ML091480767

License Renewal Commitments Inspection, Exit Meeting - Dec 23, 2008, Rev 10a

ML091480767
Person / Time
Site:	Oyster Creek
Issue date:	12/23/2008
From:	NRC Region 1
To:
References
FOIA/PA-2009-0070
Download: ML091480767 (7)

Text

Oyster Creek License Renewal Commitments Inspection Exit Meeting - Dec 23, 2008 at 9 am G:\DRSXEngineering Branch 1\ LicRenewal\Oyster CreekX2008 Outage\lnReview\OC LRI 2008-07 Exit Notes rev-10A.doc Information in public domain for which a question or issue can be raised or it wasn't exactly stated that way but the issue remains the same as being in the public domain

Introductions

• NRC Region 1

• NRC HQ

• NRC Residents

• AmerGen

• NJ DEP (Observers)

Excellent Overall Cooperation from everybody

>>> use of the Certrec Internet Database was quite helpful Special Thanks 9 Pete Tamburro (LR Program Owner)

" Chris Hawkins (NDE Level-Ill)

" Cal Taylor & Jhansi Kandasamy Inspection Schedule Slippage

• LR outage schedule slipped due to unexpected issues

. Some NDE UTs re-scheduled, due to unanticipated physical interference issues

• As a result, our inspection ran into a 2nd on-site week and a 3rd in-office week Documentation Team Report 45 days after the Exit Meeting (early Feb)

Review of Regulatory Framework

[Darrell Roberts]

Existing Part 50 -- Current Licensing Basis Prt*--*c/* l ltranir -- Oa#I a 1/#1.

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Pending Part 54 Decision on License Renewal and License Obligations PQe-'dcistnalntrrnatian ""OfficbUt U ly OC LRI 2008-07_Exit Notesrev-10A.doc 2 of 7 Updated 12-22-08

Exec Summary of Inspection Results

• Because the application for a Renewed License remains under Commission review for final decision -- With respect to proposed SER commitments:

" No assessment of implementation or effectiveness will be documented

" Factual Based Observations of activities will be documented

• Inspection observations were considered, in light of:

" Part 50 existing requirements (e.g., CLB)

• Pending Part 54 commitments

" Programmatic performance under on-going implementation of Part 50 requirements

• The conclusions of PNO-1-08-012 remain unchanged

• Reviewed 2 change packages for proposed activities described in SER App-A

" A summary of the change will be documented

" The Exelon commitment management program is an existing CLB program. The implementation of this existing program provided adequate administrative controls.

Unresolved Item

• An Unresolved Item (URI) will be opened to evaluate whether existing current licensing basis commitments were adequately performed and, if necessary, assess the safety significance for any related performance deficiency.

• The issues for follow-up include the strippable coating de-lamination, reactor cavity trough drain monitoring, and sand bed drain monitoring.

• The commitment tracking, implementation, and work control processes will be reviewed, based on corrective actions resulting from AmerGen's review of deficiencies and operating experience, as a Part 50 activity.

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Key Inspection Observations Six Key observations will be Documented For the Six Key Observations:

• Regarding AmerGen's activities to perform proposed LR commitments, the NRC will review AmerGen's operating experience review and corrective actions, as appropriate, as part of the scheduled March 2009 IP 71003 Inspection.

Strippable Coatinq De-lamination

From Oct 29 to Nov 6,

• On Nov 6, the

• AmerGen identified several likely or contributing causes

• A portable water filtration unit was improperly placed in the reactor cavity, which resulted in flow discharged directly on the strippable coating

" An oil spill into the cavity may have affected the coating integrity

" No post installation inspection of the coating had been performed

• AmerGen stated follow-up UTs will re-evaluate the drywell shell next outage Cavity Trough Drain Line Found Isolated

• On Oct 27, the drain line was isolated to install a tygon hose to allow drain flow to be monitored

• On Oct 28, the reactor cavity was filled

• Drain line flow was monitored frequently during cavity flood-up, and daily thereafter

• On Oct 29, a boroscope examination identified the drain line isolation valve had been left closed

• When the drain line isolation valve was opened, about 3 gallons of water drained out, then the drain flow subsided to about an 1/8 inch stream (< 1 gpm)

Drain Flow Monitoring Plan o AmerGen stated a calculation determined cavity trough drain flow of less than 60 gpm would not result in trough overflow into the gap between the drywell shield wall and the drywell shell

• AmerGen had a pre-approved Action Plan for monitoring cavity & sand bed drains

• Per the Action Plan --

" Ifdrain flow > 5 gpm, then monitor every 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />

" Ifdrain flow > 12 gpm, then monitor sand bed poly bottles every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />

" Ifdrain flow > 12 gpm and water found in sand bed poly bottles, then enter & inspect sand beds edlY Noesolf e7pd POrLdIcisn2a0 8f-04_aEtxn OC LRI 2008-07_ Exit Notes_ rev-110A. doc of 7 Updated 12-22-08 3

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0 0 Increased monitoring of trough drain to 2-hr and sand bed poly bottles to 4-hr (not req'd by Action Plan) 0 On Nov 8, workers inside sand bed bay 11 identified dripping water 0 Subsequently, 0

0 Sand bed bays were originally scheduled to have been closed by Nov 2 0 On Nov 15, after cavity was drained, water was found in sand bed bay 11 poly bottle Sand Bed Drain Poly Bottles Not Connected

• Sand bed drains were remotely monitored by checking poly bottles, attached via tygon tubing to funnels hanging below the drain lines

• The drains were not directly observed

• After the reactor cavity was drained, 2 of the 5 tygon tubes were found disconnected, laying on the floor

• Sand Bed Bay 11 drain poly bottle was empty during each daily check until Nov 15 (cavity was drained on Nov 12), when it was found full (> 4 gallons). Bay 11 was entered, visually inspected, and found dry.

0 Directly observed conditions of the drywell shell epoxy coating in selected sand bed bays 0 NRC reviewed VT-1 examination records for each sand bed bay, and directly inspected 7 bays 0 Observed AmerGen's activities to evaluate the epoxy coating Sand Bed Bay 11 Blisters

• Observed activities to evaluate and re air blisters found in Ba 11

• 1 small 1/4 inch broken

• unbroken blisters were identified by the NRC., during initial investigation

• All 4 blisters were within a 1-2 inches square area, and all were evaluated and fixed

• For extent of condition, 4 bays re-inspected by different NDE level-Il

• -- AmerGen reported that

" AmerGen estimated corrosion of - 3 mils had occurred over about a 16 year period Sand Bed Bay 9 Coating Deficiency 0 AmerGen identified and fixed a area approximately 8" x 8" that appeared to NOT have had all 3 layers of the epoxy coating applied.

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• Directly observed conditions of the drywell shell moisture barrier in selected sand bed bays

• NRC reviewed VT-1 examination records for each sand bed bay, and directly inspected 7 bays

• Observed AmerGen's activities to evaluate the moisture barrier

• AmerGen identified deficiencies in 7 of the 10 sand bed bays, including

• Surface cracks

• AmerGen determined the moisture barrier function was not impaired, because no cracks or separation fully penetrated the seal. All deficiencies were repaired.

2006 Inspection Did Not Identify Any Seal Cracks

• During 2006 seal inspections, no deficiencies were identified

• Observed AmerGen perform drywell shell UT thickness measurements

• Observed AmerGen evaluate the UT data (2000 separate UT readings)

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• AmerGen did not identify any on-going corrosion or corrosion trend, based on the UT examinations

• AmerGen did not identify any statistically significant deviations from 2006 UT data values As a Reminder -- For these Six Key Observations

• Regarding AmerGen's activities to perform proposed LR commitments, the NRC will review AmerGen's operating experience review and corrective actions, as appropriate, as part of the scheduled March 2009 IP 71003 Inspection.

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No Noteworthy Observations Protective Coating Monitoring and Maintenance Program

• D/W Interior Service Level I Coating Electrical Cables and Connections

• Drywell Cable Inspections Inaccessible Medium Voltage Cables

• Cable Test - as part of the Doble Test on Auxiliary Transformer (bank 4)

Buried Piping

• ESW Pipe Replacement and Tie-in Structures Monitoring Program

• Intake tunnel and expansion joints One-Time Inspection Program

• Isolation Condenser Inspection and UT below the water line Periodic Inspection Program

• Condensate System expansion joint inspection

• Fire barrier inspection inside a switchgear Metal Fatigue Program

• No changes to the high cumulative usage factor components list Looking Forward -- Next Steps -- Closing Comments

[Rich Conte]

ANY QUESTIONS for US P-/eci ona)/Infrm/tio/1-- OfrciU OYi OC LRI 2008-07 Exit Notes_rev-IOA.doc 7 of 7 Updated 12-22-08