ML20196A182
| ML20196A182 | |
| Person / Time | |
|---|---|
| Site: | Calvert Cliffs  |
| Issue date: | 11/13/1998 |
| From: | Dave Solorio NRC (Affiliation Not Assigned) |
| To: | NRC (Affiliation Not Assigned) |
| References | |
| TAC-MA2156, NUDOCS 9811270075 | |
| Download: ML20196A182 (144) | |
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November 13, 1998 LICENSEE: Baltimore Gas and Electric Company FACILITY: Calvert Cliffs Nuclear Power Plant, Unit Nos.1 and 2
SUBJECT:
SUMMARY
OF JUNE 24,1998, MEETING WITH BALTIMORE GAS AND ELECTRIC COMPANY (BGE) REGARDING LICENSE RENEWAL ACTIVITIES FOR CALVERT CLIFFS NUCLEAR POWER PLANT, UNIT NOS.1 AND 2 (TAC NO. MA2156)
On June 24,1998, the Nuclear Regulatory Commission (NRC) staff held a public meeting with representatives of Baltimore Gas and Electric Company (BGE) at Rockville, MD, to discuss BGE's Integrated Plant Assessment Process for License Renewal. A list of meeting attendees is provided in Enclosure 1 and slides used by BGE for the discussion are pruvided in Enclosure 2.
During the meeting BGE summarized how its integrated plant assessme,i nrocess (IPA), which was broken down into the three major activities of system level scoping, component level scoping and pre-evaluation, and aging management review, was used to buit its license renewal application. BGE then used its feedwater system evaluation and fa9gue monitoring program as examples to illustrate how its IPA processes were implemented. BGE concluded its presentation with an overview of how its fatigue monitoring program elements compared to the NRC's Draft Standard Review Plan for License Renewal program elements related to aging management programs.
bSlgned By David L. Solorio, Project Manager License Renewal Project Directorate Division of Reactor Program Management Office of Nuclear Reactor Regulation Docket Nos. 50-317 and 50-318
Enclosures:
- 1. List of Attendees i
- 2. BGE's Presentation Slides cc w/encls: See next page l DISTRIBUTION: See next page j
DOCUMENT NAME:G.\ WORKING \SOLORIOUUNE_24.MTG OFFICE PDLR/DRPM LA: PDI-h PDLR/DRPM:D NAME Sliple[ Dsolorio d CGrimes fy :
DATE %/j/98 1$/85/98 10/3/9F '
OFFICIAL RECORD COPY [)f b/
9811270075 981113 PDR ADOCK 05000317' P PDR
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i DISTRIBUTION:
HARD COPY (w/nclosures 1&2) ;
(Doolet Files -
PUBLIC PDLR R/F l OGC l MEl-Zeftawy DISTRIBUTION: E-MAIL:(w/endosure 1 only)
FMiraglia (FJM)
JRoe (JWR)
DMatthews (DBM)
CGrimes (ClG)
TEssig (THE)
GLainas (GCL)
JStrosnider (JRS2)
GHolahan (GMH)
SNewberry (SFN) 4 GBagchi(GXB1)
RRothman (RLR)
JBrammer (HLB)
CGratton (CXG1)
JMoore (JEM)
MZobier/RWeisman (MLZ/RMW)
SBajwa/ADromerick (SSB1/AXD) i LDoerflein (LTD)
BBores (RJB)
SDroggitis (SCD)
RArchitzel (REA)
CCraig (CMC 1)
LSpessard (RLS)
RCorreia (RPC)
RLatta (RML1)
EHackett (EMH1)
AMurphy (AJM1)
TMartin (TOM 2)
DMartin (DAM 3)
GMeyer (GWM)
WMcDowell(WDM)
SStewart (JSS1)
THiltz (TGH)
SDroggitis (SCD)
DSolorio (DLS2) l PDLR Staff
ee Baltimore Gas & Electr' Company Calvert Cliffs Nuclear Power Plant cc: Unit Nos.1 and 2 President Mr. Joseph H. Walter, Chief Engineer Calvert County Board of Public Service Commission of Commissioners Maryland 175 Main Street Engineering Division Prince Frederick, MD 20678 6 St. Paul Centre Baltimore, MD 21202-6806 James P. Bennett, Esquire Counsel Kristen A. Burger, Esquire Baltimore Gas and Electric Company Maryland People's Counsel P.O. Box 1475 6 St. Paul Centre Baltimore, MD 21203 Suite 2102 Baltimore, MD 21202-1631 Jay E. Silberg, Esquire Shaw, Pittman, Potts, and Trowbridge Patricia T. Birnie, Esquire 2300 N Street, NW Co-Director Washington, DC 20037 Maryland Safe Energy Coalition P.O. Box 33111 Mr. Bruce S. Montgomery, Director Baltimore, MD 21218 NRM Calvert Cliffs Nuclear Power Plant Mr. Loren F. Donatell 1650 Calvert Cliffs Parkway NRC Technical Training Center Lusby, MD 20657-4702 5700 Brainerd Road Chattanooga, TN 37411-4017 Resident inspector U.S. Nuclear Regulatory Commission David Lewis P.O. Box 287 Shaw, Pittman, Potts, and Trowbridge St. Leonard, MD 20685 2300 N Street, NW Washington, DC 20037 Mr. Richard I. McLean
, Nuclear Programs Douglas J. Walters Power Plant Research Program Nuclear Energy Institute Maryland Dept. of Natural Resources 1776 l Street, N.W.
Tawes State Office Building, B3 Suite 400 Annapolis, MD 21401 Washington, DC 20006-3708 DJW@NEl.ORG Regional Administrator, Region i U.S. Nuclear Regulatory Commission Barth W. Doroshuk 475 Allendale Road Baltimore Gas and Electric Company King of Prussia, PA 19406 Calvert Cliffs Nuclear Power Plant 1650 Calvert Cliffs Parkway Mr. Charles H. Cruse, Vice President NEF ist Floor Nuclear Energy Division Lusby, Maryland 20657 Baltimore Gas and Electric Company 1650 Calvert Cliffs Parkway National Whistleblower Center Lusby, MD 20657-47027 3233 P Street, N.W.
Washington, DC 20007 l
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- p ATTENDANCE LIST l NRC MEETING WITH BALTIMORE GAS AND ELECTRIC COMPANY June 24.1998 !
l l 1. DAVID SOLORIO .NRC/NRR/PDLR l 2. BOB PRATO NRC/NRR/PDLR L 3.. CARL YODER BGE
- l. 4. C.A. NEGIN - EPRI
- 5. JOHN CARBY EPRI
- 6. MICHAEL HENIG VIRGINIA POWER
- 7. - JANAK RAVAL NRC/NRR/SPLB
- 8. LYNN CONNOR DOC-SEARCH ASSOCIATES
- 9. PETER PENN BGE i 10. MARVIN BOWMAN BGE-
- 11. MICHAEL SNODDERLY NRC/NRRISCSB
- 12. TONY GRENCI BGE
- 13. ERNEST TAORMINA BGE
- 14. HERBERT BRAMMER NRC/NRR/ECGB i 15. SYED ALI NRC/NRR/ECGB
- 16. PAUL MANBECK BGE L 17. SHOU-NIEN HOU NRC/NRR/ECGB ,
L 18. EMMETT MURPHY NRC/NRR/EMCB i
- 19. JAlRAYAN NRC/NRR/EMEB
- 20. DEBORAH STAUDINGER WINSTON & STRAWN L 21. - SAM LEE NRC/NRR/PDLR
- 22. TED SULLIVAN NRC/NRR/EMCB
- 23. TED MARSH NRC/NRR/SPLB
- 24. PRAKASH PATNAIK NRC/NRR/ECGB
- 25. CHARLES BRINKMAN ABB-CE
- 26. DALE THATCHER NRC/NRR/EELB
- 27. CHRISTOPHER LUDLOW BGE
- 28. TODD CONNER BGE
- 29. JIM BENNETT BGE
- 30. STEPHANIE COFFIN NRC/NRR/EMCB
- 31. GEORGE GEORGIEV NRC/NRR/ECGB
- 32. DAVID TERAO NRC/NRR/EMEB
- 33. DOUG WALTERS NEl
.34. DON SHAW BGE
- 35. CHUCK GEPFORD NUS
- 36. PAUL SHEMANSKl NRC/NRR/EELB
- 37. RAJ ANAND NRC/NRR/PDLR
- 38. KRIS PARCZEWSKI NRC/NRR/EMCB
- 39. DICK WESSMAN NRC/NRR/EMEB l: 40. KAMAL MANOLY NRC/NRR/EMEB 1
Enclosure 1 f
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- 41. .KEITH WICHMAN NRC/NRRIEMCB
- 42. ALEXANDER DROMERICK NRC/NRR/PDI-1
- 43. JOHN FAIR NRC/NRR/EMEB
- 44. YUEH-LI C. Li NRC/NRRIEMEB
- 45. CHANG-YANG Li NRC/NRR/SPLB
- 46. MUHAMMAD RAZZAQUE NRC/NRR/SRXB '
- 47. ROBERT WEISMAN NRC/OGC I
- 48. ROBERT ROTHMAN NRC/NRR/ECGB
- 49. CLIFF MUNSON NRC/NRR/ECGB
- 50. FRANCIS GRUBELICH NRC/NRR/EMEB i
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[g tire cycie management Project ,
i
" Vertical Slice" Example of the BGE Integrated Plant Assessment Process for License Renewal June 24,1998 '
\
(
slide i Enclosure 2
.l
/
( Life Cycle Management Project h
Purpose To provide NRC staff with an overview of BGE's entire Integrated Plant Assessment (IPA) process '
To provide an overview of how the License Renewal Application (LRA) was built 1
l q Slide 2 ,98-037 f
Life Cycle Management Project Topics for NRC Briefing by BGE What is BGE's Aging Management Review (AMR)?
What is it's purpose?
System level scoping - Provide NRC with .
procedure /results overview of how BGE selected systems and structures within the scope oflicense renewal.
Component level. scoping and pre-evaluation Provide .
NRC with procedure /results overview of component scoping and active / passive determination Slide 3 98-037
M Life Cycle Management Project Topics (continued)
~
Aging : Management Review - review goals, procedure for the aging management process for piping examples.
]
LRA Section 5.9, Feedwater System - provide overview of the layout of an LRA section and how Feedwater i results are reflected.
Fatigue Monitoring Program - discuss fatigue program to effectively " demonstrate" an adequate depth of engineering.
Review of overall approach.
Staff comments, need for additional information.
Slide 4 98-037
t M t Life Cycle Management Project Acronyms :
A MR- Aging Management Review ARD M- Age related degradation mechanism CLSR- Component Level Scoping Results IPA-Integrated Plant Assessment LRA- License Renewal Application SLSR- System Level Scoping Results Slide 5 j 9R-037
f i
Life Cycle Management Project Introduction 1990 - NRC established the License Renewal (LR) and Environmental Projects Branch 1990 - NRC issued proposed LR rule for comment 1990 - BGE formally initiated IPA process 1991 - 10 CFR Part 54 was published 1991 - BGE developed IPA methodology 1995 - Amended 10 CFR Part 54 was published 1996 - BGE revised IPA methodology 1996 - NRC SER on IPA methodology Slide 6 98-037
7 Life Cycle Management Project Introduction (continued) 1996 - BGE submitted a template for the format and .
content of technical reports 1996 - NRC concluded that proper application of the template should result in sufficient reports 1997 BGE submitted Section 5.9, FW System, of the BGE LRA -
j 1997 NRC formally begin a technical review of I Section 5.9, FW System 1998 - NRC issued RAIs on the FW System Slide 7 98-037
y O
' i Q-List UFSAR DWGs Plant Procedures, Tests, Inspections NRC Documents Generic Externa; Assessments EPRI Reports Standards Codes Textbooks '
Slide 8 98-037
((g tire cycie management Project Current Licensing Basis Aspects of the plant's CLB which are not related to plant aging are not addressed in the LRA.
All aspects of the plant's CLB will be carried forward into the period of extended operations in the same manner and to the same extent as during the current license term.
Slide 9
Life Cycle Management Project Operating Experience Operating experience (OE) is factored into the IPA process in various steps and will be identified in this presentation where appropriate OE is factored into the IPA process through all of the supporting documentation that incorporates such experience BGE has not repeated processes that are built into CCNPP operations (e.g., review of GLs) in the IPA Slide 10
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98-037
s' o
[g Life cycie management Project Operating Experience (continued) ,
For example, our Industry OE Assessment Unit:
Reviews the following OE information to assess the applicability and significance of the information
- NRC GLs, Info notices, bulletins, and admin letters
- INPO SOER, SER, SEN, SO, OR, and OE reports
- Other; 10CFR21 reports, vendor information, misc.
Recommends corrective actions when inadequate barriers are in place to prevent similar events at CCNPP Documents results and forwards to appropriate plant personnel including LR Project ,,,
i Life Cycle Management Project IPA Flow Diagram i CopI7tjf Pre-Evaluation Passive ,,,,
or SS within Active? V scope Intended aci;y, No functions Periodically Components replaced?
that contribute AM to intended anaged No functions Excluded No y xisting by rule?
activities? y ;
y,, Modify existing or ves add new programs t
V V V V V ,
SCs not subject Demonstration that the effects of Results to A M R aging are adequately managed ;
Slide 12 98-037 t
M Life Cycle Management Project Scoping BGE felt the most effective approach in scoping SSCs is the use of two levels of scoping, i.e.,
system level and component level.
This process segregates SSCs into logical, manageable pieces.
3 Slide 13 98-037
_ _ - - - _ - _ _ _ _ _ _ _ _ _ - _ - - - _ - - _ _ _ _ - - _ - _ _ _ _ _ _ _ _ - _ - _ - _ _ _ _ _ _ _ _ _ _ __ - _ - - _ _ _ _ _ _ _ - - _ _ _ _ _ - - - - - - _ - _ _ _ _ - _ _ - _ _ _ _ - _ _ _ _ _ - _ _ ~
Life Cycle Management Project 3
System Level Scoping Establishes boundaries for plant SSs Develops screening tools that capture the 10CFR54.4 scoping criteria Applies tools to identify SSs within the scope of LR
/
Slide 14 98-037
l '
Life Cycle l Management Project l
( All plant systems Systeni Levet i and structures 1
Scoping Process Define conce,tuo boundaries and
! functionalrewireinents l
i.
Develop screenmg 4 toots Rule 54 4 Rule 54 4 Rule 54 4 Criterion 1 Cntenon 2 Cnterion 3 DBE Vital FP.EQ.
Flow Chart Auxiliaries ATWS SBO.
Tool Tool PTS Tools ir u , ,
N* is sy; tem' No is system / No is system' is the buildmg a 3, m No Class I structure? / n - structure required , structure required structure required by the tool? by the tool' by the tool?
Yes Yes Yes Yes i' ir ir o Add Function to Add Fenetion to Add Function to Add Function to Intended Functions intended Functions - Intended Functions -
Intended Functions -e List List List List I l l 1
List ofintended functions _
for systems and structures Does the No 4, system or structure have an intended function' Yes l E No further action required for Systems and structures e within the scope of p mese systems and structures //
license renew al _
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Slide 15 98-03*/
t l
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Life Cycle Management Project EN-1-J01, Revision 1 BGE LCM Program TABLE 1 SYSTEMfSTRUCTUREINFORMATION Systemf Revision 5 Description structure Urdt ID Functson Summary Description Reference FunctionelRequirement(s) f eedwater 1&2 45 The e.=to txmster pumps dehver the e ie to the two L.4 e Refer-50 No. 32 1. To transfer feedwater from the steam generstor feed pump SD No. 32 driven steam generator feed pumps through two paraIIel sets d three Pgs 2. 5 seettion to the steam generators. Pos. 2,5 feedwper heaters. The steam generator feed pumps pump the feedwater trough two parallet hepressure heaters to the steam genefators The 2 To regdate me flow of feedwater to the steam generators to mainfeedwater system consists of LL . d. ..centnfugal steam maintain a constant water levet h the steam Generators generaer feed pumps (SGFP). transmum (trden) flow control valves, a pump seat UFSAR urs.yg water system. feadwaw regulatmg valves. feedwater regulanng valve bypass Section to 2 2 3 To provide a means of raising the temperature of the condensate Section to 2 2 valves. HP and LP feedwatiar heaters. and associated ppmg and ins:.w.m./.;.m. received tr' the feed pumps.
The mam fe=dwater system interfaces wth the fonowing systems / components 4 To provide a means for irieceng chemicals into the steam
. Condensate system generators from the chemical addtion system.
- Main steam system
- Chemical addelen system
- E'mergency safety features actuehon system
= Seal water t:ooster por p Extract % steam sstem
. Steam Generatrss E.xtradion 1&2 46 The extractJn steam is used to encrease the Ly..iwe of the t&,7winer pnar SD No 25 1 To increase 6 e temperature of the feedwater onor to its entenng Steam SO No 25 to its erd.mng the steam generators Wet steam is directed from the low pressure Pgs 1 thru 3 the steam Generators, which results in an increase in overall Pg 1 and NA pressure feedwater heaters in the condensate and feedwater systems pfant efficier.;y The magor mmponents are the feedwater heaters, turtxne tWeeder inp '
valves, ewtracten line dram valves and associated piping 2 To minimize lhermal shock in the steam Generators UFSAR The e* action steam system inaerfaces wth the followmg systems / components Secton to 2 2 3 To assrst in removm0 moisture from the tugh pressure
- Feedwater heaters, drams, and vents system turtaine 3rd stage try supplying steam to the 1st stage of the
- Reheat steam system moisture separator reheater.
- Scavengmg steam
- Reactor conlant waste evaporator system
- Miscellaneous waste processmg system
- Man steam system
\ Slide 16 /
9R-037 t
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Tube Rupture _Basis Event Event
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1 l
l Life Cycle Management Project l
EN-1-301 Revision I i l
Station Blackout Screening Tool l Reference 1 - Calvert ClitTs Nuclear Power Plant, Station Blackout (SBO) Analysis Reference 2 - Calvert Cliffs Nuclear Power Plant, Updated Final Safety Andysis Report, Section 8.4, Revision 20
~
SYSTEM / SYSTEM STRtiCTURE ID No. SOURCE DOctiMENT/PC SBO COPING FUNCTION Instrument AC 17 Ch VII Pgs.5,6 Deenergize the plant computer h
Emergency Diesel 24 UFSAR Section 8.4 - Provide power to reach safe shutdown coaditions Generator Auxiliary Feedwater 36 ChIV Pgs.6,7 - Decay heat removal & condensate inventory Sampling System 38 ChIV Pg.2 Provide RCS isolation to maintain RCS inventory (NSSS) [ Note 4)
Chemical and 41 Ch IV Pg.2 - Provide RCS isolation to maintain RCS inventory Volume Control [ Note 4)
Feedwater 45 ChIV Pg 7 Provide SG levelindntion Safety injection 52 ChIV Pgs. I1.16 - Provide valve position indication & manual closure of containment isolation valves [ Note 1)
ChIV Pg.2 - Provide RCS isolation to maintain RCS inventory
[ Note 4]
Plant Drains 53 ChIV Pgs.1I,16 - Pr vide valve position indication & manual closure of containment isolation valves [ Note 1)
Control Rod Drive 55 Ch IV Pgs. 4. 5 Insert CEAs to provide untive reactivity for Mechanism and shutdc wn Electncal Reactor Protective 58 Ch 11 Pg.14 - Provide RFS loss-of-load (LOL) trip [ Note 3)
Primary 60 ChIV Pgs.14-16 - Prc vide vane position indication & manual Containment H & V closure of containment isolation valves [ Note 1. 3]
Reactor Coolant 64 ChIV Pg.5 - Provide indication of natural circulation (CETs)
ChIV Pg 2 Provide RCS isolation to maintain RCS inventory
[ Note 41 Nuclear 78 ChIV Pg.5 - Provide shutdown mdication ,
instrementation i
l Ma'n Steam 83 ChIV Pg.6 - Provide motive steam to AFW pumps
[ Note 3) ChIV Pg.7 - ?rovide closure of MSIVs and SG blowdown isolation valves to prevent excessive RCS l g Slide 18 98-037
e e N
Life Cycle Management Project ,
EN-1-301 Revision i UGE LCM PROGRAM 1ABLE 2 SYSTEM LEVEL SCOPING RESULTS Revision 5 CRITERIA 1 & 2 CRITERION 3 Class I, Class I, SR-1M in Scope Req'd SR-1M, or HELD SystemrStructure Unit ID for DBE OBE Plant Function (s) Q orNELB Peference PAM FP ATWS $80 PTS EQ Yes/No Condensate Pohstung 1&2 39 No None No N/A N/A No No No No No No No Domineralizer Chemical and Volume 182 41 No. 2 Manual inpl8craten No MA N/A Yes Yes No Yes No Yes Yes Cont of(CVCS) No 3 (#2.3.5,6.9.10,12,16.26)
(7)(9) No. 4 No 5 RCS Press & PZR Lvl/ Manual No 6 (#2.3,4,5.6.7,9.10.12.14.15.16.26)
No.7 No 9 Letdown Line Isolation (#17)
No 10 Cok! Leg Dreak-PZR triecten (#17)
No 12 Containment isolaten (s13.17)
No 13 SIAS-Safety injection /Doration No.14 (#4.7,13.14.15.17)
No.15 '
No 16 No 17 No 26 Cucutsung Water 182 42 No None Yes N/A N/A No No No No No No Yes Condenser Air Removal 1&2 43 No None No N/F N/A No No No No No No No Condensate 1&2 44 No None No NdA NtA No Yes No No No No Yes Feedwater 1&2 45 No. 2 Cntmt Overpressure Protechon (#14) No N/A N/A Yes Yes Yes Yes No Yes Yes No. 3 Provent Reverse Flow from SG (#26)
No. 4 Cntml Press Control & Coohng (813,14.17)
No.5 Provide Signats to ESFAS (814.t5)
No 6 Provide Signah to RPS (#4.6.7,12.14.26)
No 7 Provide Signals to AFAS (NOT #7 & #26)
No. 9 Isolate Affected S!G(#14.15)
No.10 No.12 No 13 No.14 No.15 No.16 ji No 17 No.16 /
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No.26 Slide 19 - 98-037
Life Cycle Management Project Structures in Scope Per ES-011 (safety classification standard), the following structures have been designed as SR-CATI Containment Structures
. The containment emergency sumps including grating enclosures The permanent cavity seal ring Auxiliary Building (several areas are exempt per ES-011)
Intake Structure (circulating water and saltwater enclosure portion)
Diesel Generator Rooms Refueling Water Tank Pumps Rooms Condensate Storage Tank 12 Enclosure Structures Fuel Oil Storage Tank 21 Enclosure Structures Auxiliary Feedwater Pump Rooms Auxiliary Feedwater Valve Pit Enclosure Electrical Ductbanks Slide 20 98-037
j [M ~
Life cycie management Project IPA Flow Diagram .
C O p IIjf Pre-Evaluation Passive or ,
SS within Active? V scope Intended ac,;y, functions No Periodically Components replaced?
that contribute /
1r AM to intended '
II:nctions No Managed No Excluded y existing by rule?
activities? y Yes ,
Modify existing or-Yes add new programs V V V V U SCs not subject Demonstration that the efTects of Results to A M R aging are adequately managed j
t j
slide 21 98-037 '
t .
Life Cycle Management Project l
Component Level Intended functions for the system being scoped Scoping Process for Systems DDE Flow Charts v
PAM, SBO, FP, PTS, Describeintended function
=
ATWS, EQ Screening in m re detailif needed Tools I Otherimplicitintended functions, e g. PB,1E, structuralsupport 1
1e \
Master Equipment List / For allintended
\ l for the Systems 1 functions of the system l System tevel Scoping
,, j l
Results & References L t all system Function catalog 01 components uhich are _
_g required to perform the . Function catalog 02 function or could fail Plant drawings and prevent the ,__, .
OE( maa" .
A l-1r Q List documentation Function catalog n ;
Next intended functson
\ / d Operating!nstructions
{ l Resort function catalogs by component l List of system components and k their intended function (s) E Slide 2_2 1
98-037
e e j Life Cycle Management Project 3CSE (CM Program CCuPP Eu-13o2, Revision 0 taste 1 NTENDEo sis 1EM fuhCTious sisrEJt: o45 IEEDW4:ER etisi Criterie 1 & 2 Criterien 3 C a fuktison DSE i P P i s oEsCRiPfied 1 '1 '1 1 1 1 2 V s P o NUMBER 1 1 1 1 E A T W 8 F oF FUNCTION 2 3 4 5 6 7 8 9 o 2 4 6 a 3 5 T 6 A 1 E n e e a s s o P tee 45-on sEmo sicuats to Estas Amo PaavioE siEA= cEweAion isotation. . . . . . . . . . . . xx. . . . . . . . . . .....l (iPt 92-155 AccaEssEs NE APPt CASTE 00Ee Fat TNis fuktiloNi I
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ta045-o2 PeoviCE CoMTAihMENT oVERPEEssutE PtoTEtinou. x
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i E
R t oc5-o6 to maintain T E P.Essu E saumoini or inE sisTEn tiouro. . . . . . . . . . . . . . . . . . . . . . x .
.....l tex 5 or so PeovinE inroanariou usEn To assess inE Ptani Ano Envinous . . . . . . . . . . . . . . . . . . . . . . .x CoNDivioM inut NG Ako rott0 WING AN ACCIDENT.'
. . . .l ti m 5-or-a uni usEn . ........
. . . . . . . . . . . . . .....j tRM5-oT-3 STEAM GEERAlot tEWt. . .. . . . . . . . . . . . . . . . . . . . .
.....l tRo45 07-C STEAM CENERAroR PRESSURE. (IPR 92-155 BEQUESTS INE ADDifion of TN!s PARAMErER)
........................l A
i Slide 23 98-037
e e Life Cycle Management Project ScAE LCM Program PAug 2 CCmPP En-1-302, REvlSION O =
taste 1: luTENDED STSrEM fukCil0NS STEIEM: 045 fEEDWAfte ettsi Criterte 1 8 2 Criterter 3 C A DBE t P P 1 1 FUNCTION DESCRIPil04 1 1 1 1 1 1 1 1 2 V $ 1 1 P E A I W G f ID munsEt of fustil0N 2 3 4 5 6 7 8 9 0 2 3 4 5 6 7 8 6 h e A 1 E e N s s 0 P t 045-08 Pa0Viet STEAM umERA10e LEVEt smDICAf ton. (Afus AffaleurE ADDED . . . . . . . . . . . . . . . . . . . . . . . . .
BT THE DISPOSITION OF ipa 92-15T) xx .l s
A A
tam 5-09 10 MAlktAIN EtECitlCAt CONTIMuliY AND/0E PSOVIDE PROTECTION OF . . . . . . . . . . . . . . . . . . . x. . . . . . . .l THE ELECTRICAL siSIEM.
R I A tt045-10 DELETED IN REVISION 210 COMPtf WITH THE DISPottil0N OF TPt . . . . . . . . . . . . . . . . . . . . . . . . . . . .l l 92-155 ti m5-is noviDE sicmAts 50 ArAs. xx xxxx . x xxxxxx . x. . . . . . . . . . .l l xx ti m5-i2 novioE sicmAts To us.
. . x . . . . x . x . . . . x . . . . . . . . . .
.l, inm5-i3 momif0= so tEvEt A=O ntssunE T0 suPPoni sArE snurocum != vat . . . . . . . . . . . . . . . . . . . . . . . . ....xl EVENT OF A PO$fUtATED SEVERE FIRE. (FUNCil0M ADDED Si IPR 95-006 AND 92-157)
R I
Slide 24 98 037
Life Cycle Management Project SG&E CCNPP COMPONENT INTENDED FUNCTION CATAIDG EXTRJCF DATE:
REPORT DATE:
PAGE NUMBER: 1 FUNCTION: LR045 06 SYSTEM: 045 EQUIPMENT ID REFERENCE NOTES 1-DB1-1018 NETD 1, 4 1-DB1-1013 NETD 1, 4 1-DB3-1001 NETD 1, 4 1 DB3-1002 NETD 1, 4 1CKVFW-130 FEiD 1 1CEVFW-133 NETD 1 1HVFW-1501 NETD 1 1HVFW-1502 NETD 1 1HVFW-1503 NETV 1 1HVFW-1504 NE1D 1 1HVFW 1505 NETD 1 INVFW 1506 NEID 1 1HVFW-1507 NETD 1 1HVFW-1508 Nrn 1 1HVFW-1510 NETD 1 1HVFW-1511 NETD 1 1HVFW-1512 NETD 1 1HVFW-1513 NETD 1 1HVFW-1514 NETD 1 1HVFW-1517 NETD 1 1HVFW 1518 NETD 1 Slide 25 98-037
I 4
~
4, Life Cycle !
Management Project SG&f Life Cycle manegament Program CCMPP EU la302, alvi $10N 0 TA8LE 22 CO*0NENT LEVEL SCCrfk3 ttSULis
$7 stem: 065 ft s m itt i
i EQUIPDENT ID Ik SCOPE EQUIPeENT DESCRIPTICu FUNCTION ID OF Lkt e -
(atF TABLE 1) t!FERENCE LR on a NOTE u
da AAAAAAAAAAAkaAAAAAdd a A&aa AAA&&aad &&a aaad &aa aa a a a aaa a a a a a aaa a aa a a a a &a d a a n saa a aaa a aa aaa&A &a A A& l
) 18K33 1034 fu SYSTIA PIPluG
- B I AA46&AAtAAA AA A AAAA&a aaa n d ad aA a d aa a a a a aa aa a a aaa a a a a a a a a a a a a s s aa a a a aa a n d a d a s a d a d a &a ddad ad d aad 18KR3-1035 FV STsitM P1Plus W
AAAAAAAAAA AAAAU LA A A AALLAla LAAAAAAakaasa A A A AAAA a ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ' ^ ^ ^ ^ ^ ^ ^ ^
1 081 1018 Lt045-06 NETD tr 1, &
daaaaddadalaas s aa d aanasada s s ad a dad as a d a s a a d as sa d a d a a d ad an a s s a d a d a daa da d ad a s s a da s sa d as s asasad assadadassa&aaaa l 1-081 1019 Lt045 06 mitD tr 1, &
AAAAAAAda &AAA AAAAAAA AAAAAAA AAA A AA Aa sa A A Adaas A A A A& & da&&d as ada sa aaaaaa A A A AA AAaa ssaA A A&&&Asa&AaaAAAAAA&A A j 1 053 1001 Lt065 06 mETD tr 1, &
asa d add a i aAasA d aAda d u a s a d u s aa s u d a d a a d a n a d a d a d a a a d a a d a s a d a s s a d a a d a a d a s a u s s a a s u d a u s alsaaassaadassaadadauu ass 1 D53 1002 1 Lt045 06 3
WEfD tr 1, &
d ad addadanuss aa dadad aadud a ad du e d d a n n an da d d a n u n d s s as sa n n a n n a n n a ss a s s a n u u d u unan d aud dunuuadundsauuuuuaan 1AT&&83 SGfP 11 T11P & Rest 1 i
N AAaa aaakasa u u uAd a s s u ad a s u a da s s u o u u u d a d a d u a 9 a a n u d u s s u u d a d u u d d a sadu sa ssada ss aaaa aaa u a AAAda sadas a AAaaaaag 180 1C35/Ct1 ftp witt CouTROL 11 s
I N Me u&&&&&&ua&M&&uMMa&&&&&&&M&&&&&&&&&&M&444446&&&&de a u a u n a a n d a s a s s a s s a a n a s s a &&a s a u u n a4&M64M&&&&&&&&&&
itK21C35/Cs2 ftp mitt tout DL 11 4 l 4
m 1 M&H&4&He&& &&He&H&44&H H44444&M&H a a a a a a a&&&&u14g u a a a a a a aa a a a a&&4444M&4Ma&M&H&&&&&&&Mi&H&4444&4u u s u n a ga 4
18Et1C34/C81 FEp Mfit CONTROL 12 i
a
&& && H &&&&&&& && &&44444446& &&&4444444&&MM&&u&&M&&&&H 6&&&&&&& &&&ha&&Hg&&&&&&&&g&&&g ggg&g&&g&gg&gg a a a a a a a a a 4
18Ct1C34/C52 FEp Witt CCWit0L i
u I
He&M6&&&&Me&Me&M&&&&444466&&&&&H&ea d a a H a a a a d a&&&&MMMH&446&M6444&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&M&64444444444&
4 1CEV7PYLO 107 11 SCFP TLD CO @ 't PP Ist 1 =
asanadass adad ad ad dad aansad d a dass aa d a d a d da d d a s d ia d a d a s a Id a d d a d a d i d f aa d a d a s s a d a sa ad assadadaaa ssadasassassiaaa aaaaaaaaaaaassa 1CrV7PTLO-113 11 $GFP TLD CDC QUT CKV a
&&&& &&&&&&&&&&&&&444&&&&&&&&M&44446&M&&&&&&&&&&&&&&&&&&&&&&&&&&&Ma&&&&&&&&&&&&&&&&&&&&&M&64M4646444444444 A A A A A aa a&&&&
1CKV7PTLO-121 11 BGFPT NOP A DISCN trY a
&&&&&&&&&&&&&Me&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&us4&&&&&&&&&&&&&& a d a H a s a a a d &&&&&&&&&&&&&&&&M&&&&us&&&&&&&&&&&&&&&&&&
1CEVFPTLD-122 11 SCFFT MOP $ pl$CN CTV l 1
m uuuuuummusmuu uuuu&uud a u u Auu&umauuuuuuuuuuuummuuuumuuuumeuuuuu 1CKV7PTLO 129 1
12 5C777 LO CD@ PP IMLET l Slide 26 98-037
g Life Cycle Management Project PAGE: 248 ,
BC&E Life Cycle Management Program TABLE 2: COMPONENT LEVEL SCOPING RESULTS SYSTEM: 045 FEEDWATER REFCRENCES
$80 SCREENING TOOL 0002 GENERAL NOTES:
1 'These ccaponents are required for pressure boundary only and do not appear in any other function catalog.
2 Att associated ttbing for these conponents was included in the screening process and thus will need to mdergo aging evaluation.
3 QLIST Redline drawing M 39 sh4 designating the pressure bomdary was transferred to P&lDs 602273H0004 and 622273H0004 as well as 00s 60702SH0004 and 62702SH0004 so that all conponents would be captured that were required for pressure bomdary.
4 The nemenclature of this tag was updated in revision 4 to this work product to conform with the current designation in NUCLEIS.
5 This conponent was added to or reclassified in the 6/12/96 System 045 MEL and scoped in revision 2 to this work product.
B Conponents satisfyi. g PAM prrameter LR045 07 B on Table 1.
C Conponents satisfying PAM parameter LR045-07 C on Table 1.
4 Slide 27 98-037
Life Cycle Management Project 1
Component Level Scoping for Structures Does the structure have Yes system type components?
Perform component No O level scoping using the
,, system process for systern type ident:fy strue'ure intended function components
. Structural support to SR equipment
- Shelter / protection for SR equipment
. Piessure or fission product boundary
. Missile barrier
. Class II/I support l
- Flood protection barrier l
- Rated fire barrier l l
l Determine generic structural component types in this structure ir Add unique structural component types l
1r identify structural component types which contribute to each intended function l
1
\
sr Add supports for larFe SR equipment to scopmg results 1r Integrate scoping results for system type and structuraltype cornponents u
List of structural e cornponent types 5 and their intended functions Slide 28 v_,_.. e 98-037
Life Cycle Management Project IIG&E LCM Program EN-t-303, Rev. I TABLE IS: STRUCTURE INTENDED FUNCTIONS STRUCTURE: FOST #21 ENCLOSURE SIIEET 2 OF 2 INTENDED DESCRIPTION OF INTENDED FUNCTION CRITERIA Applicable to FUNCTION this structure?
ID NUMITER YES/NO I 2 3 4 LR-S-01 Provides structural and/or functional support to safety X Yes (2,3) related equipment.
LR-S-02 Provides shelter / protection to safety related equipment. X Yes (2) 1.R-S-03 Serves as a pressure boundary or fis*9 product rete ;on X No -
barrier to protect public health and safety in the event of any postulated DBEs 1.R-S-04 Serves as a missile barrier (intemal or extemal). X Yes(2) 1.R-S-05 Provides structural and/or functional support to non-safety- X Yes (3) i related equipment whose failure could prevent satisfactory accomplishment of any of the required safety related functions.
LR-S-06 Provides flood protection barrier (intemal flooding event). X No I.R-S-07 Provides rated fire barriers to confine or retard a fire from X No spreading to or from adjacent areas of the plant.
Slide 29 98-037
M Life Cycle Management Project BG&E LCM Program TABLE 2S STRUCTURAL COMPONENTS TIIAT ARE PART OF TIIE STRUCTURE STRUCTURE: FOST #21 ENCLOSURE SIIEET3 of 5 Component I" Strut'"re in Seracture ' Remarks / Reference (s)
Yes/No Reference H Structural Steel I. Columns NO 2 Heams YES CCNPP Drawing Nos63-756 Rev. 2 and 63 757 Rev. 0 3 Haseplates VI3 CCNPP Drawing No 63-757 Rev 0 4 Floor Framing NO 5 Roof Framing YES CCNPP Drawmg Nos63-756 Rev. 2 and 63-757 Rev 0 6 Roof Trusses NO
- 7. Dracing YES CCNPP Drawing Nos63-75R Rev 0, and 63-759 Rev 0 1
8 Girts NO '
9 Platform llangen Yl.S CCNPP Drawing Nos63-752 Rev 0, and 63-759 Rev 0 10 tktking YES CCNPP Drawing No 63-757 Rev 0 1I Jet Impmgement Harrien NO 12 I.ight Poles NO I3 Steel f.iners NO I4 I ight-Gage Metal Buddmg NO
!5 f loor Grating YES CCNPP Ikawing Nos 63 758 Rev 0, and 61-759 Rev 0 I6 Checkered Plate NO I7 Stairs and I. adders YES CCNPP thawmg Nos63-75R Rev 0, and 63-759 Rev 0 BR I entcls NO 98-037
Life Cycle Management Project TAHLE 3S:
STRUCTURAI, COMPONENTS WITitlN TIIE SCOPE OF I,1 CENSE RENEWAI, STRUCTURE: FOST # 21 ENCI.OSURE SIIEET 3 UF 5 Com ponent Intended Intended Function Description Rem arks / References Function Numher L R -S-11 Structural Steel I. Columns -
Component not in structure 2 Ileams 2,4.5 Supports roof which is a missle barrier. CCNPP Drawing Nos.63-756 Rev. 2 and 63-75 7 Rev. 0
- 3. 11aseplates 2,4.5 Ilaseplates for beams in item 2 above. CCNPP Drawing No.53-757 Rev. 0 4 Floor i reming --
Component not in structure 5 R oof I'eaming 2. 4. 5 Supports roof which is a missle barrier CCNPP Drawing Nos.63-756 Rev. 2 and 63-757 Rev. 0 6 Roof Trusses -
Component not in structure
- 7. firacmg 5 Ilracmg for NSR components (e g . access platforms stairs) CCNPP Drawing Nos.63-758 Rev 0 and 63 759 Rev. O R Girts --
Component not in structure 9 Platform llanters 5 llangers for NSR components (e g , access platforms, stairs) CCNPP Drawing Nos 63 758 Rev. O and t 3-759 Rev. 0 10 Decking 24.5 Integral part of concrete roof CCNPP Drawing No 63-757 Rev.0 1I Jet Impingement flarriers -
Component not in structure
- 12. I.ight Poles -
Component not in structure 13 Steel I.iners -
Component not in structure t4 l.ight-Gage Metal fluilding Component not in structure 15 f loor Grating 5 NSR components whose failure could potentially prevent CCNPP Drawing Nos63-75R Rev 0 and 63-759 Rev. O accomplishment of a SR funcleon 16 Checkered Plate --
Component not in structure 17 Stairs and 1. adders 5 NSR components whose failure could potenteally prevent CCNPP Drawing Nos63-758 Rev 0 and 63-759 Rev. 0 accomplishment of a SR function.
I8 1.intels Component not in structure Slide 31/
98-037
/
Life Cycle Management Project IPA Flow Diagram Scoping _
fyg.[yg[gggjgg Passive or :
SS within Active? V scope
- Intended Active No functions Periodically Components eplaced? y that contribute AMR to intended No fimetions Excluded No anagW y xisting :
by rule?
activities? U ;
ves Modify existmg or i Yes add new programs V V V U V l
ses not subject Demonstration that the effects of Results to A M R aging are adequately managed Slide 32 98-037
l l
Life Cycle Management Project l l
l Pre-Evaluation Process 1 1
1
/ T l Functional Scoping -* For all passive SCs i
Results !
1 1 I
! ' N SC l
i % For allintended functions f e systems subject to replace- ."
ment at set frequency }
or qualified life <40 l years? l Does function No mvolve motion or change vu ,
in properties or configuration ; l ofSCs
- l No further IPA SCs review required Y" No excluded by LR Rule u language? l v
l Add SCs to system list No further IPA review !
of passise SCs 3, required for these SCs i u
l Add SCs to system list ~
No of passive LL SCs All functions
! complete?
! \ / 1 SCs Subject i vu f 3 l Any passive SCs ! 4 to Aging ,
o remaining? Management Y"
I Review List of passive SCs for No the system o t_ _
Pre-eval Complete l
1r 1r l
l System or Commodity Structure Aging AMR Evaluation Slide 33 98-037 l
L
(( M Life cyc e management Project t
Feedwater Scoping Results No. of Device Types:
i In scope of LR 20 With only active functions 13 Replaced or in ILCE 2 Subject to AMR 5 i
i Slide 34
1 l
l Life Cycle l Management Project l
l Component Pre-Evaluation ATTACHMENT 1, FUNCTIONAL DISPOSITION RECORD l System: Main Feedwater (045)
Function Function Function Explanation of Passive / Active ID Description Passive? Determination LR045-01 Send signals to ESFAS and No Providmg a signal mvolves a change in provide SG isolation. configuration, Closure of SG MOVs requires motion and change in configuration I LR045-02 Provide Contamment overpressure No Closure of SG MOVs requires motion and l protection change in conficuration !
LR045-03 (Function deleted by TPR 96-010) NA NA LR045-04 Prevent reverse flow from SG via No Closure involves motion and a configuration check valve closure chance LR045-05 Maintain functionahry of electncal No Motion and change m configuration required equipment as addressed by the EQ to function after a DBE.
Program LR045-06 Maintam the pressure boundary of Yes System pressure boundary is maintamed ~
the system without motion or change in configuration LR045-07 Provide mformation used to assess No Providing mformation requires a change in the plant and environs condition configura: ion.
- during and following an accident LR045-08 Provide SG level indication No Providmg indication requires a change m l
configuration.
LR045-09P Mamtam electrical contmuity Yes No motion or configuration or property and/or provide protection of the change is required for listed device types electrical system
( All components m the IE Catalog have been relocated to an activ.e catalog or perform the IE function by motion or a change in configuration or properties)
LR045-09A Maintain electncal contmuity No TY, X - Electncal continuity provided by and/or provide protection of the changing properties electrical system (includes only RY - Electrical continuity provided by device types performing the changing state function by exhibiting motion or FU - Electrical continuity and fault isolation
, changing properties or provided by changing configuration i configuration)
LR045-10 (Function deleted by TPR 92 155) NA NA LR045-Il Provide signals to AFAS No Providmg a signal mvolves a change in configuration l LR045-12 Provide signals to RPS No Providmg a signal involses a change m configuration LR045-13 Monitor SG level to support Safe No Providmg indication requires a change in Shutdown in the esent of a configuration.
postulated severe fire, (Function added by TPR 95-006)
Slide 35 l
98-037
t l
1 w*
- l l
t !
Life Cycle '
Management Project i j
ATTACHMENT 2, COMPONENT REPLACEMENT RECORD i
l System: Main Feedwater (045) l Function ID: LR045-06 Function
Description:
Maintain the pressure boundary of the system l
Equipment Subject to Program Equipment Subject to Program ID l Replacement ID ID Replacement ID l Program? Program?
- ILTlll4A YES PT0009-104 2LTill4A YES PT0009-205 ILTill4B YES PT0009104 2LTill4B YES PT0009-205 ILTill4C YES PT0009104 2LTill4C YES PT0009-205 ILTill4D YES PT0009-104 2LTill4D YES PT0009-205 ILTil24 A YES PT0009-104 2LTil24 A YES PT0009 205 ILTil24B YES PT0009104 2LTil24B YES PT0009-205 ILTil24C YES PT0009104 2LTil24C YES PT0009-205 l ILTll24D YES PT0009-104 2LTil24D YES PT0009-205 l IPT1013A YES PT0009-105 2PT1013A YES PT0009 204 l IPT1013B YES PT0009-105 2PT1013B YES PT0009-204 l IPT1013C YES PT0009-105 2PT1013C YES PT0009-204 IPT10l?D YES PT0009-105 2PT1013D YES PT0009-204 IPT1023 A YES PT0009105 2PT1023A YES PT0009 204 IPT1023B YES PT0009105 2PT1023B YES PT0009-204 j IPT1023C YES PT0009-105 2PT1023C YES PT0009 204 IPT1023D YES PT0009-105 2PT1023D YES PT0009-204 l
l Slide 36 l 98 037 l
i
Life Cycle Management Project Component Pre-Evaluation ATTACHMENT 3, ISOLABILITY DETERMINATION System Name and Number: Main Feedwater (045)
Isolation Drawing Devices (including Coordinates if possible)
Isolable ponion 1 of 16 IHVFW 1541, IHVFW-1543, lHVFW-1705 l 60702SH0004 (C/D-6)
Isolable ponion 2 of 16 1 HVFW-1561, lHVFW-1563, lHVFW-1714 l 60702SH0004 (C/D-6)
Isolable ponion 3 of 16 I HVFW-1501, IHVFW-1503, lHVFW-1587 l 60702SH0004 (C/D-5)
Isolable ponion 4 of 16 IHVFW 1521, lHVFW-1523, lHVFW-1596 l 60702SH0004 (C/D-5)
Isolable ponion 5 of 16 I H VFW- 1661, l HVFW-1663, l HVF W- 1814 l 60702SH0004 (G/H-6)
Isolable ponion 6 of 16 IHVFW 1641, IHVFW-1643, lHVFW 1805 l 60702SH0004 (G/H-6)
Isolable ponion 7 of 16 I HVFW-1601, l HVFW-1603, lHVFW-1687 l 60702SH0004 (G/H-5)
Isoi&le ponion 8 of 16 IHVFW-1621, l HVFW-1623, lHVFW-1696 l 60702SH0004 (G/H-5)
Isolable ponion 9 of 16 2 H VFW- 1541, 2 HVF W- 1543, 2 HVFW- 1705 l 62702SH0004 (C/D-6)
Isolable ponion 10 of 16 2HVFW-1561,2HVFW 1563,2HVFW 1714 l 62702SH0004 (C/D-6)
Isolable ponion 11 of 16 2H VFW- 1501, 2 HVF W- 1503, 2 HVFW- 1587 l 62702SH0004 (C/D-5)
Isolable ponion 12 of 16 2HVFW-1521,2HVFW-1523,2HVFW 1596 l 62702SH0004 (C/D-5)
Isolable ponion 13 of 16 2HVFW-1661,2HVFW-1663,2HVFW 1814 l 62702SH0004 (H-6)
Isolable ponion 14 of 16 2 H VFW- 1641, 2 H VF W- 1643, 2 HVF W- 1805 l 62702SH0004 (H 6)
Isolable ponion 15 of 16 2HVFW 1601,2HVFW-1603,2HVFW-1687 l 62702SH0004 (H-5)
( lsolable ponion 16 of 16 j 2HVFW 1621,2HVFW-1623,2HVFW 1696 l 62702SH0004 (H-5) /
\ Slide 37 98-037
Life Cycle Management Project Component Pre-Evaluation ATTACHMENT 4, COMPONESTS SUIMECI TO SYSTEM AGING MANAGEMENT REVIEW System: Main Feedwater (045)
Eq uipm ent ID Equipment Description 1-DBi 1018 FW SYSTEM PIPING l D B I-1019 FW SYSTEM PIPNG l -D B 3 1001 FW SYSTEM PIPING l D B 3-1002 FW SYSTEM PlPING I CK V F % -13 0 12 SG FW HDR CK V I C K V F W -13 3 11 SG F% HDR CKV I H V F W -15 01 LT-ill3 A ROOT IHVFW 1503 LT-lll3A ROOT I H V F % 1521 LT ill3B ROOT IH V FW 1523 L1-1113 B ROOT I H V F W -1541 LT lll3C ROO f I HV FW 1543 L T-1113C ROOT I H V F W -15 61 LT ill3D ROOT l H V FW -15 63 LT-ill3D ROOT I H V F W -15 8 7 l-LT-ill4 A ROOT V L V I H V F W 1596 l-LT-ill4B ROOT V L V I H V F % 1601 LT-il23 A ROOT I H V F W -1603 j LT-il23 A ROOT I I H V F % 1621 L1 il238 ROOT I H V F W -1623 LT il23B ROOT I H V F W 1641 LT-il23C ROOT I H V F W 1643 LT il23C ROOT I H VF W 1661 LT-il23D ROOT IH V FW 1663 LT il23D R' JOT I H V F W - 16 8 7 l-LT-l l24 A ROOT V L V I H V F W -1696 l LT-il248 ROOT VLV I H V F W 1705 1 LT ill4C ROOl VLV I H V F W -1714 1 L1-1114D ROOT VLV l I H V FW-1805 1-LT il24C ROOT VLV I H V F W -1814 l LT il24D ROOT VLV IHVFW 220 11 SG F% CNTM1 HDR DRN I H V F W -222 12 SG FW CNTMT HDR DRN i M O V 4 516 V L V 11 SG F W ISOL I M O V 4 517 V L V 12 SG F W ISOL 1TE4516 11 F % S'O IN L T EM P ELM N T I T E 4 517 12 F W S/G IN L T E M P E L M N T 2-D B l-2 018 FW SYSTEM PlPING 2 D B i-2 019 FW SYSTEM PIPING 2 DB3 2001 FW SYSTEM PlPlNG 2 DB3-2002 F% SY S TEM PIPING 2CK V F% -130 22 SG FW HDR CKV 2 C K V F W -13 3 21 SG FW HDR CKV 2 H V F W -1501 t il3 A-LT & 1013 A-PT ROOT j 2 H V F W -1503 lil3 A Li ROOT
[ 2 H V F W -15 21 i l 05-LT. Il 13B LT & 1013- '
! 2 HV F W 1523 Il05 LT & lil3B LT ROOT 2H V F W 1541 lil3C-LT ROOT 2H V F % 1543 lil3C LT & 1013C-PT ROOT l N Slide 38 98 037
7" N
Life Cycle Management Project Component Pre Evaluation ATTACIBIENT 4A, COMPONENTS SUBJECT TO COMMODITY AGING MANAGEMENT REVIEW System: Main Feedwater (045)
Instrument Lines Commodity Evaluation Equipment ID Equipment Description I H V F W-1502 LT-lil3A ROOT IHVFW-1504 Ll lll3A ROOT IHVFW 1505 LT-ill3A HI VENT IHVFW-1506 LT Ill3A DRN IHVFW 1507 LT Ill3A ISOL IHVFW-1508 LT ill3A ISOL IHVFW 1510 1105 LT ISOL IHVFW 1511 LT ill3A EQUAL I H V F W-1512 LT Ill3A B/U DRN IHVFW-1513 LT-Ill3A DRN I H V F W-1514 LT-ill3A B/U DRN IHVFW 1517 Il05 LT ISOL IHVFW-1518 Il03LTISOL I H V F W-1519 Il05.LT DRN IHVFW 1520 1105-LT DRN IHVFW 1522 LT-Ill3B ROOT IHVFW-1524 LT Ill3B ROOT IHVFW-1525 LT lll3B HI VENT I H VF W-1526 LT lll3B DRN IHVFW 1527 LT-ill3B ISOL IHVFW 1528 LT-Ill3B ISOL
~
IHVFW 1530 1 LT Illi 150L I H V F W-1531 LT-Ill3B EQU AL IHVFW-1532 LT Ill3B B/U DRN I H V F W-1533 LT ill3B DRN IHVFW 1534 LT ill3B B/U DRN IHVFW 1537 1 LT-Ill! ISOL IHVFW 1538 l LT illi ISOL IHVFW-1539 t ill-LT DRN lHVFW 1540 lli1-LT DRN lHVFW-1542 LT ill3C ROOT IHVFW 1544 LT-Ill3C ROOT IHVFW 1545 LT-1113C HI VENT 1HVFW 1546 LT 1113C DRN l
IHVFW 1547 LT lll3C ISOL
- IHVFW 1548 LT-Ill3C ISOL IHVFW 1550 ll05.LT B/U DRN I H V F W-1551 LT lll3C EQU AL IHVFW-1552 LT-1113C B/U DRN lHVFW 1553 LT ill3C DRN lHVFW-1554 LT ill3C B/U DRN Slide 39 /
IHVFW 1557 Il05 LT B/U DRN j
98-037 l
l
O 4 7[g Life cycie management Project IPA Flow Diagram '
V I
Passive p,,,,
or SS withm Active? U scope Intended ac,;ye ,
functions " ,
Periodically -
Components replaced? U that contribute to intended Ye5 functions No Managed No Excluded ;
y 3 ng by rule?
activities? y y,, Modify existing on Yes add new programs V V V V V ,
Restilts sCs not subject Demonstration that the effects of
/,,
to A M R aging are adequately managed Slide 40 98-037
Life Cycle N \
Management Project
}
Ust of passive, long-lived SCs and their i-u ,unen.s Aging Management C- at i,e Review Process is SC part shown that effects a
% y, dassembi a -Pt am areb-g wd w/o addressmg for Systems ARDMs' w
o Provide documentanoi is SC rep! y. that effects of agmg ar ,
bcense frequently based _ bems managed to Renewal on condia assure mtended Applicatiot j funcnons f w
isSC Y" refurbishmen w
h SC long- k lived {
List of plausible i
- Msub-, + OE(
Combmanons Create potennal Organize SCs mio ARDM bst poups of subcomponeris / For each plausibleT
~ ARDM'subroup r l l combination j input from Site Expert Panel Create ARDM matnx Assess lesel of concem and seventy of l agmg effects OE( g [ Foreach ARDM )
-l subpoup combination l Determme the appropnare tpe of bcense IS ARD. 'N * *"##"'"' --e Renewal
- 3. Add ARDMsubroup based on concerns Application plausible based on t hst of plaus:ble ones and effects.
mat't. ens, a,nd for the system document reasons w -
Document reasons l ARDMs are not
! plausible 1' Allplausible ARDM IPA subroups managed} g, Com plete I All ARDM'subpoup he ( combmanons complete' ) 1.
L Slide 41 98 037 l
l
P Life Cycle Management Project Goal of AMR To demonstrate that the effects aging of SCs within the scope of LR and subject to AMR are adequately managed. This is accomplished by:
Crediting replacement, refurbishment, comprehensive performance and/or condition monitoring, or the long-lived EQ programs or Identifying plausible ARDMs for each component Evaluating the effects of the ARDMs on the passive functions Determining the manner in which the effects are managed snde n 98-037 ,
Life Cycle Management Project Definitions Potential- An ARDM is potential for a given equipment type if the engineer concludes that it could occur in applications of the equipment type throughout the plant with conducive environmental conditions.
Plausible- An ARDM is considered plausible for a specific component if, when allowed to continue without any preventive or mitigating measures or enhanced monitormg techniques, it could not be shown to maintain the capability to perform its intended, passive function throughout the period of extended operation.
\ /
Slide 43 93-037
Life Cycle Management Project Definitions (continued) .
Equipment type- A general categorization of components according to their function and design. Examples of specific equipment types are valve, piping, instrument, etc. '
Device type- A more specific categorization of components according to their function and design.
Equipment types are divided into a number of device types. For example, the equipment type for valves include
~
device types hand valve, check valve, control valve, and others.
4 i
Slide 44 98-037 '
[M Life cycie management Project Potential ARDM List Equipment Type Based on previous list for equipment type or ,
another device type of the same equipment type Developed if equipment type not previously evaluated Description of ARDM must include information useful for plausibility decision Slide 45 j'98-037
m ,
.x_
Life Cycle Management Project Component Agmg Management Review NITACIIMENT 7, POTENTIAL ARDM ' iST System: Main Feedwater System (NS) Equipment Type: PIPE ARDM PONIAI' j OTSNO) IDESCRIPTION/ JUSTIFICATION
~
- SOURCE l
- t Fatigue I Yes i istigue damage results from progressive, localimt structural change in [5] 1 materials subjected to fluctuating stresses and strains Associated failures
[6] l may occur at either high or low cycles in response to various kinds of
{21 I loads (e g., Mechanical or vibrational loads, thermal cycles, or pressure cycles). Fatigue cracks initiate and propagate in regions of stress concentration that intensify strain. 'Ibe fatigue life of a component is a function of several variables such as stress level, stress state, cyclic wave form, fatigue environment, and the metallurgical mndition of the material. Failure occurs when the endurance limit number of cycles (for a j
given load amplitude) is exceeded. All materials are susceptible (with varying endurance limits) when subjected to cyclic loadmg. Vibration loads have also been the cause of recumng weld failures by the fatigue of small socket welds. Certain piping locations, such as charging lines, have been found to experience vibration conditions. In some cases these failures in pipe have been due to inadequately supported pipe or obturator induced vibratory loads.
Plant equipment operating in a corrosive environment subjected to cyclic (fatigue) Ioading may initiate cracks and/or fail sooner than expected based on analysis of the corrosion and fatigue loadings applied separately.
Fatigue-crack initiation and growth usually follows a transgranular path, although there are some cases where intergranular cracking has been observed. In some cases, crack initiation occurs by fatigue and is subsequently dominated by corrosion advance. In other cases, a corrosion mechai a (SCC) can be responsible for crack formation below the fatigue threshold, and the fatigue mechanism can accelerate the crack propagation. Fatigue design curves incNde factors which acmunt for these environmental effects.
Shde 46 98-037 I
)
l
/) ________J
l . .
l Life Cycle Management Project '
Grouping By device type May be one group May be twenty groups Material, design, function, environment, contact w/ fluid Slide 47 98-037
7 Life Cycle Management Project Component Aging Management Resiew ATTACHMENT 3, COMPONENT GROUPING
SUMMARY
SHEET SYSTEM: Main Feedwater (045)
GROUP ID NUMBER: 045-DB-01 GROUP ATTRIBUTES:
- 1. Device Type: -DB
- 2. Vendor: NA
- 3. Model Number: NA
- 4. Material: Carbon Steel
- 5. InternalEmironment: Controlled ehemistry water at 435F (normal operation)
- 6. External Environment: Climate controlled atmoseherie air (Containment Blde )
- 7. Function: Maintain system oressure boundan-
- 8. Name Plate Data:
PARAhETEE VALUE System Temperature Variable from ambient (70F) when shutdown to 435F when operating (subject to thermal transient conditions due to thermal stratification near S/G nozzle at HSB, plant start-up / shutdown, and operational transients)
System Pressure </= 1300 psig Materials of Construction Carbon Steel-seamless ASTM A 106 piping, cast steel ASTM A-234 fittings (alternate material for 1-DB1-1018, -1019 piping and fittings: Cr-Mo per M600C)
Joints Butt welded, except socket welded for 2" and smaller branch lines LIST OF GROUPED COMPONENTS (EQUIPMENT ID):
Eguioment ID Descriotion Eauipment ID Descriotion 1 DB1 1018 FW SYSTEM PIPING 2-DB1-2018 FW SYSTEM PIPING l DB1 1019 FW SYSTEM PIPING 2-DB1-2019 FW SYSTEM PIPING Slide 48-98-037
e Life Cycle Management Project Component Aging Management Resiew ATTACHMENT 3, COMPONENT GROUPING
SUMMARY
SHEET SYSTEM: Main Feedwater (045)
GROUPID NUMBER: 045-DB-02 GROUP ATTRIBUTES:
- 1. Device Type: -DB
- 2. Vendor: NA
- 3. Model Number: NA
- 4. Material: CartEn Steel
- 5. Internal Emironment: Controlled chemistry water at 435F (normal operation)
- 6. External Emironment: Climate controlled atmoso.heric air (Auxilian* Bldel
- 7. Function: Maintain system cressure boundan-
- 8. Name Plate Data:
PARAMETER VALUE System Temperature Variable from ambient (70F)when shutdown to 435F when operating (subject to thermal transient conditions due to plant start-up /
shutdown and operational transients)
System Pressure </= 1300 psig Matenals of Construction Carbon Steel-seamless ASTM A-106 piping, cast steel ASTM A 234 fittings (alternate material for 1-DB3-1001, -1002 piping and fittings: Cr-Mo per M600C)
Joints Butt welded, except socket welded for 2" and smaller branch lines e
LIST OF GROUPED COMPONENTS (EQUIPMEhT ID):
- _E_quipment ID Descriotion Eauiom,e_nLQ Descriotiqn I
l-DB3 1001 FW SYSTEM PIPING 2-DB3-2001 FW SYSTEM PIPING 1 1-DB3-1002 FW SYSTEM PIPING 2-DB3-2002 FW SYSTEM PIPING Slide 49 98-037
Life Cycle Management Project Subcomponents/Sub-Group Identification Subgroup based on material, design, function, environment Disposition subcomponents without a passive intended function .
i I
Slide 50 l 98-037 i
Life Cycle Management Project Component Aging Management Review ATTACIIMENT 4, SUBCOMPONENT/SUB-GROUP IDENTIFICATION SYSTEM NUMBER: 045 SYSTEM NAME: Main Feedwater EQUIPMEKrID: NA GROUP ID: 045-ilV-01 Subject se
. SaWrsup ID SuKomponent/Neme Manarseturer Material Modet Number AMR Pamelee Intended Fanction(s)
(Replaceinent Pgns) (Source) (Source) (Seeree) (Soune) (yerN) 04SIIV4tA Body. Bennet Var aoes Carbon 5aeet, Mark IIO!! 130 Malatalm eystens pressuro beamdary Y Forged er Caet (None) (NA) (9277151I-CLB-1) (FSK-MF 1003) (CIJR)
(VTM-D24S4001)
(I5587-0000)
(I$587-0021) 04SliV-01B Stem Whos 13% Chrome, Mestttelt,130 Maintale syntaan pressere beaudary Y ASTM A182 F6er eladtar (None) (NA) (VTM D240 0001) (FSK-MP-30al) (CLSR)
(15587 4008)
(15587 4021) 04SIIV4tC Body / Bonnet Betting (for Various Carben er ABoy MarkIIOff 330 Mainfala system pressere ! "7 Y bolted bonnet valves) Sesel '
(Neaw) (N/A) (VTM D2440001) (FSK-MP-1003) (CLSR)
(15587-0008)
(15587-0028) 045-IIV-OR D Dinh. ether men-preware Vashes NA NA None (Nermally open) N retalning yests (NA) (NA) (NA) (NA) (NA)
Slide 5I 98-037
p Life Cycle Management Project Plausibility Determination Materials and environment NRC and Industry Information Effects on passive intended functions
=
l Slide 52 98-037
Life Cycle h' Management Project Component Ag2ng M2a$Pt Review ATTACHMENT 5. ARDM MATRIX SYSTEM NUMBER- 045 SYSTEM NAME: Main Feedwater EQUIPMEhTTYPE: PIPE DEVICE TYPE: -DB GROUP ID (if appbeable). NA GROUP OR SUB GROUP ID ARDMs 045-DB-DI 045 DB-02 MA NA CAVITATION EROSION 1 1 CREVICE CORROSION B B DYNAMIC LOADING 3 3 EROSION CORROSION C C FATIGUE D 4 FOULING 5 5 GALVANIC CORROSION 6 6 GENERAL CORROSION E E HYDROGEN DAMAGE 7 7 INTERGRANULAR ATTACK B B MIC 9 9 PARTICULATE WEAR EROSION 10 10 PITTING B B RADIATION DAMAGE I1 11 SALINE WATER ATTACK 12 12 SELECTIVE LEACHING 13 13 STRESS CORROSION CRACKING 14 14 THERMAL DAMAGE I1 11 THERMAL EMBRITTLEhENT 15 15 Slide 53 98-037
N :
Life Cycle
[
Management Project ,
Component Aging Management Review ATTACHMENT 6, MATRIX CODE LIST I
SYSTEM NUMBER- 045 SYSTEM NAME: Main Feeduster ;
EQUIPhENT TYPE: PIPE DEVICE TYPE: -DB 1 GROUP ID (tf applicable): NA '
CODE DESCRIPTION SOURCE I The feedwater system fluid flow condinons, pressure and temperamre do not result [5),[11) in cavitauon condtoons in the piping. The flow is relauwly neady and the '
l pressure is much greater than the vapor pressure at system temperature.
Therefore, cavitauon erosion is not plaurible I 2 Not used 1
3 Normal servicz loads for feeduster piping do not result tu sigmfacant vibranon or (1), [4], l other dynamic loading conditions. The system pressure is normally m=mtamed (5),(10], !
steady. The transient effects of abnormal conditions, such as utter hammer, are 111]
not considered routine and do not result in cumulative degradanon of the piptog. ,
Based on these considerations, the effects of dynamic loading are neghphle and 1 will not affect the piping funcuon 4 The feedwater piping components in this group are far removed from the S/G, and [5),[8),
are not subject to rapid thermal trannent condicons associated with the S/G 19]. [Ill,
)
feeduster nozzle / piping thermal stratificanon conditions De source of thermal [12],[13],
cychng for the piptng in this group is plant start-ups/ shutdowns and secondary [19], [20]
plant transients These thermal cycles are conservauvely emtloped by the design code requirements associated 31th this piping (ANSI B31.7/B31.1 rules for calculaung aDowable stress range for expansion stresses) which aDow 7000 full temperature range cycles before applying addinonal stress hmitacons The code requtrements conservauvely envelope expected plant thermal transients through the penod of extended operation, therefore, thermal fangue is not considered plausible for this gro :p of piping components 5 Fouhng does not affect the component funcuan. The component tutended funcuen [5],[16) is to maintain the pressure boundary integnty only. Due to the control of l feedwater chenustry, fouling (includmg contammauon and sedtmentation) is not ,
expected. Any fouhng or sedimentauon mill not have an affect on the intended j funcuen i
6 Paping matenal as all carbon steel (asth potennaDy Cr-Mo steel also) and water [6J,[16] l chemistry is controDed. Therefore, the required galvanic cell and electrolyte are not present, and galvanic corrosion is not plausible-7 The piptog ts not fabncated from the high strength steel suscepuble to hydrogen [5]
embnttlement and cracking Therefore, this ARDM is not plausible 8 Carbon steel matenal is not rusceptible to intergranular attack (5) 9 MicrobiologicaDy influenced corrosion is not plausible due to the chemical [5), [16]
conditions and temperature of the workmg fluid in the system. The source for feeduster is deminerahzed water, and organic contaminn'itt are avoided through feedwater/ condensate chemistry control. AdditionaDy, normal feeduster temperature is above 200F mhr M:C not possible 10 Control of feedwater chemictry ensures essennaDy no paruculate matter in the (16) feeduster Domstream Therefore, particulate wear erosion is not plausible 11 The thermal damage and radianon damage ARDMs affect non-metalhes only. [2),[5]
There are no non-metallic matenals in thcee piping groups 12 The effects of sahne mater attack ts potennaDy apphcable orJy to piping in contact [1],[11]
with concrete and exposed to moisture (i.e., emhwM pipe) There is no embedded pipe in these piping groups of cornoonents 13 The carbon steel piping matenal is not susceptible to selectrve teachtng [6},(17J Therefore, this ARDM is not plausible Slide 54g 98-037 l
7 Life Cycle Management Project Component Aging Managemem Review ATTACHMENT 6, MATRIX CODE LIST SYSTEM NUMBER: 045 SYSTEM NAME: Main Feedwater EQUIPMENTTYPE: PIPE DEVICE TYPE: -DB GROUP ID (if apphcable): NA CODE DESCRIPTION SOURCE 14 Control of feedwater chemistry (parucularly oxygen concentranon) prevents the (5),[16]
environment necessary for SCC of carbon steel matenal Therefore, this ARDM is not plausible.
15 The feedwater system operanng temperature of- 435F max. is not suf!icient to [51, [Ill result an embrittlement Thermal *:mbnttlement of plain ca: bon and low alloy steels requires temperatures greater than 650F .
A Not used B Crevice corrosion and pttung can occur to areas of the piping system that are not [5],[6],
exposed to the general flowstream such as areas oflack of complete penetranon in [16}
butt welds, clearances at socket meld fit-ups, and other crevices. These areas may ccmprise sma!! locahzed volumes of stagnant solucon for which Duid chemistry may deviate from bulk system chemistry. Higher mncentranons ofimpunties may exist in these crevices due to out of specificanon system chem 2stry dunng shutdown conditions and due to the stagnant flow conditions of the crevice. The resulung degradation is highly lernhved pits or crais. The control of feedwater/ condensate system thud chemistry signincantly hmits the effects of crevice corrosion and pitting. Adinonally, controls over pipmg fit-up and wc! ding quahty dunng construction limit the locanons of potential crevices in the large bore piping. Most susceptible locations for crevices are the small bort branch piping (drains and instrumentanon taps) where socket wc!dmg creates potential crevices by design of theJomt.
The effects of crevice corrosion and pitting can not be d.smmM due to the potennal for crevice locahons and pote=Hy high impunty concentranons in the system during shutdown conditions Management of the effects of crevice corrosion and pitung should consist of. 1) maintenance of the current system chermstry control program, and 2) subjecting a representatne sample of pipmg locanons (from piping in these groups or representaave piping in other poruons of the plant) to an Inspecnon to determme the extent of fersh7ed degradanon occurnng in the feedwater piping C Erosion corroston as plausible due to tugh velocity, high energy fluid Dow [3],[5),
condinons. The effects of erosion corrosion include potentially rapid prpe wall [t1J.[16) thmntng to the point of pressure boundary failurt. The control of feeduster system fluid chemistry hmits the rate and effects of erosion corrosion. The feedwater system is monitored rouunely for the effects of crocon corrosion by the plant erosion corrosion monitonng program. The chemistry control progrra and the erosion corrosion monitoring program should be connnued through the pened of extended operanon tn order to manage the effects of erosion conosion D Fangue due to thermal cychng of the feeduster prpmg in this group Dow-cycle [5),[14),
fangue)is plausible due to thermal strati 5 canon of the piping adjacent to the S/G [15]
noznle during hot stand-by and low power operat:ng conditions The resulang high number of thermal cycles to which the piping is subjected could result m faugue damage accumulation to the point of crack ininanon and propagation An evaluation of feeduster system piping thermal fatigue should be performed to ensure that plant components that are currently momtored for the effects of fangue are boundmg for the feedwater piping Slide 55 98-037
. M Life Cycle Management Project l Component Aging Management Review j
ATTACHMENT 6, MATRIX CODE LIST l
SYSTEM NUMBER- 045 SYSTEM NAME: Main Feedwater EQUIPMENT TYPE; PIPE l' DEV1CE TYPE: -DB GROUPID (if applicable): NA CODE DESCRIPTION E
SOURCE General cononon of the feedwater system piping is plaunble due to exposure of [5J.[6],
carbon steel matenals to corrosive medium during shutdons periods and, to a [7],[16]
lessor extent, dunng operanon. The rate of general corrosion is low after the initial build-up of the protecove corronon film (magnente). Exposure to high oxygen concentrations dunng shutdown and potennal removal and re creauon of the corrosion film result in general cormston. The effects of general corronon is i l
pipe wall rhtnning over a relanvely large area and could result in pressure boundary failure if extensm The control of feedmater/ condensate system fluid chemistry significantly hmits the effects of general corrosion. Management of the effects of general corrosion should counst of: 1) maintenance of the current system chemistry control program, and 2) subjecung a representatm sample of piptng locanons (from piping in these groups or representative piping in other pornons of the plant) to an inspecuan to determine the extent of general degradation occurnng tn the feeduster piping. Portons of the feedwater system piping inspected for the effects of crosion corrosion are thereby managed for the effects of general corrosion 6 e , wall th" mae)
Reference List Source Title
[1] Standard Format and Content of Technical Informanon for Applications to Renew Nuclear Power Plant Operanng Licenses, Draft NRC Regulatory Guide No. DG-1009, December 1990
[2] Radtaban Effects on Organic Matenals in Nucicar Plants, EPRI Repon No. NP-2129 November i 1981 '
[3] Erosion / Corrosion in Nuclear Plant Steam Piping, EPRI Report No. NP-3944,1985
[4] Component Life Esnmation: LWR Structural Matenals Degradation Maehan*=. EPRI Repon No. NP-5461,1987
[5] Environmental Effects on Components Commentary for ASME Section III, EPRI Report No NP-5775, April 1988
[6] Corrosion Engmeenng, Fontana and Greene,1978
[7] Corrosion and Corrosion Control, An Introducuon to Corrosion Science and Engineenng. Uhlig, Third Edition,1985
[8] Drawing 60702, Sheet 4, Rev. 28; ConArnate and Feeduster System, Unit !
[9] Drawing 62702, Sheet 4, Rev. 30; Condensate and Feeduster System, Unit 2
[10] 01-12A-1, Rev. 22/OI 12A 2, Rev.14; Feedwater System Operaung Instruenons
[11] UFSAR, Rev.18; Chapter 4 - Reactor Coolant and Mmm sted Systems, Chapter 10 - Steam and Power Cotmrsion Systems
[12) ANSI B31.1,1967, Power Paping Code
[13] ANSI B31.7,1969 Nuclear Powc* Piping Code
[14] CE-NPSD 634-P, April 1992, Fatigue Monitonng Program for CCNPP Units 1 and 2
[15] IRI 011-785 ; S/G Feedwater Nozzle / Piping Thermal Stranficanon Issue Report
[16] CP-217, Rev. 5; Chemtstry Specificanons and Surveillance Secondary System
[17] Marks' Standard Handbook for Mechanical Engiacers, 8th Edinon, McGraw-Hill
[18] Metals Harthet , 9th Edition, Volumes 1 and 13, ASM
[19] Drawing 12543A 01, Rev.13; Feedaster Piping Isometnc, Unit 1
[20] Drawing 13547A-20. Rev. 6F; 13547A-47, Rev. 4; 13549A 26, Rev. 3; Fedwater Piping Isometnc, Unit 2 Slide 56 98-037
[g tire cycie management Project Aging Effects Management Assemble Discussion Package Plan Meeting w/ Implementation Engineer P
Meet w/ System Engineer & Program Experts Document Programs to Manage Effects of Aging Slide 57 98-037 l
_m Life Cycle Management Project Component Aging Management RevicW ATTACIIMENT is AGING MANAGEMENT REVIEW
SUMMARY
System Name and No.: Main Feedwater (045) pubcomponenter .
Devlee Oswey Pensive Intended Cresping Sehemspo Not Ptaesible Managed i.; Esisting Medtlketions New Pe*tten Type fD Punctsens Attribases Subject te Aging ARDMs Progreme 10 Needed Needed Mrmt Review
-DD 043-DB41 Mamtam system - Cartwns Steel Mstmet N/A Crevice Cerrosma CP4217 Yes - Age-Reisted pecure boundary - Conteo!!ed environment Pitting DegredationImpection
-Water @ 433F Oeneral Cerresion Program
. Sulject to thermal f.resion Cerrosion MN-3 3I1 CP4217 stratificatien cefitions Fatigue Fatigue Monitervig Yes -Censuitmerit e t
.. Program (see Anacienet 101,,,,,.
CP4217 043-DIM 12 Maintain symem - Carte Steel Memel N/A Crevice Cerroome CP4217 Yes - Ap Related pressure boundary . Centretted environment Pdting Degredation Inspection
- Water @ 433F Ocnevel Onevoeion Prograni Erosion Carrosmi MN 3 III CP4217 CKV 043CKV41 Maannin system . Carteni steet Memet 043CKV41C Crevice Cerreian CP42 t? Yes. Ag*Relatet pressure ^
_ ^ -y - Centretted environment Disk, and other Pdting Degradetion tropectean
- Water @ 433F empeasure. Ocneral Cortesion Pregrare retaming parts iresica Cerrowen Rept aska !0432032 10432033,20832043,
, and 20432044 CP4217 IIV 043 flV41 Meantami system .Carban Steet Matmal 043-IIV41D Crevice Corenesor CP4217 Yes - Age Refsted pensure " ' j Centretted environrnent Disk, and other Pitting Degradation Impwtsen
- Water / Steam up to $30F nontransure. Genceal Correeicn Program
. Normaffy open retaining parts 043-IIV42 Masitain syWem - Carhnn Steet Metmat 043-IIV4 t E Crevice Corrosion CP4217 Yam- Ag>Retsted pressure boundary . Contro: led envireernent Noncessure. Pitting Degradation Impection
. Water @ 433F retainmg *ntemst r General Corresion Program
- Norenally timed parts MOV 043 MOV48 Maintain system . Carbon Steet Matmet 043-MOV4 t E Crevice Carvenion CP42t? Yes- Ag*Refered peanne boundary - Contretted enwnenment Non pressure- Pitting Degradation Insputaan
- Water @ 433F retainnig irnemal Omeral Corresica Progrunn
- Normally open parts heeson Cerrosion CP42 t7 Yes- Ag*Reisted Degradation Inspection Nm TE 043-TE48 Meansin system - 2 l'4Cr-lMe Mstmet 043-TE4B!! Crevice Corrosion CP4217 Yes- Age-Retsted presure boundary - Controtted envirerunent Temperature Pming Degradstion Inspectuan
- Water @ 433F Elevnent Oenerst Corvesian Prograrn Erossen Corresson CP4217 Yes- Age Related Degr d timier-om Progr=ra Slide 58y 98-037
. a f
Life Cycle Management Project Component Aging Management Review ATTACllMENT 10, PROGRAM / ACTIVITY (PA) MODIFICATIONS SYSTEM NUMBER: 045 SYSTEM NAME: Main Feedwater PA/ TASK ID and PRESENT DESCRIPTION NEW/ REVISED AFFECTED PORTION CORRECTIVE ACTION / RECOMMENDATION Age-Related Degradation New Program The ARDI Program must provide %.ac ants for inspection (ARDI) Program identification of representative plant mmponents for inspection based on the results of this aging management review, the inspection sample size, appropriate inspection techniques, and requirements for reporting of results and corrective actions. Reference BGE Memorandum LCM 96-044, dated 2-15-96, for further infonnation.
CCNPP Fatigue Monitoring The FMP currently excludes the Main Feedwater System from An evaluation of the Feedwater Sy-tem piping (for which Program (FMP)- Scope of the scope of the program. thermal fatigue is plausible) is required in order to determine program portion, whether current fatigue monitoring practice emtlopes fatigue Commitment 01 effects on Feedwater components. The FMP must be modified, as necessary, to monitor appropriate plant components such that the thermal fatigue effects of Feedwater mmponents are bounded and managed.
Slide 59 98-037
e
- Life Cycle Management Project Component Aging Management Review ATTACIIMENT 8, DEVELOPMENT OF AGING MANAGEMENT ALTERNATIVES SYSTEM NUMBER: 045 SYSTEM NAME: Main Feedwater COMPONENT ID: NA GROUP ID: 045-DB-01 1 2 3
, PLAUSIBLE ARDM PLANTPROGRAM REASON FOR TIIE FORM OF AGING MANAGMENT FROM ALTERNATIVE CHOSEN ATTACIIMENT 5 Crevice Corrosion. Control system fluid chemistry in order to minimize the Control of fluid chemistry prevents a corrosive environment for ,
Pitting, General concentration of conosive impurities (chlorides, Feedwater System components.
Corrosion sulfates, oxygen):
CP-0217, Chemistry Specifications and Surveillance
- Secondary Systems Determine the extent of degradation due to the effects of The occurrence of crevice corrosion, pitting and general corrosion are crevice corrosion, pitting. and general corrosion expected to be limited and may not affect the intended function of the through inspection of representative plant components Feedwater System components due to the control of fluid chemistry.
prior to the period of extended operations: Inspections of representative plant components will provide assurance Age-Related Degradation Inspection Program (new that significant corrosion is not occurring, or will result in initiation of program) appropriate corrective action if significant cor rosion is occuring.
Erosion Corrosion Monitor Feedwater System piping for the effects of An crosion corrosion monitoring program is effective in determining a erosion conosion: rate of degradation and preventing crosion corrosion from affecting the MN-3-111. Erosion Corrosion Monitoring of component intended function.
Secondary Piping CMrol system fluid chemistry in order to minimize the Control of fluid chemistry prevents a corrosive environment for cor= ration of corrosive impurities (chlorides, Feedwater System components, and limits the rate cad effects of erosion sulfatet mygen)and optimize fluid pil: corrosion CP-0217, Chemistry Specifications and Surveillance
- Secondary Systems Fatigue Monitor the effects of thermal fatigue: Tracking and monitoring the fatigue status of Feedwater System CCNPP Fatigue Monitoring Program (with components will ensure that fatigue threshholds are not exaeded and
, modifications) that fatigue cracks are prevented or controlled.
k Slide 60 t 98-037
. N Life Cycle Management Project AMR Process for i J
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Slide 61 98 037
7 Life Cycle Management Project A TTACIIM ENT 3: PL AIISillLE A R DM s FOR STR UCTU R A L-CO M PON EN TS STRUCTU RE N A M E: No. 21 FOST Endasure SYSTEM NUMilER: --
Sheet _L of _1 STRUCIURAL PLAUSillLE ARDMs APPLICAllLE10S1EELCOMPONINIS I REMARKS COMPONLWIS K L M N R S T Stect Ikans PA NA NA NA - - -
Ft:nctions LR-52,4,5 liseplates PA NA NA NA - - -
I unctions LR-52,4,5 Rnit !mdng PA NA NA NA - - -
Functions LR-S-2,4,5 Bracing PA NA NA NA - - -
l' unction LR-SS P!atfiwm flangers PA NA NA NA - - -
Function IR-S5 IEcking PA NA NA NA - - -
l unctions l.R-S-2,4, 5 I huw Grating PA NA NA NA - - -
Function I.R-S5 stairs & Iakkrs PA NA NA NA - - -
I unction I.R-SS Anctor Itrakets PA NA NA NA - - -
function i R-SI Iegend A I recre-thaw G Shrinkage M Corrosion in tendons S Irradiation 11 I caching of calcium hydro 61e it Abrasion and cavitation N Prestressing losses T l'atigue C Aggressise chemicals I Cracking of masonry block walls O Weathering U (Not Used)
- 1) Reaction with sFgregates J Settlement P (Not Used) V I: (Not Ilsed)
Corrosion in ernbedded steel /rebar K Corrosion in steel Q (Not IIsed) NA Aging Mech not appl.
I' Creep I Corrosion in I.iner R lilevated temperalere -
Aging Mcch not poten.
\
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Slide 62 /
98-037
[ Life Cycle Management Project ATTACllMENT 4 STRUCTURAL COMPONENTS - ARDM MATRIX CODES STRUCTURE NAME: No.21 FOST Enclosure SYSTEM NUMBER: -
Sheet 2 of 3 CODE JUSTIFICATION REMARKS 101 See Appendix A 102 See Appendix B 103 See Appendix J PA See Appendix K Slide 63 98-037
i Life Cycle l Management Project APPENDLX K. CORROSION OFSTEEL 1.0 MECHANISM DESCRIPTION' Steel corrodes in the presence of moisture and oxygen as a result of electrochemical reactions initiall), the exposed steel surface reacts with oxygen and moisture to form an oxide film as rust Once the protective oxide film has been formed and if it is not disturbed by crosion, alternating wettmg and drsing. or other surface actions, the oxidation rate will diminish rapidly with time. Chlorides, either from seawater, the atmosphere, o groundwater, increase the rate of corrosion by increasing the electrochemical activity. If steel is in contact with another metal that is more noble in the galvanic series, conosion may accelerate.
In some cases, corrosion of structural steel in contact with water may be microbiologically induced due to the presence of certain organisms, which is sometimes referred to as microbiologically influenced corrosion (MIC).
These organisms, which include microscopic forms such as bacteria and macroscopic types such as algae and barnacles, may influence corrosion on steel under broad ranges of pressure, temperature humidit), and pH MIC cffects on carbon steci may result in random pitting and general corrosion.
The rate of steel corrosion depends on site-specific environmental condidons and measures taken to preven corrosion. A steel structure surface subjected to attemately wet and dry conditions corrodes faster than one exposed to connouously wet conditions Atmospheric corrosion proceeds much more rapidly in areas where the l
' atmosphere is chemically polluted by vapors of sulfur oxides and similar substances. Steel will corrode much ;
faster in the vicinity of seawater because of sodium chloride in the atmosphere The corrosion rate of steel usually l increases with tising temperatures.
Corrosion products such as hydrated oxides of iron (rust) form on exposed, unprotected surfaces of the steel and l
are easily visible. He affected surface may degrade such that visible perforation ma) occur. In the case o l
exposed surfaces of structural steel with protective coatings corrosion may cause the protective coanngs to lose l their abihty to adhere to the corroding surface. In this case, damage to the coatings can be visually detected wel in advance of significant degradauon.
2.0 EVALUATION 2.1 Conditions l
Steel can corrode m the presence of moisture and ox) gen as a result of electrochemical reactions The steel I
com.oonents on external surfaces are exposed to the outdoor weather conditions at the plant site. The CCNPP site is located in a geographic region subject to severe weather condiuons
- All outdoor components will experience the extreme temperature ranges, rain, snow, and changes in humidity expected at the CCNPP site. Since the ai inside these enclosures is not conditioned, the interior components will experience similar temperature and humidity changes throughout the life of the plant. The steel components located inside the enclosure may b exposed to moisture from condensation and from rain leaking through openmgs in the enclosure u alls l
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Slide 64 t
j 98-037
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D Life Cycle Management Project 22 Potential Aging Mechanism Determination Corrosion is a potential aging mechanism for the following enclosure structural steel components because conditions conducive to steel corrosion discussed in Sections 1.0 and 2.1 exist:
- Steel beams Functions LR-S-2. 4. and 5
+ Roof framing Functions LR-S-2,4, and 5
+ Steel decking Functions LR S-2. 4. and 5
+ Baseplates Functions LR-S4,4. and 5
+ Cast-in place anchors Functions LR-S-1,2. 4. and 5
+
Post-Installed Anchors Functions LR-S-5
+ Bracing Functions LR S-5
+ Platform liangers Functions LR-S-5
+ Floor Gratmg Functions LR S-5
+ Stairs and Ladders Functions LR-S-5
+ Anchor Brackets Functions LR-S 1 where:
LR-S-1: Provides structural and/or functional support (s) for safety-related equipment.
l LR-S-1 Provides shelter / protection for safety-related equipment. I 1
LR-S-4: Serves as a missile barrier (internal or extemal)-
LR-S-5: Provides structural and'or functional support to non-safey related equipment whose failure could directly prevent sausfactory accomplishment of any of the required safety related functions.
1 2J Impact on intended Functions if corrosion of steel is allowed to degrade the above structural steel components unmitigated for an extended period of time, this aging mechanism could affect all intended functions of components listed in Section 2.2 2.4 Design and Construction Considerations Since corrosion was considered a potential degradation mechanism for structural steel components of the Auxiliary Feedwater Valve Enclosure, protective coatings were incorporated into the origmal design Exposed structural steel surfaces in the enclosure were coated during the construction phase (e.g., shop or field-painted, or galvanized)?
A walkdown' identified that the cast in place anchors and post installation anchors used for stairway and platform j support were painted after installation.
Slide 65 98-037 i
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l Life Cycle Management Project \
I 25 Pisusibility Determination Based on the discussion in Sections 2.1,23 and 2.4, corrosion could affect the intended functions of all structural steel members and is, therefore, a plausible aging mechanism for all steel components listed in Section 2.2 2.6 Existing Programs' Routine structure walkdowns conducted under MN 1319, " Structure and System Walkdowns," will provide th ;
discovery mechanism for degraded coating conditions and/or the presence of corrosion. MN 1319 provides for l
degraded coatings or any signs of corrosion to be documented on a checklist which is then used to prioritize corrective actions. Assessments of structure degradation are based on previous walkdowns to determine if the degradauon is dynamic or static. Dynamic degradation should become the subject of an issue report and have a
)
plan of corrective action in accordance with the CCNPP Corrective Actions Program.
3.0 CONCLUSION
The No.21 FOST Enclosure structural steel components, such as steel beams baseplates, metal decking. and cast-in-place anchors are vulnerable to corrosion anack if a corrosive environment prevails. Exposed structural steel surface in the enclosure are covered by a protective coating Aging management of degraded coating conditions i accomplished through existing plant programs.
4.0 I RECOMMENDATION All coated structura! steel components in the No. 21 FOST Enclosure should continue to be inspected to evaluate the condition of the coating. and repaired as required.
5.0 l REFERENCES
- 1. " Class I Structures License Renewal Industry Report." EPRTs Project RP-2643-27. December 1991.
- 2. BGE Drawing 63754SH0001. " Yard Tank Enclosures. CCNPP Unit No I and No 2." Revision i February 26,1997.
l 3 l
" Specification for Furnishing. Detailing. Fabricaung. Dehvenng. and Erecting Structural Steel.*
CCNPP's Design Specification No. 6750&l9. Revision 3, September 1970.
l l
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- 4. Not used i
- 5. " Standard Specification for Concrete Aggregates." Amencan Society of Testing and Matenals. AST C33-82.
- 6. "Examinanon of No. 21 Fuel Oil Storage Tank Enclosure - Calven Cliffs Nuclear Power Plant" September 21,1994
- 7. CCNPP Administrauve Procedure MN 1319." Structure and System Walkdowns." Revision 2. Apnl 10,1998 l
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( Slide 66j 98-037
Life Cycle Management Project Commodity AMRs Each commodity evaluation is documented in a report:
t Scope of evalua~ tion is specified Method of evaluation is described with emphasis on difference between commodity evaluation and
" standard" IPA process.
Results presented including plausible aging and programjustifications j The following commodity evaluations have been done:
Electrical Commodities (EC) Cables Instrument Lines (IL) Component Supports Cranes & Fuel Handling (C/FH) Fire Protection (FP) '
Slide 67 98-037 j
Life Cycle Management Project Commodity Evaluations- EC and IL For e:Lectrical commodities and instrument lines evaluations,
-Scoping /p.re-eval results are gathered from each of the system results i
-The A MR process is the same as it is for i systems j Slide 68 y 98-037 '
[, M Life Cycle Management Project Commodity Evaluations-C/FH For the Cranes / Fuel Handling commodity evaluation
-Components were scoped as part of the commodity evaluation
-Structures component level scoping results were reviewed to ensure proper interfaces
-The AMR process is the same as it is for systems i,
Slide 69 ;98-037
[g Life cycie management Project Commodity Evaluations - Cables i
For the Cables commodity evaluation
~
-Commodity evaluation covered all steps of the IPA
-Scoping step assumed all plant cables were in scope initially
-The AMR process is similar to that used for systems
- As effects were analyzed the scope was reviewed, and reduced as appropriate 98-037
[M Life cycle management Project IPA Process - Cables All Cables Group by ID Cables atCCNP{ SCs Subject m ID Potential Determine to EQ?
ARDMs Plausibility
+ Supporting SCs Materials Within Scope y i Addressed With
^
all EQ in Section Al w im 6.3 ofI.RA Slide 71 98-037
[M Life cycie management Project Commodity Evaluations - Component Supports For the Component Supports commodity evaluation ,
-Commodity evaluation covered all . steps of the IPA
-Scoping step was closely linked. to scoping results for supported components
-The AMR process is similar to that used for t systems i
Slide 72 98-037
, M Life cycie management Project 3
IPA Process - Component Supports t
ID Support Types p 7 Develop Gener,ic providing Support List ofSupports
--> Similar to that for '
to SCs Within Systems Scope t
1 b
}
Slide 73 98-037
7 ,
Life Cycle Management Project Commodity Evaluations - FP For the FP commodity evaluation
-Sysi: ems in scope primarily for FP function were scoped and pre-eval'd as part of the commodity evaluation
-Other systems with FP functions were scoped and pre-eval'd using the standard process
-The AVR process was unique from that used for the systems Slide 74 98-037
Life Cycle Management Project Fire Protection AMR Process System Subject to FP AMR No Nilounding "
i Normal Operation N" flounding Yes SR Pil No lloun AMR Conducted for Remaining Components FP AMR Complete Slide 75 98-037
(( g tire cycie management Project
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IPA Flow Diagram V
Scoping Pre-Evaluation .
Passive g ,,,
or SS within Active? U !
scope ,/
Intended ac,;ye functions Periodically Components replaced?
that contribute AM to intended y,,
functions Excluded No by en,su,ng by rule?
activities? V 3 ,, Modify existing or Yes add new programs V V V V V Scs not subject oemonstration that the errects or Results to A M R aging am adequately managed Slide 76 98-037
[g Life cycie management Project Section 5.9 of BGE's LRA Feedwater System Purpose To present the results of the Integrated Plant Assessment by summarizing the stream of evidence that has been documented to demonstrate that the effects of aging will be adequately managed in accordance with 10 CFR 54.29 i
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Slide 77 98-on
Life Cycle Management Project -
Construction of LRA
~
CCNPP Specific AMR SLSR,CLSR Q-List UFSAR DWGs Plant Procedures, Tests, Inspections NRC Documents ;
Generic externai Assessments EPRI Reports Standards Codes
( Textbooks slide 78 98-037
['M 4 Life cycie management Project Approach Provide a summary of scoping, pre-evaluation, and aging management review activities conducted for the FW System Provide direct reference to required supporting documentation that is maintained on site Satisfy all requirements delineated in the " Template"
- Provide a summary of relevant operating experience
- for the system as a whole
- to show the effectiveness of credited programs
- to identify significant component failures related to aging
- Slide 79
- mm l
Life Cycle Management Project Operating Expedence SystemInterview Sheet 1
System / Structure / Commodity-Eo.al: Collect idstorica! m' formation regardmg:
e i Overall historical system performance with respect to aging. '
. Significant age-related events that may have affected any SSCs intended function within scope officense renewal.
Significant improvements to plant operations, equipment and/or engineermg, maintenance and/or practices pertammg to these events.
, Preliminary Data:
Portions within scope ofLicense Renewal:
Portions subject to Aging Management Review:
Plausible ARDMs and applicable component types:
Any aging-related FCRs (facility change requests) or changes to the design basis, from the System Description (s).
There may be multiple system descriptions that cover the system covered by the LRTR:
Interviewees: Name: Position:
. Name: Position:
Name: Position:
Noter (document the event, the conclusions, the corrective actions and any subsequent observations relative to the effectiveness of those corrective actions.)
Now that these interviewees are awsre of the information being sought, what other individuals would they recommend speahng with7 Slide 80 98-037 I
Life Cycle Management Project Operating Experience ProgramInterview Sheet Program:
Spoal: Collect historical information regarding:
Historical program performance with respect to aging.
SigniScant age-related events associated with any SSCs for which this program is credited.
SigniScant improvements to the program related to aging.
?
Preliminary Data:
Aging management for which program is credited:
Interviewees: Name: Positlon:
Name: Position:
Name: Position:
Notes (document the events, the conclusions, the corrective actions and any subsequent observations relative to the effectiveness of those corrective actions.)
Is there anyone else who could offer similar information regaroMg this program?
Slide 81 /
98-037
Life Cycle Management Project Overview There are two main sections of the report Scoping - where we identify those components subject to AMR A:MR - where we evaluate component groupings to determine the methods BGE will rely on to manage aging through the renewal period Slide 82 98-037
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[ M_ ~
Life Cycle Management Project Scoping System level scoping
- System description
- System interfaces
- System scoping results Component level scoping Components subject to AMR
- Passive intended functions
- Device types subject to A MR .
Slide 83 98-037
Life Cycle Management Project AMR Potential and plausible ARD Ms Grouping Group 1
- Materials and Environment
- Aging mechanism effects
- Methods to manage aging
- Aging management programs
- Demonstration of aging management -
Group 2
)
- Same _ _ _
sno,,, j 98-037
1-
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- l. N l Life Cycle l Management Project l
Typical BGE LRA Section I Section Title 5.9 Title 5.9.1 Scoping l 5.9.1.1 System Level Scoping l System Description System Interfaces System Scoping Results 5.9.1.2 Component Level Scoping 5.9.1.3 Components Subject to AMR Eassive Intended Functions Device Tynes Subject to AMR 5.9.2 Aging Management l Potential and Plausible ARDMs Cimuping Group 1 Materials and Environment Aging mechanism effects Methods to manage aging Aging management programs Demonstration of aging management Groun 2
. Same l
\ 5.9.3 Conclusion 5.9.4 References Slide 85 98 037
0 0 Life Cycle Management Project System Level Scoping System Description / Conceptual Boundaries A brief description of the system Reference to Section 10.2 and Table 10-1 of the UFSAR Lists major components i
Introduces the simplified diagram '
References:
Slide 86 !98-037
M Life Cycle Management Project Main Steam System 3
WSLR, Refer to Section 5.12 7 -.
D >
- ",8'll'*'j8
- c ,,,, ,,a Computer Computer stored Specific instrument data is c*' d""d Fatigue Monitoring Engineer transferred and stored U Processes data Reviews data
- Deletes erroneous data
' Computer ( -
> neereces8esa te Prints graplucs and information sheets (FatiguePro) orarts semiannual Fatigue Evaluation Reports m Mechanical Issues final Fatigue Evaluation Reports Issues final annual Summary Reports R ie gn j r Slide 116 98-n37
/ 1
[ Life Cycle Management Project FMP Overview Plant instrument signals to plant computer
- Electronic signals converted to engineering numerical data and stored Specific plant computer data transferred to Reliability and Availability of Data (READ) computer ;
- Specific data stored in READ computer ;
Specific data extracted from READ computer via LAN :
- Data obtained monthly i L
- Data stored in FMP software (FatiguePro)
L
- Data check performed monthly (FatiguePro) l
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Slide ll7y ;98-017 i
7
[g Life cycie management Project FMP Overview (continued}
Six months of data processed twice each year Process data (FatiguePro)
Evaluate data (FME)
Remove invalid data (FME using FatiguePro)
Reprocess data (FatiguePro)
Print graphs and information sheets (FatiguePro)
Reports produced that are lifetime records
- Two semiannual fatigue evaluations reports
-- One annual fatigue summary report Design Engineering reviews reports
- Design Engineering performs independent r~ eview ofFME's work Slide iI8 98-037
Life Cycle Management Project FMP Cycle Based Locations Monitored Bounding Locations (Each Unit)
RPV Outlet Noz7les SI Nozzles RPV Closure Studs ChargingInletNozzles SDC Outlet Nozzle .
- Charging Inlet Nozzle Piping (2)
PZR Surge Nozzle > - Charging System Piping PZR Bottom Head & Support Skirt SG Tube-to-Tubesheet Weld (2)
PZR Spray System SG Secondary Shell(2)
~ Auxiliary Spray Piping SG Feedwater Nozzle (2)
\
Slide i19 98-037
f h
[ Life Cycle Management Project
}
Transients Monitored by FMP RCS Heatup
- RCS Cooldown
- PZR Heatup
- PZRCooldown 4 Reactor (RX) Trip
- Initiation ofShutdown Cooling
- Loss \ Recovery of Charging Flow
- Loss \ Recovery ofLetdown Flow
- Main Spray Actuation
- Auxiliary Spray Actuation
- Initiation ofAFW (each SG)
- Initiation of Safety Injection Loss ofSecondary Pressure Turbine Trip w Delayed RX Trip (U1 only) Loss of all RCS Flow !
R.CS Leak Test
- RCS Hydrostatic Test SG Leak Test SG Hydrostatic Test Seismic Safety Injection Check Valve Test *
(* Critical Transient Slide 120 98-037
Life Cycle Management Project FMP Stress Based Locations PZR Surge Nozzle SG 1 Feedwater Nozzle (4' Locations)
PZR Surge Line Elbow SG 2 Feedwater Nozzle (4 Locations)
Charging Inlet Nozzles (Both Nozzles) Hot Leg SurgeNozzle PZR Spray Nozzle ,
i i
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k Slide 12 V 98-037 5
Life Cycle Management Project FMP Specifics for FW Piping (continued) 1995 - BGE determined horizontal piping adjacent to t SG may have Thermal Stratification
- Thermal data collected during plant startup after 1995 refueling outage (Unit 2) i
- Found delta Ts up to 450 F top to bottom ofpipe Data Analyses
- Highest stressed location determined to be safe-end-to-reducer weld '
- Developed correlation between SG level and stratification -
activity
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[M Life cycie management Project FMP Specifics for FW Piping (continued)
Modified FatiguePro
- Added Four new locations per SG for each Unit to FatiguePro
- Stressed-based analyses (NB-3200) used to compute Fatigue Usage Past Fatigue Usage
- Extensive baselining performed to account for past usage
- Usage per hour of hot standby determined based on actual plant operation
- Determined hours ofpast hot standby operation
- Past usage is the product of past hours of hot standby operation and usage per hour of hot standby (Initial fatigue usage)
- Current fatigue usage is initial usage plus computed usage Slide 124 98-037
7 Life Cycle Management Project N
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Environmental Effects :
BGE participated in Industry Demonstration Project
- EPRI sponsored project
- Evaluated three systems Feedwater piping (including thermal stratification) n PZR surge line (including thermal stratification) .
Charging system piping Results show no changes needed to CCNPP FMP Report - Evaluation of thermal fatigue effects on systems requiring aging management review for license renewal for the Calvert Cliffs Nuclear Power Plant, EPRI TR-107515 ;
- Results presented to NRC on March 19,1998 Slide 125 98 037
y
[g Life cycie management Project
\
Map of FMP to SRP Requirements
)
siiac i2e)
/
Life Cycle Management Project !
Draft SRP Requirements - 1 Scope of program should include the specific structures and components subject to an aging management review for renewal.
BGE LRA: i
- Page 5.9-12, fourth paragraph and page 5.9-13, fifth paragraph identifies the horizontal FW piping adjacent to the SG nozzles as the fatigue critical location.
- Page 5.9-16, second paragraph states that the FMP includes these locations. ;
Slide 127j 98-017 l
I 7 [M Life cycie management Project Draft SRP Requirements - 2:
Preventive actions should mitigate or prevent aging degradation.
BGE LRA:
- Section 5.9, Group 2 of the LRA does not discuss preventive
, actions for the FMP because the FMP is a condition monitoring program.
'l Slide 128 ,98-037
f
[ Life Cycle Management Project Draft SRP Requirements - 3:
Parameters monitored or inspected should be linked to the degradation of the particular structure and component intended function (s).
BGE LRA: '
- Page 5.9-14, paragraphs 4 and 5 identify the parameters monitored to develop the FatiguePro algorithms used to calculate fatigue usage resulting from thermal stratification.
(
Slide 129 98-037 !
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[ Life Cycle Management Project Draft SRP Requirements - 4:
Detection of aging effects should occur before there is a loss of the structure and component intended function (s).
BGE LRA:
- Section 5.9, Group 2 of the LRA does not discuss detection of aging effects since the FMP does not detect the effects of fatigue (cracking), rather it monitors fatigue usage to enable the prediction of the onset of cracking.
Slide 130 l 98-017 !
Life Cycle Management Project Draft SRP Requirements - 5:
Monitoring and trending should provide predictability of the extent of degradation and timely corrective or mitigative actions. The monitoring, inspection, testing frequency, and sampling size should be appropriate for timely detection of aging effects.
BGE LRA:
- Page 5.9-15, paragraphs 3 through 5 discuss the FMP's monitoring / trending activities for both the bounding locations and criticaltransients.
- Corrective actions are discussed under Draft SRP Requirement 7 Slide 131 98-037
f
/ Life Cycle Management Project i Draft SRP Requirements - 7:
Corrective actions, including root cause determination and prevention and recurrence, should be timely.
BGE LRA:
- Page 5.9-15, paragraph 5 describes the FMP data tracking in accordance with the CCNPP QA Program, which meets ,
10CFR Part 50, Appendix B criteria.
- Page 5.9-15, paragraph 5 also describes the initiation of corrective actions by the FMP. ;
i t
1 Slide 133 98-037 '
7 Life Cycle Management Project Draft SRP Requirements - 8:
Confirmation process should ensure that preventative actions are adequate and that appropriate corrective actions have been completed and are effective.
i BGE LRA:
- Section 5.9, Group 2 of the LRA does not discuss :
confirmation processes or preventative actions for the FMP i because the FMP is a condition monitoring program. ,
- The confirmation process is built into the corrective action i process as discussed under Draft SPR Requirement 7. i Slide 134j 98-037 ,
Life Cycle Management Project Draft SRP Requirements - 9: '
Administrative controls should provide a formal review and approval process. i i
BGE LRA:
- Page 5.9-16, paragraph I describes the administrative control of the FMP.98-037 sue us]
/
[ Life Cycle Management Project
~
Draft SRP Requirements - 10:
Operational experience of aging management program, ;
including past corrective actions resulting in program ;
enhancement or additional programs, should provide objective evidence to support that the effects of aging !
will be adequately managed so that the structure and components intended function (s) will be maintained during the period of extended operation.
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I Slide 136 ;98-037
_________-____________-_-__--_________________-____--________]
Life Cycle Management Project Draft SRP Requirements - 10:
(continued) ,
BGE LRA:
- Page 5.9-11, last paragraph, page 5.9-12, paragraph 4, page 5.9-14, paragraphs 4 and 5, discuss operating experience associated with the FMP and corrections made to the program to address thermal stratification.
Slide 137j/
98-037
Life Cycle Management Project Construction of LRA 1.
CCNPP Specific AMR SLSR,CLSR Q-List UFSAR DWGs Plant Procedures, Tests, inspections NRC Documents Generic External Assessments EPRI Reports Standards ,
Codes ,
Textbooks i
Slide l38, j 98-037 I i
- _ _ - _ _ _ _ - _ _ - _ - _ - _ . _ - _ _ _ _ _ _ - _ _ _ _ - - - _ _ - - _ _ _ _ - - . - - _ _ _ _ _ _ __.