ML20245C928
| ML20245C928 | |
| Person / Time | |
|---|---|
| Site: | Summer  |
| Issue date: | 11/02/1987 |
| From: | Hopkins J Office of Nuclear Reactor Regulation |
| To: | Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 8711040232 | |
| Download: ML20245C928 (16) | |
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' DISTRIBUTION. ... :7 . f - l'J See attached sheet ~ ',i
- LICENSEE::-SouthCarolina:Electricand. Gas-Company _.m(:
4 4 g e y . qc. m 5 FACILITY:.:V.jC.; Summer NucleaE. Station. r a <<[ 1
SUBJECT:
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SUMMARY
0F AUGUST 5, 198 MEETING'WITH'SOUTHCARblINAELECTRIC .i LAND? GAS: COMPANY ]( 7 3.c, 4 I: <
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< r; 4 4 y# -i tl '4' 1 GENERAL / f 4 l wi w, l0n August'5,-1987, thE NRCLstaff met With the South CarolintpElectric and' Gas - 'y 4 w &panyc(SCE&G)ltortour the site and~to discuss technical issues. The meeting. ._.( Com v. heldat'the"V.!C. Summe,r Nuclear Station'. A 1,ist:of'tpose persons 'who. J i i Latfl ended t k meeting-is incieded'as Enclosure 1. ?., h,, l a .w {rM, ' D, . j ', i-m ~ 1 ,; DISCUSSION.C y,' e J. 1 t. e: mThe agenda:.;forjthe meetingfis [inci ded'as. EndkAare 2 Vu-graph _s used'at the r a, 4 . meeting are. included.asLEnclosure 3.- Discussion was focused on the - ~ f' .,<g , - l !:information'in.the vu-gfaphs.. 1 r a }Q 3., i Id d j. 'j. g j I L
- JonB.Hopkirls>,"ProbetManagerD T
' Project Directoratejil-l s Division'of)lReactorp Projects - 1/II' J. }' NT'
Enclosures:
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mg u. m r - 1 gf j 8 i %! [1 ' ;/ ^ .Ll,{!I -J Enclosure'2-3 ;!.3 V' lNRC PROJECT DIRECTORATE 1 i !s q-AND PROJECT MANAGER VISIT - L AGENDA' j. p;[' e. ' AUGUST 5,1987 ll ,.-h: ~ '0830 introductions Ollie Bradham: ' Third Refueling Outage Accomplishments Jack Skolds Steam Generator Program Phil Troy l.l; Generic Letter 87-02, RHR 1/2 Pipe Gene' Soult ? Operations . McGuire Reactor Trip Breaker Incident Mike Quinton . Impact on V. C. Summer Nuclear Station l 7 1000 Plant Tour R. L. Prevatte i y 1200; Lunch Nuclear Training 3 Center l A 1330l ' Nticlear Training Center and Randy Ruff 1 Simulator Tour. i N , Environmental and Dosimetry Lab Tour Bill Baehr x .s 1 dAction Item List John Connelly Mike Williams AlPagha ) 4 n 's' 1 4' ~ sj E 'A l _j 'l ~ g.f'
k i CAUSE OF OUTAGE DELAYS 9 1. Overall Activity Levels in systems higher than anticipated. i i 2. Thermocouple conoseal leak required partial draining of the RCS. 3. 1000 Lugs in the ESF Load Sequencer cabinets i required relugging and a complete retest of the Sequencer. l 4. Sheared stem on RCS RTD Bypass Manifold required ) a second cooldown and depressurization. S. Seal Injection Line leak required a third cooldown 3 and depressurization. ) 6. Scope of outage increased significantly once it started. t
MAJOR THIRD' REFUELING ACCOMPLISHMENTS 1.' 76 Plant Modifications Completed - 16: Appendix "R" - 8 Reg Guide 1.97 - 16 Reliability and Performance improvements - 36 ALARA, Safety and Other Improvements 2. Improved Reliability of Steam Generators 3. Performed Ultrasonic inspection (UT) of Two Phase Flow Piping i 4. Performed Feedwater Piping Inspection (Surry) I 5. Inspected Fuel and Core Barrel for Baffle Jet Impingement
- 6. Cleaned Feedwater and Condensate Systems (Oil) l l
7. Detailed Inspection of Main Condenser for Signs of Wear and Erosion 8. Installed Live Load Packing in Critical Valves I 9. Upgraded Steam Generator Hydraulic Snubbers 4 l
- 10. Overhauled One RC Pump Motor l
- 11. Rebuilt Seals in Two RC Pumps
- 12. Chemically Cleaned and Inspected Reactor Building Coolers j
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- 13. Cleanup and Painting Effort l
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. _ _ - _ _ _ = _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 THIRD REFUELING ACTIVITY AND MANHOUR
SUMMARY
4 The following is a summary of work activities tracked by CHAMPS. TYPE OF NUMBER OF MANHOURS % OF TOTAL ACTIVITY ACTIVITIES EXPENDED MANHOURS STPs 2832 20,324 11.3 PMs 3677 19,231 10.7 MWRs 1935 69,418 38.5 MRF/MWRs 1016 71,343 39.5 i TOTAL 9460 180,316 100 1 I Total Estimated Manhours = 111,000 l l
CONCLUSIONS: e All known preventative measures for PWSCC have been implemented in Hot leg Tube Sheet SCE&G understands and can predict corrosion rate. e Unclear if PWSCC has been cured, but clearly improved SG status. i e Need to continue F* like effort on Leak before break technology - Moisture carryover
i i CORROSION RATE l e SCE&G has developed statistical models to predict corrosion rate. e Last Outage Results BEST BEST WORST SG ACTUAL CASE EST. CASE A 9 19 64 71 B 42 66 152 118 C 19 33 91 71 l l
l ~ u OBSERVATIONS - l l e Scope For B&W To Date e Successfully Worked 3 SG's in
- Parellel, Sometimes.Both Channel Heads On Each SG Scheduled Processes Such That Set-up Tear-Down i
e Minimized, Optimum Flexibility e Outage Successful Based Upon Coordinated Planning and SCE&G Management Commitment 'To Complete Tasks on Schedule i
L l' .I PLUG REMOVAL i e Returned 24 Tubes To Service o Plugs Removed By TIG Relaxation e 10 W Ribbed 38 B&W Rolled U-Bend Stress Relief i e All Row-1 and Row-2 In A/C SG's n e Row-2 B SG i e 5 Row-1's in B SG ) i i i
PLUGGING MARGIN o Broad Front Effort F* Fo Flow Margin 1 LOCA Reanalysis e Future New LOCA Codes (BASH) Leak Before Break i I l i l 4 J
- 9.~ Changes as a result of this review may be grouped in categories as i follows: ) 1 . A. Procedural-l l 1 L 1.' Additional guidance will be added to GOP-10 and SOP-115 to:
- a. proce'duralize the methodology of initially reducing flow and.
monitor running pump amps to prevent vortexing.
- b. if vortexing is evident, align the idle train of l
RHR to the RWST and commence filling the RCS to recover t Reactor Vessellevel 1 2.' Review ARP's to add precaution if RHR pump trip is due to vortexing; . then do not start the standby pump, proceed by aligning the standby pump to the RWST per SOP-115. l
- 3. Proceduralize, using the mass balance inventory of the RCS when plant conditions allow.
- 4. Perform testing of RVLIS versus standpipe levelincluding the phenomenon of " moving air around' affecting level and adding RVLIS to i
operator's shutdown shift logs. 1
- 5. Revise EOP 2.4 to address setting containmentintegrity on loss of RHR and the RCS is open to the Reactor Building.
- 6. Update RHR or RCS DBD to include half pipe operations.
- 7. Provide a Technical Specification interpretation on Mode 5 RHR Flow Rate.
B. Hardware changes (Modifications)- 1
- 1. Hard piping the tygon levelindicators at horizontal runs to prevent inadvertent level indication spikes due to obstructions.
- 2. Temporarily install remote monitoring device for Reactor Vessel standpipe level indication.
C. Training - Provide training to operators prior to scheduled half-discussing industry problems and corrective actions. pipe operations l 1
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- 2. CONTROL AND INDICATION AVAILABLE TO THE OPERATOR MCB INDICATION '
RHR Pump Amps 0 500/330/10 amp increments .RHR Flow 0-5000 gpm/100 gpm RHR Heat Exchanger inlet - 50-400 *F/10'F q i RHR Heat Exchanger Outlet 50 400*F/10'F .l i RHR Pump _ Discharge Press 0-700 psig/10 psig - I RCS WR Press 0 3000 p,sig/50 p,sig 0 600 psig/10 psi RVL15 NR 0-120 %/2 % UP 64-120 %/109.3 %/2 % l MCB ALARMS ( XCP-610): Pump Trip SW/ Breaker Mismatch RHR Loop Flow Low 2200 gpm with Breaker Closed Dish Press High - 550 psig l j COMPUTER POINT ALARMS: Parameter High Alarm Low Alarm RHR Flow 4500 gpm 2400 gpm RHR Pump Breaker Open RHR Hx Outlet Temp 345*F 55'F RHR Pump Outlet Temp 345 F 55*F RCS Wide Range Pressure 2300 psig 325 psig PRT Pressure 7 psig 2.6 psig i incore TC's 635 522.5 l Tygon Tube B Loo] Intermediate Leg to Pzr Steam I Samp e Line, Markings are permanently on the wallin the RB. t
~ V. C. SU M M ER o REACTOR TRIP BREAKERS (RTBs) l.D. LOCATION CYCLES q 1 i RT-1 Shop 02140. i:8L3) RT-2 RT-A 02153 (4/87) RT-3 RT-B 01354 ll4/87) RT-4 BY-B 01338 ll4/87) ) RT-5 BY-A 00239I:8-3)
..e McGuire and Catawba RTBs at Westinghouse for inspection / evaluation ie Inspected RT-17/87; no visible deficiencies e Last inspected RT-2,-3,-4 and -5 4/87; due 10/87 l e Electrical Supervisor to observe Catawba RTB inspection i e WOG previouslyidentified potential problem with RTBs due to excessive cycling
- Current semi-annual surveillance test cycles the RTB 30 to 40 times e Furtherinvestigation pending Westinghouse Evaluation / inspection results
I. 1 ) MEETING
SUMMARY
DISTRIBUTION i;
- 1Doicket?No(s)A50-395?mt NRC PDR l
Local PDR PD II.1 r/f. E. Adensam. -Attorney, 000 P. Andersott E. Jordan- 'J. Partlow-ACRS (10) ~ t Project Manager Jon B. Hopkins l ) 1 -NRC' PARTICIPANTS J. Hopkins E..Adensam' [ B. Mozafari .1 l .R. Prevatte .P. Hopkins I l I l l cc: Applicant & Service List l i l ___}}