points and downstream of valves in staan generator line from ateam generators to turbine building i 10. FCV 47-291, 292, 293 MFPT GS drain orifice bypass: valves, all (WBN'only) piping and fittings _ downstream of orifices l l 11. FCV 3-187, 186, 185, SG MrW check valve bypass: valves, all 2" 1 88 piping and fittings (WBN only) i 12. FCV 3-191, 192, MrW deseration line valve: valves, piping and 193, 194 fittings to at least SD downstream of valve 4 (WBN only) I 13. FCV 3-195 Isolation valve for long-cycle recirculation i (WBN only) manual control valve: valve, piping and fittings to FCV 3-602 i 14. PCV 3-40 Demeration line backpressure control valve: i valve, piping and fittings to' at least 5D downstream of valve

15. AFW Cavitating Venturis - Venturi and downstream piping and fittings to at least SD from venturi I
16. LCV-15-18 Flash tank to condenser: valve, piping and fittings downstream of valves to the condenser l

l

17. LCV 6-190B No. 7 HDT bypass to condenser (SQN):

10" piping and fittings and 10" x 14" reducer 18. High pressure turbine exhaust piping to MSRs: Since replacement piping is considered cost prohibitive, erosion rates should be carefully monitored 19. LCV 6-185 Atmospheric condensate drain tank pump discharge to the condenser: valve, piping and fittings downstream of valve to condenser

20. LCV 2-9 Auto makeup level control valve: valve, piping and fittings downstream of valve to condenser G84296.01

,I A i ATTACHMENT 4-q 1 BFN RECOMMENDATIONS j 6 Erosion-Corrosion Study i i I I. Inspect immediately (at earliest opportunity - decision on when to be replaced to be based on criteria identified above). 1. LCV 6-62A, 62B, 73A, Moisture separator' drains to heater A2, Bc, 73B, 84A, 84B C2: ECN P0648 has been written to replace. piping and fittings between the valve and No. 2 feedwater heater with SS. 2. LCV 6-1, -19, -37 Heater 1 drains to heater 2 drain coolers: piping and fittings downstream of the valves for at least SD. Inspect valves and replace I if needed. 3 LCV 6-4A, -22A, -40A Heater 2 drains to heater 3 drain coolers: { piping and fittings downstream of the valves I for at least SD. Inspect valves and replace if needed. 1 4. LCV 6-7, -25, -43 Heater 3 drains to heater 4 drain coolers: l piping and_ fittings downstream of the valves for at least SD. Inspect valves and replace if needed. II. Inspect every refueliny outage (replace with SS components as required based on above defined criteria) 1. LCV 6-11A, -29A, -47A Heater 4 drains to heater 5: valves, piping and fittings downstream of valves for at least SD 1 2. FCV 3-6, -13, -20 RFP minimum flow recirculation orifice to l condenser: orifice downstream of valve, piping and fittings downstream of orifice to condenser 3 Main Turbine Crossaround (Replacement is considered cost prohibitive; Piping piping would tuve to be repaired, if eroded.) l 4. Steam Extraction Piping ] l l III. Inspect eirery third refueling outage (decision en type of material to i be based on accumulated service life at time of replacement and remaining plantlife) l 1. LCV 6-55A Condensate drain tank drain to condenser: ) valve, piping and fittings downstream of valve to the condenser 2. LCV 6-14A, -32A, -50A Drain cooler A, B, C to condenser: valves, piping and fittings downstream of valve to the condenser.

l l ATTACHMENT 4 Listing of TVA Inspections for Pipe Wall Thinning Plant Date System Inspected

  • Report BFN - 1 09/77 Crossaround Piping Y

12/78 Crossaround Piping Y 05/83 Crossaround Piping Y 03/86 Crossaround Piping N BFN - 2 03/78 Crossaround Piping Y t 05/79 Crossaround Piping Y 08/85 Crossaround Piping N BFN - 3 05/84 Crossaround Piping, Extr. Y Steam, EECW Piping 11/86 Crossaround Piping N BFN - 1 12/84 Equipment Drain Lines Y BFN - 2 05/83 Turbine Exhaust Piping Y BFN - 1 07/82 MS Drain Piping Y BFN - 2 09/82 MS and MS Piping Y 01/83 MS Drain Piping Y BFN - 1 01/87 Extraction Steam Piping N BFN - 2 08/85 Extraction Steam Piping Y BFN - 3 11/86 Extraction Steam Piping N BFN - 2 05/87 Feedwater Condensate Piping Y SQN - 1 02/83 MSR Drain Tank Lines (Failure Analysis) Y SQN - 2 11/84 Extraction Steam, Crossaround Y Piping SQN - 1 03/86 Crossaround Piping, MSR Vent Y Lines, Heater Drain Lines, Extr. Steam Piping SQN - 2 01/87 Feedwater, Condensate, Extr. Y Steam, Heater Drains, & Vent Lines HBN - 1 03/85 Extraction Steam and MSR Vent Y Lines (Baseline Inspection)

  • Y-Yes, report is included l

N-No, report is not included i f

l ElEE.W__4.kk THINNING INSPECTION DATA 1 PLANT: O UNIT: I INSP. DATE: ST- /'77 7 SYSTEM: [roerm a / Mio /,- p MTL. CLASS./ REFERENCE THICKNESS: LOCATIONS INSPECTED: G 'A z,2 # PURPOSE OF INSPECTION: dek FOR WALL THINNING 7 Mu / \\ INSPECTION DETAILS: Smd f \\ i j METHOD: UT INSTRUMENTS: GRIDS: ) INSPECTION RESULTS: k d, J' u e-> l n , A- - e ls,- r-s Ah p u e i CORRECTIVE ACTIONS: h/~ E- ,Z a.# <ad + f e / REPAIR / REPLACEMENT 7 MATERIALS CHANGES? FAILURE ANALYSIS? DOCUMENTATION Ab.nr 2 ~ L W. ##. ) f. Ad F1 SiE/o /1 /477 I /Am-n n,idi r eis) 1 4

a L av vJ. army had awn =4 m

  • hPd a=** 8hm y.4

.. w -

e
+ ;
:p vc n

~ ) (. . d, - }'. .. g)) , ),.. . j ,.?;~ ~

  • a.

.) '[. r + 4 >;y' , _ j ey = m'. n 4 t ) n c) r u 5.. < 3 i I v e.. j cmr p mm mvmxam. MB '771013 015 Memorandum rrystssts vitt2Y AUTHORrrY 771017A0433 ro .ch.aou o o - 3raooo m m. r= r., W. w, m e n rui -er, u m c.1 00713 E77 i g SUEJECT: BR3rMS FtzRT NT:2AR P:Ar! 'Kl? 1 - f.A.I.R CQETUHEFT T L'XA3 p c e W f6C60-90TW6 - ;3EU'EC"'!3r 01 "UtBDE CRC 68TD PIFI30 ) ElblJ.1 At the requmet of II "KS, azit 1 croesumiar piping vsa criemed for inaimation during tbs current refueling autage. 2 vsa tarited to participate in the 1.wpection, bett Ei xt send errytne on anytamber 21, 1777, rusa I first emared this piping. la riev of the artenainly aroded areas of pipig vtzich I ctearved, em requested that (E send same of theLr design engineers true Schenectady to ermaine this pipe. W. P..Toest, antal.lurgical engineer, and I est with 'E's Frank Stunt. l Bob Liaiinger, Bruce %sse rt, and :) eve Mesaaer at the site an I Septmosbar 29,15r77, to further examine this piping arxi briefly itsensa how tatia oaeparee with 3's experieaos on crtbar unita. After exantinir4 t all six rtma of pipe, 2 conclMed the follortis': s l L :)epth of pittoi areas rence from 60 to 30 mila with o.*6 inen i being the trinimum wall observed. 2. Other units wrich have been etasairmed exhibited s tallar rear

sttarna (similar btst act identica.1--eacn ucit hea its own enarec-

{ teristic metr ;sttarn). n J. Ny are st il.1 anoertain of the sectanism of attaca, but tamed oc their experieoos 60 to 30 tila la ta far as this process will go.

X erperience has ahwu that at tAls ysint, a prot ecti ve oxi.is ia farmed vt1ch reaista ftrr*.her attact.

'2 selseted a langth of one run af pi;e veie.b ther *.r; met to contiaan ta be errxiad for aone pariod af ttan a tai plaos4 e ec.4 rue re fererz:s grid (1 1/2 4et by 3 feet ) an the.m tat.ie af the pipe ani dtrascx11cally "as;ted" thre rail thickness at each t eid put'It far rw f are tre purposee. After a ramirting t.N piptog and ta111ng with.X, ; ha ve the folivring observatirms [ 1. "here is no set ;att e n if voar ( ettac k ). Same piping r una j [ v ha ve e rta na i n ge ne r a li se<. we ar pattarna vtila otbars s;5 ear g to han a series af periA! ctreu.lar ar spirst riags af m r. = Still othe r pipi:4 runa he re s imost ao==e ar. 4 a \\

L mevaammeanea h4.eemoseasheaan

u. >
o. -

mim. efs. ai m '771013 015 Memorandum TMMESSEE VAEEY AUTHORrrY = no.a a w.-ag me nue 771017A0433 Fheer / L. W. Boyd, teamhandaal heisser, V10At5 C-E h = - i en. avasact: BGM PERT EUCIEAR PLA52 WIf 1 N4JOR BElIBERT PAdEAS OWMACT 660ddHMrfb4. IMPECTIGI QF,2MRIE CROSSEME PIPIEG E1H-1.4.1 m the zogamet of EE MB, mit l' arossender WWas was opened far inspection during the currest refueling outees. S was invited to participate in the inspection, but did act seed asysse on Soyeester 21,19f7, esa I first essered this pipias. In view of the 4, 17 eyeded areas of % gas whiek I observoa, we req. nested that S seed some of their deeien engineere feen Seheneeteer to j samadas ikLa pipe. W. P. Joset, notallurgical essiaw,o, sad I art with.s's Preak Stuek, 3 u m.e_, .ee.eee. ne e site - her ar e, I m, t. far.rt, aor -- me ar et ( e, a pix as a.d m.f2, e.e.es is esmoures with s 's superienne on o.or unita. After===w asw eli sin s n e of pipe, a e==ai=aad the follastag: 1. noyek of pitted areas rense free 60 to 80 stis with 0.36 inok { being the aimisme sail ohearved. 2. Other amits which have been amendmed exhibited similar weer i patterne (*4=e1= but act idessioal--eech amit hee its own cherno-l terista.ser - 3. . 3. , ore stiu s ort.. e,.e.e.=,- of etteo., b.t - - l their experisese 60 to 80 mila is as far se this process will go. E 3 esperisese bee chose that at this potat, a protective i oxide is funned which resista fureer etteok. 3 selected a length of oss run of pfye which ther expecrt to continue to be eroded est eene period of ties and pleoed a coerne retierwece srid (11/2 fw by 3 feet) on the antaide of the pipe and ultrasonically "anyped" the wall thichases et noch grid point for l refuswace purposes. After a m imimg the piping and talking f with 3, I have the follosing observations: E 1. more is no set pattern of wear (ettack). Some piping runs f [g have atensive sam,m aused wear,ariooo o or.pire.re es,.ar v patterm mile othe - e seri.. o .,.e.r. still other piping rune betw alanet no wear. 3h

5 8 ./ U SO s LNdu Regularly en the Peyreat seemer pga, ,r t -1 e i/ t .e i .c 5 1 / f ) i meenaie.1 m.c-ing Er.ae nl i ^ { l' OCT 13 IFF ( BOM FMRT MEIEAR PLurf GL*f 1. MAJOR EQUI 7merf PACIWM ) caewf esaso.som zumme or mazz - raIEo E3H 1.4-1 I I g ) 2. Piplas em the west side of the aschine toads to be vorm worse than f em the east side (passibly ano to more meistare entering these rene ese to rotation of the machine and asesle wientation). 3 S'Jee seees dich were being eroded away wtro mirror bristre i dils othere were covered with a dull, whitish oxide. Snese } 1ater areas wane the case which 3 elafen are "passiveted" I [ end will act erode further. k. The elboos were set eroded (eseept for a few isolated spe's) } even in runs where thsee was extensive erosion in the s* sight. runs et pipe apetream and crastroes of the elbow. 5. some arena inside the asistere asu awnibit the seen 7- -- 7 but only la small ionalised areas.

6. If the present weer rate d a==e, these pipes will have to be j

replaced within 5 or 6 years. 31moe 3 vos cedy inoking for sneeral oeer patteras ami not et f, specific areas, W. Joest and I regeseted that P 193D outage peroammel make i.trasomia emendnetions as indioeted below and forward g' the results to EN IMI. l f 3 Nahe a 3.imek.egasre grid pattern ce the to? half of a

3. foot.long f

section of the horinostal pipias run to moisture separator No. 3, f This is in sa ares where there is ocasiderebla voar and the surface 7 is shiar (indiosting what S refers to es as " active" area which can be espected to wear further). 2.

  • Map" (3. inch grid) the generalized weer area immediately downstream of the first elbow in the ease run of pipe. This ves the only such area observed by erself in any of the runs of pipe. 3 did not crevi up this rua of pipe to inspect this elbow.

I i Snese ultrasonically aspped areas will allow for future i reference exsuinations to determine if further wear has f 4

c.. ~ ~. 4 0 L l 3 I. i h 4aai W=mering Bremak F12me McEW FERIT EUC12AE FIANT tEIT 1. MAJS EQDIBGET Pu'nta CCEIRACT 66C60 97tW. DEFECTIN W TtERINE C3055DEDER FIPIEQ EU6-1.b.1 g i oeourred. n===inations will be perferend at lasst every endor outase. Sinoe unita 2 and 3 croesuador piping contain approximately 1 percent total Ei-Cr-Cu (as opposed to 0 3 to 0.6 Ca in unit 1), this piping vill also be inspected during their refueling outases ter e mparison purposes. 7twtoe et this piping are availab3m et er desk. A_..Q[. A ( Iars v. Boyf M DfE:8EE I se D. 1. Patterson [ C. A. N diar { G. F. Eilworch l f i

    • mP:AE-OCT 1 3 1817 i

oe Bivens. 5100 min-r { . Eb837 C.E j mor L puaban, W uA9 C.K y i i f \\ oct 13 571 IED:PEM ces E. 8. Fox, 716 EB-C (2) i

W NS$ 97lOl3 0E gm _,,33 QK Flft MALk THINNING. INSPECTION DATA OW UNIT: / INSP. DATE: Bec. 74 M 7f PLANT: 7 STSTEM: bre ern es v ^ d kno' cn Q MTL. CLASS./ REFERENCE THICKNESS: LOCATIONS INSPECTED: PURPOSE OF INSPECTION: FOR WALL THINNING? INSPECTION DETAILS: METHOD: INSTRUMENTS: GRIDS: INSPECTION RESULTS: CORRECTIVE ACTIONS: REPAIR / REPLACEMENT? 4 MATERIALS CHANGES? FAILURE ANALYSIS? DOCUMENTATION: 1 t

i \\ , e u.4 e UNrrED STATES GOVERNMENT Memorandum TENNESSEE VALLEY AUTHORITY [ Mechanical Engineering Branch Files j To d R. L. Lahti, W100186 C-K j FROM f JUN 5 1979 DATE

SUBJECT:

CORROSION EROSION OF CROSSUNDER PIPING AT BROWNS FERRY NUCLEAR PLANT { On December 20, 1978, L. W. Boyd and R. L. Lahti examined the crossunder piping at Browns Ferry Nuclear Plant unit 1 to determine if the corrosion-erosion pattern had changed and to select two sample areas for removal for metallurgical and chemical analysis per ECN PC062. L. W.,Boyd documented the initial examination in MEB 771013 015, " Memo to File". I. OBSERVATIONS After a review of the ultrasonic grid measurements regarding the rate of erosion which were made during this outage, no conclusions could be made since almost all areas appeared to be somewhat thinner than last year. A more detailed study will be made after the next outage when.we have more data. The pipe ID has the typical "tigerstriping" pattern of pitting in the straight lengths. The elbows and turning vanes appear to be. totally resistant to this phenomenon because no pits were observed on them. Because the same material was supposedly used in the elbows as was used in the pipe, a study of the manufacturing methods is being made to determine what causes the different reaction to the environment. One of the samples which will be taken will have enough material from the elbow that a chemical analysis can be made to verify that the elbow and pipe material are the same. The longitudinal and circumferential welds were not excluded from attack. Most attack of the welds was in the normal tiger-J stripe pattern, but the weld connecting the pipe to the turbine seemed to be preferentially attacked forming a ring. That weld was about six feet from the closest vantage point so one could ] not tell for sure whether it was the weld or adjacent base i material that was being attacked. The ring caused by the attack at this point was unique. The first examination did not reveal any attack on welds. Looking into the turbine exhaust area, one' O rld see a corrosion / erosion pattern that seemed to be completely rendom. The pits did not appear to be as deep as what was seen in the pipe. N f iY ~

2 Mechanical Engineering Branch Files JUN 5 1979 CORROSION EROSION OF CROSSUNDER PIPING AT BROWNS FERRY NUCLEAR PLANT ] The pits in the pipe were primarily of three types: l. Those which will be for convenience called "last year's pits" j were covered with the red or gray oxide which covered most of the rest of the pipe. 2. " Active pits" which are gray and have no shiny metallic appearance. No pits were found with the very bright mirror-like finish such as were found at the last outage. Some of the active pits were found to reach into last year's pits disproving GE's theory that inactive pits would not corrode further. 3. "Passivated pits" are those which have a thin,' light gray finish. These are what GE considers inactive. The oxide ranged from a bright red-orange to a dark charcoal gray. The gray oxides were found downstream of pitted areas and appear to be the result of discoloration of the red-orange oxide by the metal being eroded away from the pit. The turbine exhaust area to the first elbow to the horizontal pipe was covered with a light to medium orange oxide with the exception of the gray active and passivated pits. In the straight, horizontal pipe, the oxide ranged from medium orange to charcoal gray with streaks of bright red-orange eminating from some of the pits. From other pits, the oxide streak was varied in color and ranged from orange to gray and appeared to deposit as a bump or drift on the downstream side of the pit. The oxides appeared in the form of a compacted, fine powder which was easily removed with a penknife. The depth varied from almost no oxide to approximately 1/8 inch. II. POSTULATED In an effort to explain this phenomenon, the following scenario is offered: The steam has a turbulence which sets up a standing wave where flashing occurs in the low-pressere zones. The action of the flashing causes the erosion pattern. Without a standing wave or stable flashing pattern, the erosion would not occur. The unit load, the moisture content or bulk steam velocity, or localized flow disturbances such as the pits themselves could have caused a change in the pattern of the corrosion / erosion pits. 40310/2

3 Mechanical Engineering Branch Files JUN 51979 ~ CORROSION EROSION OF CROSSUNDER PIPING AT BROWNS FERRY NUCLEAR PLANT III. CONCLUSION-Corrosion / erosion will continue in the material that is susceptible to this phenomenon as:long as-the plant runs. It is not a self-limiting system; therefore, TVA will either have to replace or protect the pipe. MEB is pursuing a technical and cost analysis to determine which alternative is most desirable. A '(gf R. L. Lahti (,: A, RLL:MGR cc: D. R. Patterson, W10C126 C-K LlOS){j$ / DRP:MGR. JUN 5 B79 cc: D. B. Bowen, 5200 MIB-K Roy H. Dunham, W11 A9 C-K MEDS, E4B37 C-K / e d i t 415637/2 " - ' - ~ ' - - - - -. _ _ _ _ _ _

PIPE HAkk THINNING INSPECTION DATA FFM UNIT: f INSP. DATE: Alg / YJ PLANT: SYSTEM: NebN e Defwasd AS:nv V MTL. CLASS./ REFERENCE THICENESS: S Opor O N Mua d Qowu LOCATIONS INSPECTED: PURPOSE OF INSPECTION: 6cor b - c owo - ! ~ e 14 < !~ d FOR WALL THINNING 7 INSPECTION DETAILS: Ge e2gd METHOD: Viesd J UT INSTRUMENTS: GRIDS: Gr Pb,

  • e ef INSPECTION RESULTS:

f, 8c d CORRECTIVE ACTIONS: MAb du OT a d t/ E l l~3e Ach f / REPAIR / REPLACEMENT 7 MATERIALS CHANGES? FAILURE ANALYSIS? i DOCUMENTATION: Ab me d A 2 64 vote -. I ~ 6./~ M ~ 8 Th u 29, / *]/] fL29/2cle29 f* 77,){ 1

I ~ /- L29 830629' 877 'JUN 2 9 S33 1' l \\ l C. R. Favreau 12110 CST 2-C I

Subject:

BROWNS FERRY NUCLEAR PLANT UNIT 1 - INSPECTION AND EVALUATION OF TURBINE CROSSAROUND PIPING Attached for your information is a copy of the metallurgical inspection report pertaining to the subject piping. f. lHarwell

f. F

[ GJP:TRW Attachment cc (Attachment): NUC PR ARMS, 1520 CST 2-C Johnny Miller, Browns Ferry This was prepared principally by Terry R. Woods. B21753.FB Sd cc: X W, F M, d != D L W V4.Q ' . _ _ _ - _ _ - _ _ _}}

Retrieved from "https://kanterella.com/w/index.php?title=ML20234F590&oldid=3954533"