ML082330525

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July 2008 Evidentiary Hearing - Intervenor Exhibit NEC-JH_43, PP7028 FAC Inspections 2004 Refueling Outage
ML082330525
Person / Time
Site: Vermont Yankee File:NorthStar Vermont Yankee icon.png
Issue date: 07/23/2008
From:
- No Known Affiliation
To:
NRC/SECY/RAS
SECY RAS
References
06-849-03-LR, 50-271-LR, Entergy-Intervenor-NEC-JH_43, RAS M-211
Download: ML082330525 (41)
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Text

NEC-JH 43 PP 7028 F]ACINSPECTIONS 2004-REFUELING OUTAGE TABLE OF CONTENTS

[

FAG 2003-2004 Program EWe Program Seeping Memo 2

2004 Refueling Outage Inspection location Worksheets 1 Methods and Reasons for Component Selection 3

VYM 2003/009 DEWMS Memo: J.e.Fitzpatrick to S.D.Goodwin subject,.

Piping FAC Inspection Scope for the 2004 Refueling Outage, dated 3/27/03, 4

2004 RFO FAG Scope Challenge Meeling Notes 3/28/03 5

2004 FAG Outage Implementation Scope Challenge Meeling Noles 12/02/03.

6 RFO 24 FAG Personnel Adjunct Training I Pre-Job Brief Handout (includes Sample Report Format, Scope List, & Component Gridding Requirements) 7 2004 FAC Refueling Outage Inspection Report (Text portion 01 ENN-DC-147 Engineering Report No, VY-RPT.04-00010,.Rev_0) 8 Component Evaluation Worksheet-index 9

Component Evaluation Worksheets Large Bore & Small Bore Piping Pages 2-6 7-19 20-40 41 46 47-59 60 -79 80 81-448 1!

DOCKETED

  • USNRC August 12, 2008 (11:00am)

OFFICE OF SECRETARY RULEMAKINGS AND ADJUDICATIONS STAFF m9IflNw Stw f 1

Page 1 of A4' NEC020179

.Engineeing Department Work Management Handbook 2003.2004 Program Scope Memo Vermont Yankee -Engineering Department WBS Element:

6098 Pro"ect Number:

6098

Title:

Piping Flow Accelerated Corrosion (FAG) Inspection Program 2003 & 2004 Efforts De artmenl:

Des! n En ineerln

- Mechanical I[Structural Owner: James Fltz trick Backu : Thomas O'Connor Procedure. pp 7028, Piping Flow Accelerated Corrosion Inspection Program No. &

Title:

Detailed Scope of Prolec (explanation); Engineering activities to-support ongoing Inspection Program to provide a systemnatic approach to insure thai Flow Accelerated Corrosion (FAC) does not lead to degradationofplanl piping systems. Program Procedure PP 7028 controls engineering and Inspection activities to predict, detect, monitor, and evaluate pipe wall thinning.due to FAC. Activities include modeling of plant piping using the EPRI CHEGWORKS code to predict susceptibility to FAG damage, selection of components for inspection, UT inspections of piping components, evaluation of data, trending, monitoring of industry events and best practices, and recommending future repairs and for replacements prior to component failure.

(

Expected Benefits (Justification): VY committed to have an effective piping FAG inspe:fon program in response to GL 89-08.

_Consequences. of Deferral: Possible hazards to plant plersonlqeLUoss of plant availability, unscheduled repairs, and deviation from previous regulatory commitments.

Duration of Program: Life of plant Kev Deliverables or Milestones:

Completion Estimate Issue 2002 Outage Inspection Report 1/20203 Issue 2004 RFO Outage Inspection Scope per Entergy template (14 3M27/03 months before outAae). Includina. Scobinnq worksheets.

Update Piping FAG susceptibility screening to account for p*pIng and 611/03 drawing, updates. Include consideration of power uprate &iIf2 extension, Update piping Small bore piping database and FAG screening to 7/1/03 account for piping and drawing updates. Include consideration. Of Power uprate &life extension..

Update GHECWORKS mOdels with 2001& 2002 RFO Inspection data 9/1/03 (Note ideally results are to be used in detennining the 2004 inspection scope, however schedule mllestonas override prbogrm Iopic.)

NEG020180

Engineering Department Work Management Handbook Key Dellverables or Milestones: - continued Completion Estimate Updates to Program Procedures as identified in Self 6/1/03 Assessments.

Develop FAC Program Health Report Template (Format and 7/1/03 Performance Indimitors).

Perform Program Self Assessment (minimum once per cycle).

10/1f03-Ongoing Program MaIntenance. Includes: procedure revisions.

12f31/03 program Improvements, benchmarking, attendance at industry meatinns & evaluation of Indusl events for effects on VY.

RFO 24 support 5/1f04 Issue 2004 Outage Inspection Report 7f1 5f04 Update CHECWORKS mOdels with 2004 RFO InspecUon data.

8115104.

Issue 2005 RFO Outage Inspection IScope per Entergy template 8115104 I(Anpox. i4 months before outage) Including Scopinq worksheets.,

Perform Program Self Assessment (minimum once per cycle).

1011104 Ongoing Program Maintenance. Includes: procedure revisions, 12/31/04 program improvements,, benchmarking, attendance at industry meetinos & evaluation of indust-v events tor effects on VY Estimated Bud etorEx enses:

Amount Ca lured in DE MechJStruclural Base Bud et.

NfA Others Impacted By Project:

Support Required?

Estimated Review Yes/No Hours 2120- S tern En ineerin YES 40 2130 E

ineeri Su. oft 2160 Fluid S stems En ineerin YES 40 9 1 fT Pl*_ntrinnll119.

Fon inprinn 21bu iecnanicalu iructural ues n others:

Level 3 Fra net:

Attached Performance Indicator (as applicable) Performance Indicators for FAC Program wilt be developed in new Program Health Reports Task as defined above.

i J

I NEC020181

Engineering Department Work Management Handbook YEAR zuu'+

Preparer Revlower TOTAL Est; Est.

Task No.

Task Description.

(HRSJ (HRS)

(HRS)

Start Delivery f Estimated Estimated.

Estimated..

Completior Date RFO 24 support 04-1 160 80 240 3/15/04 5/1/04 Issue 2004 Outage. Inspection Report. Required within 90 04-2 days of startup from.2004 outage 50 30 90 6/1104 7/15104 Update CHECWORKS models with 2004 RFO 04-3.

Inspection data.

120 50

.160 6/1/04 8/15/04 04-4 Issue 2005 RFO Outage Inspection Scope per Entergy.

template (14 months before outage) Including Seoping.

40 20 50 8f0/04 8115f04 worksheets.

04-5 Perform Program SelfAssessment {minimum once per 40 20 50 9f1f04 1011/04 c-,c1,e.

04-'

Ongoing Program Maintenance. Includes: procedure 200.

50 250 1/01/04 12131104

.revisions,. program improvements, benchmarkJng, attendance at industry meetings, evaluation of industry events for effects on VY.

Total 2004 Hrs 880 z

I":10 0

0

28 Piping FAC frr,-ection Program Level 3 Fragnet I

'Task DescrIption J )

W" Dfllfl to 8 Ow Urt for P Pipn and dmrVuv~~,pdates, Incdudo

~rt lkaton 01 pow~ up"it. &,

lito 05-3

________150 2atO~P~i1 Small bare piplM

(

tBWU and FAC meaningW t

=outnt for pipihg and dmw1 ng fJpdates. Inctdude, cosideraon of QiQ OW~r UP~afe & 1if extenslon),

180

,ýdtCHEC WO.RKS modeI4 Wvtli

=2011& 2002 RFo lnsp~cton data (N~tO id5RIlY ýefti~ S to bO Iil5d In detWMmntng the 2004 Iinspsedon I~c0~G h

Soe~ule Milesmes&

overdde progrm rogo.)

=.I I Fi-nish jANq I FI I

A M

S 1

FEB,._.B i AP_.R.MAYJUN JU

[AUG SEP.OCT NOV I -

I D.EC I

30 80 141_15/03 611/03 IDEC k-k 4o 1.120

-I I

5/11103 711/03 z

w M

0. UPdataM IQ Program Prooodures as 06 irie7nUed In SWiAssessents.

~Report Template (Format And 120 160

'180 40 120 7/1 1031 5/1/03 911/03 WVI03

.i

  • i igfll

[

-/ii llt]

i I

I I

i :

n, I 4A w

A1IW.

I a

Perormon PtOOra SOAiASssooarnent*

,(minimumn once p~er -cyds)

Includec. proodirer9t'sionsý.

program improvemonts, banoflmwiftb aftt~danc a mrerye

&vq.,& Oyad~Lton of JtMusb' 'wtsa (of eh~ads on vy.

I I

40 120

, I 160 I.

I V

I1 7/1103 10111031 I

\\. \\

I

!I I, I I

160 40 200

.1/1103 12..311,3

OcN CIA urrant C.immn Bull T*

-"O 8098033 Upidete Piping FAC SusacptibliLtY 80".

-Orwe 15AFRO3A OM.UN03 34* ME.PITZP, IN 60.00 a' aogaos.

ý910 pd0ai. 1 Pirgrsm irr edU.ý as Identlflad In SA OVMA AOOO 2JU-.I2

! M~TP ECNN 00.00

.2.4s0 Itd~~

Plcin Srmall.

fpierd Dalabna, O FAC 01JUNCA 01AtJCOS 43 EFn7ZP, RA5-OCONN 20.00 0

0608~37 DeVIodo FAfC Progiam Heaftb Reen TompI0I*

M~UNHOS OIIULOO 22W' JE.FIP, ME-OOOMNN 30.00 0

340303 qpdiW CHECKWORKS Model w/2001i2002 KFO.. a.ct 01IJUL03 28Ep{J3 419*

E-IT2P, ME-QOONN 130,00 4

GO9ODS&

port" POM Soff.1 Aswsmenamf d1JULý.Y iGOCTO*

Jam.a E-lP 8AEwOCONNI 80000 59 N0O3SND 23POQ90 Emoslomcn.Corron~r Pow mant inteunence

  • NOIA 240KtCO3 206.00 0 4203EEN0 6'G 4 Issue 200A Oubiie. InspectIoi, '..pofl (90 Day F1*;:i)

OIJU.,.a4 32-ME.FITzp msoOON 9{ 00

.4 600604' PF24-20 oo0.-.

jpdM. 0O4ECKWORKS moidel vJ 2004 ftrO Iui~et a

BJUL04

  • ERP0S 54 E.FLrP,IZOCONN
00.

-28 60980S44 A4S lztue 200 RFO Outai;. nspect Omm Iq taryTeTmp 241SEFIDI

4OjcT04 1

¶ZP, Me-OCONK 60.00

.2 fic..045 Perform ý-"gram "I4 ý-*snn GtzEke4 01IOCT04 23' E-PITZP, MEOOONN 60.0 02 tMEND P866 0ir or.nPrmMjrAc 2J*MA

~

247 ME-OCONN. ME.FITZP 2r,,

2SWA5

,a*

u nd&V4.

iSJUL03-27AUGSj 22 4E.PITZP 0.00 A6 SIVTY Hlieorla Besalining O*.UG 100~TO 0

0 ME.F'TZP 0.00

.39 3CA06 Vy 0avW.AP Fatigue*

mnioi~ng WIOJLJL NOCT08 7

E-IZ 0,00-Af 20034.NO r23A7' II Iaelaln Tu~g eOf 10 11mE-FIT2P 0.00 3? 2 O3EKD 723008 VY. Fatigjue Projert Sug~)e1

  • 2JANOSA 10100.

.. a-urz-Frzp

'00000 0 2005END stad Dew011A2 A1nIsh C14i; 31 MAY07 Data Dat 12MAY03 Run Dalej John Dougherty EX 3098 VYEnginme0rfrg WOrk Control

VY Piping FAC Inspection Program.. PP 7028 2004 Refueling Outage Inspection Location Worksheets I-Methods and Reasons for Component Selection Reviewed Z?

-6/3 Piping components are selected for inspection during the 2004 refueling oUlage based on the following groupings and/or criteria.

Lar Bore _Eiping LA:

Components selected from measured or apparent wear found in previous Inspection results.

LB:

Components ranked high for susceptibitity from current CHECWORKS evaluation.

Le:

Components identified by induslryeventslexperience via the Nuclear Network or through the EPRI CHUG..

LD:

Components selected to calibrate the CHECWQRKS mOdels.

LE:

Components subjectedto off normal flow conditions. Primarily-isolated tines to the condenser In which leakage is indicated from the lurbine perfonnance monitoring system. (through the Systems Engineering Group).

LF:

Engineering jUdgment I*Other LG:

Piping identified from EMPAC Work Orders {malfunctioning equip., leaking-valves, etc.l Small Bore P~iping SA:

Susceptible piping locations (groups of components) contained tn Ihe Small Bore Piping data base which have nol received an initial inspection.

SB:

Components selected from measured or apparent wear fOUnd in previous inspection resuits.

sc:

Components Identified by industry events/experienoe via the Nudear Network or through the EPRI CHUG.

so:

Components suLected to cff normal ftowconditions. Primarily isolated lines to the condenser in which leakage is indicated from the turbine performance monitoring system. (through the Systems Engineering Group).

SE:

Engineering Judgment I Other.

SG:

P"lp'lng identified from EMPAC Work Orders (malfunctioning equip., leaking valves, etc;)

Feedwater Heater Shells NO feedwater heater shell inspections will be performed dur'Ingthe 2004 RFO. Previcus plans vra to complete the I IT grids on the No.1 & 2 heaters have been made moot by the decision to replace ali 4 HPfeedwater heaters for EPU. The Shellson all four new heaters will be a Chrome-moly material (P-1 1). Informational visual inspections of the open ends cf Feedwater, Extraction Steam,.Heater Drain, Vents and Moisture Separator piping will be performed as access is available.

Page 1 of1l I I

-S 1f $!ta pqP'iA4 4

NEC020185

VY Piping FAG Inspection Program PP 7028 2004 Refueling Outage inspection Location Wo-kshee_ t /Metho-ds arid Reaeohs for CbmO6n6ht Slectibii LA: Large Bore Components selected(identified) from previous Inspection Results

- From the 19951199611998119991200112.002. Refuelin9 Outage Inspections (Large Bore Piping) these components

-were identified as requiring future monitoring. Ttle following components have eitheryet to be inspected as recommended, or.the recommended inspection is in a future'outage Inspect.

Loc.

ComponemlD Notes/Comments / Conclusions No.

.SK 96-13 001 FDO1EL04 1996 report recommended inclusion of FDO1SPO4 into 2001 RFO Scope 96-14 FD01SP04 (lower readings at U.S. counterbore}.

UT InPeat elbow and downstream i e In 2004 99-03 002 FDO2.EL01 1999 Recommendation to inspect tee in 2002. Component is 99-04 FD02.TE61 dowllnstrea of pump 18."B. Pump IS used a standby pump, based on usage, inspeution was deferred until 2004.

UTinspect elbow and'downstream tee in 2004-99=25

00.

.FD14EL03 1999 recommendation to inspect pipe at upstream counterbore in 2004.

99-26 FD14SP03 Given that the only low readings were at the pipe counterbore and that 2004 RFO work includes replacement of both No.1 feedwater heaters located under the elbow.

Defer re-inspection olthe elbow FD14EL03 & pipe FD14SP03 unil the 2005 RFO.

101-03 001 FD01EL01

  • 2001 recommendation to inspectthe tee In 2.004. UT Inspect elbow 01-04 FDO1TE05 and downstream tee in 2004 (19098 RFO results recommended.

inspection in 2001)

Also add inspectioniof the reducer upstream olthe

._elhw

.02-08 016 FD18ELO1

-2M02 recommendation to Inspect (heelbow in 2007 based on a single.

0:2-09 FD18SP02US Measurement. Re-Inspect elbOW and downstream pipe In 2007 (3 I cycles from 2002).

Page 2 of 11 NEG020186

YY Piping FAC Inspection Program.. PP 7.028 _2004 Refue1ing Outage.........

Inspection Location Worksheets I Methods amI Reasons for Component Selection LA: Large Bore Components eelected (identified) from previous Inspection Results - continued Turbine Cross-around Previous Internal Visual UT & Repair History:

FLine Mai.

Year Internal Visual =V Intemal Thickness UT, Re irs Performed =R Replaced RF016 RFOt7 RF018 RF019 RF020 RF021 RF022 RF023 81992 F1993 81995 F1996 81998 F1999 82001 F200:2 36"-A GE*`

108-3 V

V V

V 36"-B GE" 1981 V

V V

V V

V 36"-e GE" 1981 V

V V

V V

V Y

,~

'5 3(

3(

0-A

" I-1-2" 198 V.

V V

O"-B CS.

Or inal VIUTIR VIUTIR-VIUTIR.

V/UT _

V V

0"-C.

P-22" 1993 VIUT/R 0"-0 P-22' 1985 V

"36' stnlghtpipesactions raplacad WIth GE 850A24F_ elbowson theB&Qlnes are o0 inaI GE

.D50A67D, elbows on A &0 lines are 050A67E (Thorn =0,625 inch).

'30" AB,C replaced with A691 CL22 (2_114Cr), Fittings A234 WP22. (Tnom. =0.625 inch) 30' B remains GE B50A2420, Fittings and GE.050A670 carbon steel (Tnom = 0.50 inch),

IV 1

pec~fcatlon

.i.!

I

_NOTE: Reference Dwg. No. 5920-6841 Sh.1 of2 needs to be updated with correctinf6rmation. This will be

!perfonned during the EPU design change effort.

2004 RFO HP turbine work and MS intemals/dralmn line work wAl haveall (4) 36 inch line manways open for access to perform internial visual-inspections.

Perform internal visual inspection of all four lines, Priority is A36"line for access to internals of the 12 inch diameter CS stub piece In extraction steam line. Also if manways and CIV SRVs are removed, perform visual inspection of the 30' C & D lines to confirm condition of P22 replacement materials.

2005 RFO based on Increased flows and the possibility of different flow regimes in both the 36 &.30 inch piping, perform a visual inspection. LP turbine work in 2005 RFO may provide opportunityforaccess to the 30- lines. As a minimum inspect-(2) 36 inch lines and the 30" B line.

i.

1*

.1 Page 3 of 11 NEC020187 I

VY Piping FAC Ispt!oqn _Program PP-7028 2004 Refueling Outage Inspection Location Worksheets I Methods and Reasons for Component Selection LB:

Large Bore Compon&nla Ranked High for Susceptibility from CHECWORKS Evaluation The current CHECWORKS wear rate calculations contain Inspection data up to the 1999 RFO and wear rale

  • predictions are current to the 2001 REO. The 2001 and 2002 RFO inspection data has been entered into the CHECWORKS database, However, updaled wear rate calculations are not complete, and won't be in time to support

. the schedule date for Issuing the inspection scope for the Spring 2004 outage. Based on a review of the 2001 and 2002 RFO inspection data for components on [he Feedwater, Condensale, and Heatar Drain Systems, the' CHECWORKS models still appear to over-predict actual wear, Nothing newar unanticipated was observed in 2002.

Feedwater System Listed below re components wh',ch meet Ihe followIng criteria:

a) negative time to Tmin from the predictive CHECWORKS runs which include Inspection data up to the 1999

RFO, b} no inspectloras have been performed on these components or the corresponding components in a parallel train since the 1999 RFO.

Component Location Location Notes ID Sketch FD07EL03 005 T.B Feed Pump Room No inspection data for corresponding component F008EL02 in other train. Inspect this orthe other train component In 2004. This componentwill be lnspcatod In 2004.

'FD07TE01 006 T.B Healer Bay Elevs 228 Components on other train were inspected in 19g8.

'FD07EL11

& 248 Results indicate minimal wear-After updating the CHECWORKs model with newer data, assess need foradditional ine ections In 2005 RFD, FD07EL12 006 T.B Heater Bay Bev, 248 Feedwater healer replacement to occur in. 2004 RFO.

Perform Internal visual Insp4ction at open end on this comnonenl.

FD14EL07 009 RX Steam Tunnel El. 266 Internal visual of elbow performed In 1996 during Check valve replacement. no indication bfwaliloss at that time.

Inspect this or the other train componeit in 2004, InsDect this corn nent In 20OM.

FD08EL02 011 T.B Feed Pump Room No Inspection data for corresponding component FD07EL03 in other train. Inspect this or the other train.

component in 2004. FD07EI03 will be Inspect&d In

2004, FDO8TE01 012 r, B Heater Bay Elevs 228 Intermediate components FD08EL06 & FD08SP06 were FD08EL07

&248 inspected in 1908, Resulls indicate minimal wear' After updating CHECWORKs model with newer data, asses need for Inspecting components on the train vS, these, FD08ELO0 012 TB Heater Bay Eiev. 248 Feedwater healer replacement to occur in 2004 RFO.

Perform internal visual Inspection at open end on this comronent.

FD15EL08 01 RX Steam Tunnel EL 266 Internal visual of elbow performed in 1998 during check valve replacement. no Indication of wall loss at that lime.

After updating CHECWORKs model With new&rdata, assess need for inspecting this component in 2005 RFO Page 4 of 11 NEC020188

@D)

VY Piping FAC Inspection Program PP 71128 2004 Refueling Outage I ns p e ii, on -L o c ti -o n Work -S' he 1 Mikfi6d& 6Hd 0R.ea.s -.s7f for Cbfriip6rienit Seldctidn LB:

Large BOre Components Ranked High for Susceptibility from CHEMWORKS Evaluation. continued Condensate System Only one component was identified as having a negative time to Tmin. This was CD30TE02DS, the downstream side

  • of a 24x24x20 tee on the condensate header in the feed pump room. The CHECWORKS prediction for the downstream side of the tee has a smatt negative hrs relative to the remainder of the components in the system and relative to the upstream side of the same tee. Other tees on the same header have been previously inspected and show no sigrnficant wear. The CHECWORKS model Includes UT data up to the 1999 RFO. The inspections on this system performed in 2001 indicate minimal wear. The 2001 inspection data witt be Input to CHECWORKS to better calibrate the model.

To inspect the components with the highest susoept*'fity as ranked byCHECWORKS and to obtain a more complete set of inspection data for the Condensate System inspect additional components between the No:3 feedwater heaters and the feedwaterpumps. Inspect CD30TE02 and CD30SP04 in 2004.

Moisture Separpr prains & Heater DrainSystem.

No components kientified as haVing negative times to Tmln, No components wera selected for inspection in 2001 or 2002 based on high susceptibility. However future operation under H-WC will change dissolved oxygen in system. A separate evaluation has been performed and components were selected for inspection in 2002. See Section LD below.

,Extraction Steam'v"e" Three components on this system with negative time to code min. wall. The piping is Chrome-Moly. ES4ATEOI &

ES4ATE02, 30inch diameter tees Inside the condenser have negative prediction (-3426@Hn.) for lime to min wall. The negative times to Imin may be conservative based on the modeling techniques used. Refinement of the model of this system is in progress. The negative time to tmin is most likely a function of lack of inspection data vs. actual wear.

Due to exlernallagglng on this piping and the location.inside the condenser. no compoe ame selected for external UT inspection in 2004 based on high susceptibility. However, an opportunity to parfOlm an Internal visual inspection of all the Extraction -Steam lines inside the condenser during planed LP turbine work in the.2005 RFO maypresent itself. See Section LF below.

Note the short section of Al 06 Gr. B straight pipe on line 12'-ES-lA at the connection to the 36 lnch A cross around

.line is not modeled In CHECWORKS. The component material should be included in the next model update.

Page5ofl I NECO201 89

VY Piping FAC Inspection Program PP 7028 _ 2004 Refueling Outage InspectIon Location Worksheets / Methods-and Reasons for Component Selection LC:

Large Bore Components Identified by IndustryEvents/Experience.

Review of FAC related Large Bore Operating Experianee (OEI and/or piping failures reported since January 2001 nap IPlant e

[Deseri tion & Recommendled Actions at VY

-Deseri Von & Recommended Actions at VY 4/7101 Callaway - PWR Unexpected extent of thinning in feedwater piping (NRC IN 2001-009 & INPO OE12342)Add'rtionai components were Inspected 'In the feedwaler system in the 0

II durin. the 2002 RFO in res onse to this event.

5/9/01 Grand GUlf-Pin Hole Leak in 4 inch carbon steel elbOW in RHR min flow line. System has low BWR use atVY <<2%. of time). A review of VYdrawings VYI-RHR-Part 14 Sht111 and VYI-RHR Part 15 Sht111 show elbows downstream of restriction orifices. Additional research into this event is warranted. Inspections oan be performed with the plant operatino. Don't include in the SCoDe of 2004 RFO.

11120/01 Hamoka 1 Rupture of HPCI/RCI 6 Inch steam supplylineat asection of pipe to RHR Hx BWVR s..rt*.VY'IS an olderdskon which dgoes not have lhisconfbiuration.

9124102 IP2 - PWR Pin hole leak on 26 W cross-under piping (HP to MSR) in vicinity of dog bones at expansion joint under location of weld overlay localiZedwear under/aroUnd a previous weld overlay repair. VY has solid piping (no expansion joints. Visual Insoections of CAR Dioina will be nwfnrrmed in 2004-112102 Point Lepreau-Failureof Extraction Steam Bellows from LP turbine. VY bellows are made from PHWR stainless steel. Primary causes of past failures have been cracking of convolutions and vibration failures of tie rods. The bellows War$ replaced in 1995 and should not be susr:rnIlble to FAC dama e.

1115102 Surry 1-PWR Leak in 8 inch Condenser drain headerfor 3 /4 'pt. FDW Heatervents. Also, CHUG thinning in Gland steam Piping Inside the condenser and thel2" Condenser Drain Meeting header from MS Drain trap lines. The only large bore drain colleclora! VY is the 8 inch diameter low point drain header. Inspect sections of this line during the 2004 RFO.

1/15/02 Cooper BW1R Thinning found in two 20 inch diameter exit nozzles offLP turbine for extraction CHUG steam piping, (VYba r.6placed all LPturbine stub pieces.upstream of the Meftinn exoansian bellowm with P-11 malerial, No actions are reeailred at this time.

6/02 Oconee I Wear found In Heater Drain piping downstream of bock valve. Ops was using the CHUG gate valve to control flow. All valves on VY HD system are control valves. Normal*

Meeting, flow downstream of valves is directly into the teedwater heaters. Bypass valve discharge directly into condenser. TPM monitors possible leakage past the Bypass valves.

6/24102 Prairie Island 1 -

Preliminary nolice of possible extraction steam tine piping/bellows failure inside PWR condenser. MSeg 1/2102 Point Le reau notice aba.

8129102 Turkey Point 3-Failure of a 6x10 SchedUle 40 carbon steel expander in Heater Drain System PWR downstream of a level control valve. Same valve on other train was replaced.

However, no inspections were performed on this valve (from INPO Event 250-020829-1, DE 14866. & Info a11103 CHUG Meeting), Location is similar to millstone 2 & 3 events in 1991/92. Piping on HD system at VYOS of normal level control valves is constructed from FAG resistant materials or planned for replacement wtth new Feedwatar Heaters. No actions are re uired for this OE, 1019102 Clinton -BWR Interoonnecting piping (4 and 6 Inch diameter).between RWCU Heat Exchanger not included in FAC program, Plant assumed they were equipment when in fact they are piping. VYhas replaced the original 3 Perflex Hx design with aU-tube Hx.

RWCU oig ino in this area is stainless steel. Therefore not an immediate concern.

I Page6ofl1 NEC020190

VY Piping fAC Inspection Program PP 7028 _ 2004 Refueling Outage Inspection L ocation Worksheets/ Methods and Reasons for Component Selection LD:

Large Sore Components Selected to Calibrate CHECWORKS The CHECWORKS models have been upgraded to include the 96, 98, & 99 RFO inspection data. The 2001 and 2002 inspection data has been loaded however wear rate analyses are not complete at this time. In 2001 components on the higher temperature end of the Condensate System were inspected to calibrate the CHECWORKS models. The inspection data indicate minimal *wear and should reinforce the assessment oflowwear in the Condensate System. Additional components selected for inspection in 2004 in Section LB above will bs used to calibrate the CHECWORKS model.

Prior to the 2002 there was limited Inspection data for the Heater Drain system. The current CHECVIIORKS modelS (Pass 1 and some Pass 2) indicate low wear rates. During2002 a number.of new inspections were performed to obtain base line data prior to operation under GE Noble Metals HWC. NO additional components on the Heater Drain system will be inspected in 2004.

LE:

Large Bore Components subjected to off nonnal flow conditions identified by turbine perfonnance monitoring system (Systems Engineering Group).

The Systems Engineering Productk~a Variance Reports for 2002 & Shooe startup from 2002 (RF023) do not identify-.

any leaking valves. No other leaking valves or steam traps have been Identified (to date) using the Turbine Performance Monitoring (TPM) system. No components will be scheduled for the 2004 RFO based on the TPM

.reports to date. H-owerv, if new data indficates leaking valves then, addttions to the outage scope may be'reqUired.

LF: Engineering Judgment /Other Nine ASME Seelion XI Class 1 Category B-J welds are to be inspected by the FAC program per Code Case N-560 in lieu of a Section Xt-volumetric wSkW inspection. The VY ISI Program Interval 4 schedule for inspection of these welds is as follows:

Refueling Outage Section X1 Descripton FAC Program Components ISI Program Weld Spring 2004.

FW19-F3B upstream pipe to tee "A" Feedwater on Sketch 010 (RF024)

FW19-F3C tee to reducer FD19TE01 Interval 4 FW19-F4 reducer to pipe FD19RD01 Period 1, FW21-F1 tee to pipe FD19SP04 Outage 1.

FD21SP01 Fall 2011 (RF029)

FWN18-3A upstream pipe to tee "B" Feedwater on Sketch 016 Interval 4 FW20-3A

-tee to reducer FD18TEO1 Period 3, FW20-F1 reducer to pipe FD20RD01

OutageS, FW20-F1 B horizontal pipe to pipe FD20SPO1 FW1 8-F4 tee to oioe' FD18SP04 1*

1 Page7ofl 1 NEC020191

VY Piping FAC Inspection Program PP 7028 - 2004 Refueling Outage inspectioon liccafion workshei-tsIe Me'th6dsand Reasins f6r Coii]notni.Seletio0 LF: Engineering Judgment I Other-continued All Extraction Steam piping is A335-PI 1, a 1-114 chrome material, except for a short calbon steel stub piece in line 12"-ES-1A at the connection to the 36"A cross arournilline. Internal visual inspe ton ofthis stub piece will be performed along with the 36' A cross around line. This extraction stream line (611 point extraction) has the highest quality sleam of all extraction lines which indicates. a relatively lower wear rala. Based on the 1996 inspection data for the catbon steel section, ES1ASP01 (inspection 96-07A) showing a small area of wall thickness less than 0.875 x nominal thickness, the expected changes in flow.regime due to power uprate, and that this is the only carbon steel section in the ES system, a repeat inspection to confirm actual wall thickness and also to obtain a baseline thickness prior to power uprate should be performed. Porfonn external UT Inspe-Ation of ESIASP01 in RF024.

Extraction Steam piping in the condenser has eXlernallagging which requires significant effort for removal when performing external yr inspections (plus there are significant staging costs). The piping is A335-P11. However an opportunity to perform an intemal visual inspecUon of all the Extration Steam lines inside the condenser during planed LP turbine work in the 2005 RFO may present itself.

LG; Piping identified from EMPAC Work Orders (malfunctioning equip., leaking valves, etc.)

Word searches 01 opan work orders on EMPAG ware performed for the following keywords: trap, leak, valve, replace, repair, erosion, corrosion, steam. FAG, wear, hole, drain, and inspect. No previously unidentified components or piping were identified as requiring monitoring during the Spring 2004 RFO.

/

Page 8 of 11 NEC020192

.V Y._tiping FAC_Inspection Program PP 7028__- 2004 Refueling Outage Inspection Location Worksheets I Methods.and Reasons for Component Selection Small Bore Pipin SASuspeptible piping locations (groups of components) contained in the Small Bore Piping data base which have not received an Initial inspection.

Locations on the continuous FDW heater vents to the condenser On lhe No.3 heaters were inspected in 2002. The continuous vents on the No.4 heaterwere installed new in 1995. The start up vents operate less than 2% of operating time. No wvear was found In previouS inspectons on Heater Vent piping from the No.1 & 2 heaters. Given*

that and the lower prmssure in the No.4. shells a complete inspection of the remainder of the NO.4 heater vant piping can be deferred. The existing small bore date-base and the piping susceptibility analysis is under revision.. No addtkr~nal components from Revision 1 of the data base will be Inspected.

SB:Components selecfed from measured or apparent wear found in previous Inspection results.

Small Bore Point No. 20. 2-112" MSD-6 (@ connection to condenser A at Nozle. 33 (Inspection No. 9-SBO I identified a low reading at weld on stUb to condenser). Upstream valves are normally closed. TPM systeril does not indicate any abnormaiflow. No inspections will be performed on this line in 2004.

A through wall leak in the turbine bypass valve che.st I sealf leak-off line form the No. 1 bypass vales occurred in 2003. (ER 2003-W44) A temporary leak enclosure has been installed (T.M.2003-002 to contain the leak). W.O. 03.-

0364 was written fo inspectlrepairireplaceiline. The line should be completely replaced with chrome-moly piping.

(Dresden has already done this) Given the amount ofwork already scheduled forthe heater bay during the 2004 RFO a complete replaoement will be deferred. A local code repa'if of the piping vill performed to remove'the Mod during the 2004 RFO. Additional inspections should be performed to insure the integrity of the line. The-long tern solution (if license renewal is pursued) Should include replacement the entire line With chrome-moly material.

.I1 S

tern Deseri tion Ins eion No.

2' 1SLBPV

.. 2 inch header off the turbine bypass valve.d est first seal leak-of" connections.

2004 5801 to Inspect five locations on !his line.- include the % line at the No.2 valve. It has the 5805

_next hi hest usa e from the no.I valve, 2-112" ISPL2 HP Turbine pocket drains. inspffct first two elbows and connecting piping under 20045B06 &

turbine based-on readinll fromT 19931inspections 93-5849 to 93-SB52]1 5807

.1 Page90fl I NEC020193

VY Piping FAC Inspection Program PP 7028 - 2004 Refueling Outage Inspection Location Worksheets.'.Methods and Reasons for Component-Selection Small Bore Piping se: Components identified by industry eventslexperlence via the Nuclear Network or through the EPRI CHUG.

Date Plant - T Descri tion & Recommended Actions at vY 1123198

-Cavert Cliffs 2 Rupture of a moisture separator re-heatief (MSR) 2 inch vent line (INPO Event

-PWR 318-9801233--il No MSRs at VY, therefore no ea'uivalent line at VY, 11103198 Hamoka 2 Leak clue to FAC in turbine driven feed pump casing drain line No turbine driven

'WR feed oumr at VY, therefore no eouivalent line at VY.

4/29/99 Darlington 1 -

Severed line at steam trap discharge pipe at threaded connection. Equivalent to PHWR HHS system at VY. (INPO Event 931-990429-1) Threaded connections typically on condensats side of HHS piping. Lower energl'cohsequence of leek.

ConSider durin next ur, date of the Small bore data base.

5101199 Darlington 4-Leak On HP Feedwater Heater Vent Line downstream of orifice (INPO0Lvent PHWR 934-990507-1%. At VY ins ctions have rformed OS of orifices on HV lines.

6114/99 Darlington 2 -

Leak on steam trap discharge pipe at threaded connection. Equivalent to HHS PHWR svstem at VY. INPO Event 932-990614-11) Same as above.

10101/99 Darlington 2 -

Leak on Feedwater Hea.erVen.t Line downstream of orifice (INPO Event 932-PHWR 991007:1\\: At Y" inspections-have nerformed OS of orifices on HV lines.

10/1100 Ocone3_PWR From 1/2001 CHUG Meeting. MSR Scavenging steam line Pinhole lea1k In I' i e downstream offlow control valve. No enulvalent s stem VY.

18,/01 Oyster Creek -

RUpture of 2 inch line connecting controller/transmitter level column to re-heater

'WR..

drain tank. No MSRs at VYW therefore no uivalent Hne at VY.

9/1101 Peach Boltom (From 1/14102 CHUG*Meeting), leak on 1 Inch Soh. 80 line from in'Off Gas Re-3 -BWR combiner pre-heater drain line to condenser. Additional review ofAOG steam supply system is required. Consider during next update of the Small bore database.

6/22/01 Pilgrim -BWR Leak Of 2 inch feedwater heater venlline (OE discussed at 1/02 CHUG Meelinni. Eauivalent lines at VY h been insoncted.

10122101 st, Lucie I -

(From. 1/14102 CHUG Meeting), Leak on 1 inch Sch. eO normally Isolated drain PWR line remote from process system. TPM used to determine leaks from N.C.

11/28/01 Browns Ferry 3 Through - wall leaks in drain lines from extraction stream non-return check

-BWR valves back to condenser. (Simiiar lines at VY are chrome-moly and there have been previous inspections performed on these lines. No additional inspections are uired.

11151/02 Halchl/2 -BWR Conblenser in leakage due to through wall erosion (exlernal?) of 1-112.inch CHUG Mig.

"slop' drains lines inside the condenser. Lines In each unit were cut and capped Similar events at Byron Unl1 (OE 12609) and Columbia (OE12145). Limerick &

Dresden. VY slop drain lines do not show u on VY P&IOs.

1/15102 Catawba 2-Leak in HP turbine pocket shell drain 1 inch dia. OEM showed pipe as P-11.

CHUG Mtg.

PWR However, A-1 06 Gr. B was installed. Inspections will be performed on this line in 2004 10 base line conditIon crior to HP turbine rotor replacement.

1115/02 Columbia -

Leak in 2 inch drain line from bleed steam trap to condenser. At VY SB piping CHUG Mt

'WR OS of steam trans Is included in the small bore dala base.

1/15/02 Peach Bottom2 Pin Hole leaks in 1" schedUle 160 HPCI Steam Supply drains (Plant thought CHUG Mtg."

. BWR piping was replaced with P-1 1 i However field conditions showed that is was not Pi in at VY ins cted in 1999 g99-SBS1I to 99-SBO31 continued.

PagelOofl 1 NEC020194

4-T Piping FAC Inspection Program PP 7028 - 2004 Refueling Outage

.Inspection Location Worksheets 1 Methods and Reasons for Component Selection Small Bore Piping SC: Components identified by in dustry events/experience via the Nuclear Network or through the EPRI CHUG - continued.

Date Plant T e Descri tion & Recommended Actions at VY 1115102 Dresden 2 Thinning found in Bypass vafve leak-off line to the 7 stage extraction steam CHUG Mtg.

'WR line. Line is 2" Sch. 80, GE.B4A39B. Lowest reading was 0,070- foundusing Phosphor Plate radiography. Line was replaced with A335 P-11. Same line as recent VY through wall leak, RFO 2M41nspect locally, then long tenn renfaement with A335-PI 1.

6102 CHUG AN01 &ANO 2 Leaks in Gland seal steam to No:3 bearing 1-114 vendor supplied line, Leak in Mtg.

PWR 1" SCh;SO drain from Reheat 2 "n stage drain tank to condenser. Addillonal review of GE supplied steam sed & drains is required. Consider during next u date of the Small bore data base.

6102 CHUG Brunswick 1 -

Replaced continuous vent lines on #4 feedwater heaters with chrome-mOly pipe-Mtg.

'WR (Smart move for long term.) New vent lines on No.1 & 2 FDW healers atVYwill be chrome-molv, 6102 CHUG Calvert Cliffs 1 Pin hole leakin '/ inch Sch. 80 drain line off MS supply to stream generator feed Mta.

PWR ouma iustdownstream of orifice. No steam driven feed ournis at -Y.

6102 CHUG Fenni 2 - BWR Leak in first elbow downstream ofAOV in 1/112" continuous vent from Turbine M tg Bypass Valve seat dra',n to condenser. Vawe has travel stop which prevents complete closure. Fermi has no steam traps, AOVs are used instead. Piping DS of steam traps on MSD lines are inclUded in the SB program, Thaonly continuous opening to the condenser at VY is the steam leads drains through RO 60-1. This -oi inc has been reolaced with chrome-rnolv ai inc.

1/03CHUG JAF -BWR Through wall leaks in 2" Soh. SO C.S. lines from 5 /6 extracticn drain lines Meeting.

immediately downstream of restricting orifices. At VY the only drain lines on the action steam piping are upstream of the reverse cUJTenf valves. There are no restriction orifices-at VY. The Tfiina Is chrome-molv.

1/03 CHUG TUrkey PtA-Leak in HP turbine bowl drain, I" sch 60 C.S. pipe. OEM recommended Meeling.

PWR replacement with SS pipe in 19S2, did not occur. Equivalent line al VYwIlI be inspected In 2004 to baseline thickness prior to HP turbine rotor repiacement.

SD:Components subjected to off nonnal flow conditions, as indicated from the turbine performance monitoring system (Systems Engineering Group).

No small bore lines have been identift~d by Systems Engineering on or before 2/27/2003 SE: Engineering judgment (None at this time,)

I j

11 ISG:

Piping identified from EMPAC Work Orders (malfunctioning equip., leaking valves, etc.)

See LG above. The EMPAC search performed in LG above is applicable to both Large and Small components.

Page 11 ofIl NEC0201 95 01 I

7 January 2003 CHUG Mceting Minutcos Page 6 a The meetisg then split into breakout seswiOns. Aaron Kelley led a sekai on BWR isgues. The following discussions were noted:

EAC Croblern Area.,.

Hatch has had lots ofwear and repairs to their g8 siage exfracmtion. (ird highest), 61e.-n though C I-,

the heatbalance diigrfam shows it to be 99% ste-am..

" t4 LaSalle is wondering ifthere may be problems in their carhon steel turbine nozzles to extraction steam. Riverbend has, had to in%,-ect these locations from'the turbine side because ofthe shields.

V-'A/.

Q.ad Cities has*had lots ofproblcms in their expnsion bellows.

Rivyfbend-replaced the exfiac.lion steam check va'ves,ising chrome moly. Unfortunately, * *,J9 the inrnols were earboia steel and they had problems after only two cycles'-

41'1 L4.

? -

La,;ailF. had *i failuwv oaused by.droplet irmpingemen. in a* heater Ynilin. IT downstrrni of the,Vahe..

PQ;O 4g*tv-LaSalle is experiencing i,_pingelmenl. dttrage.in an 8" common drain header to cdndens er l

st(

that oolle.ts six.10 eight 2" and smaller diamet.r lines. Stainless will help, but they still will need lo.in *pe4..

Hope Creek has seen a lot ofdanmage in the drain to condenser of the steam to reactor feed I"' "/A)

pump turbines.

waterh Riverbend experinced significant ineeaIes to iron lranspoi. after applying hydrogc.n 0 "M-, 1 injedlion (medium level of injection). GE did a mii-te.st.

A,,

Nine. Mile Point had unexpected failures on the lower end of the healer drains after applyiug.

HWe.

7 LaSalle measured oxygen on the-heate.r draini, and then use.d the. data to revise the.

CHEC WORKS model. The data caused to LCFs on th.e. MSR drains, 0"t stage reheate..rs, and 2" stage re.heate.rs to.skyrockket Columnbia River has teniAtively concluded thal noble metals does not effec.t the fuel. It is too.

sootn to see ifhydrogen water che.mishry alfects the FAC rates.

RfY BoUom H*ad Drain, La~alfe has not inspeeled the first elbowhelowthe "egsd bhec.ause. ofits intircesability and high radiation dose iovolved. For lh, re-ason, they selected the secknd 90" elbow which ir outside the vessel peeslal. Results were provided on FACNet. Additiorially, the sump will maintain water level ifthere is a brek at the first, elbow.

It wal noled that it may be possible 10 inspect the nominally inaccessible areas when there is a 10% d(iHs1eSnbMy to replace wome. blades.

LaSalle and Clinton plan 10 inspect the ace.s!ible poirion,. ofth.c line.

Co)lumbia River has inrl)eoted se.veral locations on the line. No wear Was found. Three iDEgpeelion" were aLso performed on the RWCU near the dr.well. No damage was found.

Exelon (Harold Croe*ket) volunteered to collate'and publish a sumtmary ofindusiry inspections on the line.

(T NEC020196

Janwuy 2003 CHUG Meeting Minutes....

Page 7 Lnsoeetlon Metd LaSalle ip performing Rome pre-outage RTs in i.elective. area, due to fimal feedw.ter fempe-rature reduction. This is the socond time that some pre-outage Work was done in nonnally high radiation areas. ALrot Kelly can be contacted for more information.

Rive.rbernd is training their QC iwpecto.r to perform VT..

Poxw Upratn.

Nine Mile Point sav little chanoge to wear ra.tej after a 7% uprate.

Dremden and Quad,ifie.. did a 15% upiale. Some line§ 8aw inc.r"erses to wear rates 0fup to 30%. Te.m. rature chan " are believed to be resof"si Perry did a-pJr-power uprate an y918 on the effecf to FAC. They used the remuIli tojustify line replaeements as part of (he plarining process.

LuSalle found no changeos to theirsi eeptible-.uo-uodeled raukins as a requh1 oftheir Life Bxtert sion.

General comment was that theNRe has emphasizod compliance with NSAG202L-RI and brought up. mafinam s,~~

se M

y as part of their approval process.

At Nine Mile Point, the NRC brought up 8e.rvic-. water i*f'ues.

Southern Nuclear is taking credit for other programn inresponse to the NRC quesfious on valves'.

I witl tIe MR session, lettITorowitz led tWe " w K 1

1eak(t-*8es5iOn1.

was bioken down into three parts" A descrip

-very high lc.vels o firon transport experience an Onofte.. ThUS presentation inelude ils ofthe investigation into the ph

<mon, a description of the deposits-found, several p ibMe explanations for sits, and what the effects of the deposit were on plant p A status report on the EdF hydrazine. t6i Unfiortunatelv..no vrofess has heen made since. the last report in J to n bet ofproblmns. The latest problem,

,!inadequate Water quality, hag ie.olvcd and tes restmied ealier this month. The testing program is take. all year to complete.

etaiIs oflbe teet-program have beenpresented at ous CHUG meelings.

There was al riefdisclus-ion offe dwater oxygen and FA.

"verl PWRs are now aUowin entry ofsmall amciinh. ofoxygen into the condensate.sh inliopvs of red g the iron tratsport. The potenlial for change to the PWR Water stiy

..j/de.1ine.* in this Owea vwaa disc~ussed..

  • Tina Gaudreaau ýiscusged everal EPRI ohem"ifry project that have FAC implications. The was the EdF testing {orthe effects ofhydrazine and oxygen oti FAC as swumrarized by Jeff H-orowitz in.the PWR breakout session. The second project wvap the next revision. to the PWR Secondatry CheMistry Guidelines, that will begin this spring. The third pioject is an investigation into the influence ofdissolved iron, olemtrodhemistry, and chemical param.eters on I

~NEC020197

-* Entergy VermontYankee Nuclear Power Station oesign Engineering Department" Mechanical/Structural To S.DGoodwin Dale March 27.2003 From Jle. Eitzpatdck File #

VYM 20Q3/L0Q9 Subject Piphig EA.C Inspection Sco forte 2D0_4 Refueling _u.ttao REFERENCES (a) PP 7028 Piping Flow Accelerated Corrosion Inspection Program, LPG 1 12/06/01.

(b) V.Y. Piping FRA.C, Inspection Program - 1996 Refueling Outage Inspection Report, March 23,1999; (o) V.Y. Piping FAC.Inspectlon Program -1998 Refueling Outage Inspection Report, April 2,1999.

(d) V.Y. Piping FAG. Inspection Program. 1999 Relueling Outage Inspection Report, February 11,2000.

(e) V.Y. Piping FAG, Inspection Program - 2001 Refueling Outage IrlSpection Report, August 11,2001.

(I) V.Y. Piping FAC.Inspection Program-2002 Refueling Outage Inspection RepWrt, January20,2003.

DISCUSSION Attached please find the Piping FAC Inspection Scope for the 2004 Refueling Outage. The scope Includes locations identified using: previous inspection results,, the CHECWORKS models, Industry and plant operating experience, Input from the Tu"rbine Performance Monitoring System, the CHECWORKS study performed to postulate affects of Hydrogen Water Chemistry operation on FAC wear rates in plant piping, postulated power uprate effects', and engineering judgment.

(

The planned 2004 RFO Inspection scope consists, of 26 large bore components at 11 locations, internal Inspection of.6 of the BlInes of the turbine cross around piping,.and II sections of small bore piping. Given that it's a ull year from the start of the outage, any Industry or plant events that occur In' the interim or new infonnation may necessitate an Increase in the planned scope.

I am available to support planning and inspections as necessary. If you have any questions or need additional Information please conlsct me.

Fitzpatrick VY FAC Program Coordinator ATTACHMENT: 2004 RFO FAC Inspection Scope (4 Pgs.)

- cc D.Girroir (Code Programs Supavklsor)

D,King (ISI Progmm Engineer)

T.MO'Connor (Design Erngfneering)

M.LeFrancois (Systems Engineering)

NEC020198

ATTACHMENT to VYM 20031009 VERMONT YANKEE PIPING FAC INSPECTION PROGRAM 20041 NSPECIION SCOPE.(3127/03)

Page 1 of 4 LARGE BORE PIPING: External UT Inspections I

I I

r

'4 t~1 C) 0 I'-,

0 Point No.

2004-01 2004-02 2004-03 2004-04 2004-05 2004-06 2004-07 2004-08 2004-09 2004-10 2004-11 2004-12 2004-13 2004-14 2004-15 2004-16 2004-17 Component 10 FDOIRDOl FOOl EL01 FDQ1TEOS FDO0EL04 FDOISP04 FD02RDO1 FD02EL01 FD02TEOI FD03SP01 FD07SP02DS "FD07EL03 FD14SP08DS FD14EL07 FD19TE01 FD19RD01 FD19SP04 FD21SPOI Location Sketch 001 001 001 001 001 002 002 002 003 005 005 009 009 010 010 010 010 Location Inspections T.B. FPR. Elav. 232.

T.B. FPR Elev.241.

Il l

T.B. FPR. Elev. 232.

II II T,B, FPR. Elev.- 232.

T.B. FPR. Ei v. 232.

ii TI IT Stm Tunnel Elev. 266 Rx Drywei Elev. 270 (6

11 II II.

I t

2001 2001 2001 1996 199.6 1999 1999 1999 NO NO NO NO NO 1999 1999 1999 1999 Previous Reason Comments Notes 2001 recommendation for repeat inspection of FD01TE05.

1996 recommendation for repeat inspection of FDQ1 SP04.

1999 recommendation for. repeat inspection of

FDOZTE01, Ranked hi h b CHECWORKS.

Ranked high by CHECWORKS include minimum of 3W Inch of vertical run upstream of elbow.

Ranked high by CHECWORKS include minimum of 32 inch of vertical run upstream of elbow.

Required Inspections perASME Section XI ISI Program FAC inspections perASME Code Case N-560.

ATTACHMENT to VYM 20031009 VERMONT YANKEE PIPING FAC INSPECTION PROGRAM 2004 INSPECTION SCOPE (3127103)

Page 2014 LARGE BORE PIPING: External UT Inspections - continued Point Component 10 Location Location Previous Reason I Comments I Notes No.

Sketch Inspections 2004-18 CD30TE02 036 T.B. FPR EI v.243.

NO Ranked high by CHECWORKS include 12 inch.

0004319 CD30SP041-_

036 NO lonq stub between CD32LEol & CD32EL02.

zu4-zu 039 NU 2004-21 CD32EL02 039 NO 2004-22 ES1ASP01 063 T.B. HB Elev. 255.

T 998 Highlysu$oeptibleto FAC dama*e. This isthe only remainIng carbon sleel section in Extraction Steam av*vem. Baseline data for ower urate.

2004-23 MSD9TE01 097 T.B. HB Elev. 249.

NO Industry Experience with numerous through WaJileaks in th ru drain Golleotor headers. Scan as much of header below drains from LeV38A to 380 and ST,6D-2A to 20 as MSD9TE08 accessible. See Nole 3.

2004-24 MSD9EL05 097 T.B. HB Erev. 237.

NO Industry Experience with numerous through wall leaks in 4

M 097.~

NO drain. 00leCtor headers. inspect a' minimum of 16 inch l*rl0 0

r'-)oo

/-UU4-Zbj MSD9SPUbUS U9/

$1 A

of NO LARGE BORE UT NOTES;

1. Coordinate minimum extent 01 insulation to be removed with J.Fitzpatrlck or T.M. cyConnorfrom DE.MIS.
2.

A 'Nio in the previous inspection column Indicates asbestos abatement may be required.

3, Piping is part of the proposecf ALT Boundary/or Power Uprate AST.

ATTAýHM.ENTOVYM20031 009 VERMONT YANKEE PIPING FAC INSPECTION PROGRAM 2004 INSPECTION SCOPE (3/27/03)

Page 3 014 LARGE BORE PIPING: Internal. Visual Inspections (with supplementsl UT as required)

Ins action Point No.

Oeser! lion 2004-27

'A" 36 inch diameter Turbine Cross Around line (CAR).

2004-28 "6" 36 inch diameter Turbine Cross Around line (CAR).

2004-29

'V 36 inch diameter Turbine:Cross Around-ike (CAR).

2004-30 "D" 36 inch diameter Turbine Cross Around line (CAR).

2004-31 "C" 30 inch diameter Turbine Cross Around line (CAR).

2004-32 "0" 30 inch diameter Turbine Cross Around line (CAR).

0 Note: Internal visual inspections of open ends at all large bore connections to the new High Pressure feedwater healers will be performed during installation of the new heaters during the 2004 RFO. (This includes Feedwatar, EXtraction Steam, Moisture Separator Drains, and Heater Drain piping.)

'It_

L t-.

~yO4-q2~

Jj

$ou 42&~I z

m REVISION 1.11124/91 VERMONT YANRLL I-lI l'(U~!-

CORROSION INSPECTION PROGRAM FELDWATER L04

.16" FDW-l TURBINE BUILDING-FEEDWATER PUMP ROOM.

REFERENCES. G191157,GI91 i82,GI91183,5g2O-PS-124

.4 COMPONENT LOCATION SKETCH No.00I

-~

4 Appondix A PP 7028 Original Page. 6 of 102

VS=At.

Scc>4 -" 0,

,Z064-o07 totA-.a pom0c

,&ksp' C14 ý I

dý z

REVISION it 11/24/91 VERMONT YANKEE PIPING EROSION CORROSION INSPECTION PROGRAM FEEDWATER LINE 16' FDW-l2 TBTtINe aUIIDINC-FEEOWATER PUMP ROOM.

REFERENCES& Gt9t t57,G 19! t82,G]91 ?8,5920F'1r124 COMPONENT LOCATION SKETCK No.002 Appemdix A PP 7028 Original Pare 1.6oi-2

z C)

NO N)

CORROSION INSPECTION PROGRAM AppendixA PP 102&Origirnl Paj

$...f 102

(C1 I'

,A>1 46 ot<l C)

REVISION 1 111/24/91 VERMONT YANKEE PIPING EROSION-CORROSION INSPECTION PROGRAM FEEOWAT6ER L(NW 18' FDW7' TURB1NS BLDG FEED PUMP ROOM/1*ATER BAY.

R£EFERBENCES G191157.G I 9t 182,I1982,5920-FS-124 COMPONENT LOCATION SKETcH NoOS5 Appedi.x A PP 7028 Original

?lap 10 of 102

REACTOR BUILWNO-STEAM TLRNNEL/ORYWELL REFERENCES G191 167,G191 IBO,GigIleI VY(-FDW-PARf 5AVYI-fDW-PART 5C, z

C)

REVISION ý: 11124/91 I VERMONT YANKEE PIPING EROSION-

~OD4 -~~Ž

~4sL CORROSION INSPECTION PRCGRAM PEEWATER UNES 16' FDW-14 & 16

.1 COMPOQENT LOCATION SKETCH No.Q09 Appendix A. PP 7028 Original

  • Fag 14 of 102

I

.FD*)LD5 F09CkO4 zT ii L

T 40 Duct 1 Do"4 FD11 REACTOR BULDING-OR~YV.LL REFýýRENC~Sx G1'g t67Gtc~t I8O,91 181,VYI-FDW-PARZT 5A 01FDW-19 FOI9SPOS REVISION It I t/24191 VERMONT YANKEE PIPIN(,-I=

CORROSION INsPECTION PRQGRABI C.FEENWATE LNES IoON-FDW-T &

N2 COMPONENT IoeATION SKETCH NcVOI FLO OW~UE Appendidx A PP 7028 OxigineJ Pgag 15't)1,102

I I i~o-,

/

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NEC020218

PP 7028 VY PIPING FLOW ACCELERATED CORROSION (FAC) INSPECTION PROGRAM RFO 24., SPRING 2004 PLANNED SCOPE External Ultrasonic Thickness (UT) Inspection of 26 large bore components at 11 locations. Includes some new locations, some repeat inspections for trending, and for a baseline prior to power uprate.

External Ultrasonic Thickness (UT) Inspection of 11 sections of small bore piping. Includes 5 sections on the turbine bypass valve 1 sealleakoff line if the line is not replaced during the outage.

0 Internal Visual Inspection of 6 of the 8 Turbine Cross Around Lines (36A to 360, 30C, & 300).

WO 02-4906 FAG Inspections -restraint removed with VYM 2003/009 BASIS I COMMENTS Component selection based on previous inspection results, the CHECWORKS models, industry and plant operating experience, the FAC HWC study, postulated power uprate effects, and engineering judgment.

  • Similar numbers of components to be inspected as in previous outages,. VY inspects less than the industry average due to a simpler design (no reheat) and Chrome-Moly Extraction Steam piping.

For Large Bore Piping: The combination of previous inspections and the proposed 2004 inspections should provide a solid basis for a high degree of confidence against unexpected piping wall loss. We will have sufficient base line data to evaluate any negative trends from Power Uprate and HWC.

  • Recent Small Bore leaks at VY and numerous ones at other plants require an increased and more intelligent focus on small bore piping.

Given that it's a full year from the start of the outage, any industry or. plant events that occur in the interim or new information may necessitate an increase in the planned scope.

NEC020219

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