ML070790188

Listing of All Items NRC Region I Inspection of PNPS Various Pages Dated October 4 and 5, 2006 with Separate Pages for Lr# 569 and Lr# 536

ML070790188
Person / Time
Site:	Pilgrim
Issue date:	10/05/2006
From:	NRC Region 1
To:
References
Download: ML070790188 (38)

Text

NRC Region Inspection of PNPS All Hems -

Item Request Response Inspector Lead Category Update?

522 Provide any self assessments of the IS1 program or None Kaufman, Paul Pardee, Rich Closed No any related to the HPCl and IGSCC AMPs.

523 Provide system or program health reports for the Provided the requested reports to the Kaufman, Paul Mogolesko, Fred Closed No past 2 years for the ISI,HPCl and IGSCC AMPs. inspector.

524 Provide printout of LR data base for questions and Printout of LR data base questions and Kaufman, Paul Mogolesko, Fred Closed No answers on AMP. answers on AMPs (all) provided to the inspector by D. Ellis.

525 Provide projectlprogram owners for IS1 and the The list of program owners for the ISI, HPCl Kaufman, Paul Mogolesko, Fred Closed No HPCl and IGSCC AMPs. and IGSCC were provide to the inspector.

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526 The program description for the Heat Exchanger The Heat Exchanger MonitoringProgram Richmond, John Ivy, Ted Closed Yes Monitoring Program provides little detail regarding includes inspectionof a sample population the sample populationto inspect. Provide from a total of seventeen heat exchangers.

additional detail defining the sample to be used. Where practical, eddy current inspectionsof the tubes will be performed. The sample First week's inspection debrief item. populationof these heat exchangers will be determined based on the materials of constructionof the heat exchanger tubes and the associated environments as well as the type of heat exchanger (for example, shell and tube type). At least one heat exchanger of each type, material and environment combination will be included in the sample population. This ensures that potential impacts of different design, material and environment combinationswill be addressed.

This requires a change to the LRA.

LRA Section 8.1.15, attribute 4, Detection of Aging Effects, is revised as follows (bold words added).

4. Detection of Aging Effects [Note: all of this line bolded, database doesn't support bolding]

Loss of material is the aging effect managed by this program. Representative tubes within the sample population of heat exchangers will be eddy current tested at a frequency determined by internal and external operating experience to ensure that effects of aging are identified prior to loss of intended function.

Visual inspectionsof accessible heat exchangers will be performed on the same frequency as eddy current inspections.

An appropriate sample populationof heat exchangers will be determined based on operating experience prior to inspections.The sample population of heat exchangers will be determined based on the materials of constructionof the heat exchanger tubes and the associated environments as well as the type of heat exchanger (for example, shell and tube type). At least one heat exchanger of each type, material and environment combination will be included in the sample population. Inspection can reveal loss of material that could result in degradation of the Thursday, October 05,2006 5:15:02 P Page 2 of 35

Item Request Response Inspector Lead Category Update?

heat exchangers. Fouling is not addressed by this program. [Note: second sentence bolded in its entirety, database doesn't support bolding]

527 Identify any coolers associated with RHR and core A review of the Design Basis Documents and Richmond, John Ivy, Ted Closed No spray pumps that are not in the Heat Exchanger Aging Management Reports for the RHR and Monitoring Program. Identify additional AMPs for Core Spray and RBCCW systems did not those heat exchangers, if any. document any other heat exchangers that cooled RHR and Core Spray pump/motors besides those currently included in the Heat Exchanger MonitoringProgram. These are the RHR heat exchangers (E-207), and the Core Spray Pump Motor Thrust Bearing Oil Cooling Coils. The room cooler for the RHR and Core Spray areas are part of the HVAC system and are included in the Periodic Surveillanceand Preventive Maintenance program.

528 Provide list of CRs with condition description for A search of PCRS condition reporting Richmond, John Ivy, Ted Closed No heat exchangers in the Heat Exchanger Monitoring database was performed by performinga Program for the last 3 years. keyword search that included the all the available component IDS for the heat exchangers in the Heat Exchanger Monitoring program. For heat exchangers with no component ID the pump or EDG component ID was searched. The search documented 66 hits. However, only one was related to a heat exchanger in the Heat Exchanger monitoring program and a copy of the description of this CR was provided. This CR documented a QA finding during the closeout of an earlier CR.

529 Perform CR search on containment leaks CR search performedand the resulting CR OHara, Tim Williams, Murray Closed No search result list was provided to the inspector.

530 Provide copies of the last 3 completed ILRT Provided copies of the 1991, 1993, and 1995 OHara, Tim Williams, Murray Closed No Procedures. ILRT Procedure results. M.E. Williams 9119/2006 531 Provide the long term trend on ILRT results. Provided results to inspector. OHara, Tim Williams, Murray Closed No

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Item Request Response Inspector Lead Category Update?

532 Provide extension of ILRT submittal and RAI The ILRT extension was contained in License OHara, Tim Williams, Murray Closed No responses. Amendment 213. A portion of the related NRC SER (technical analysis with summary of the ILRT results from 1991, 1993, and 1995),

TS 4.7.A.4, EN0 2.4.027 (initial submittal),

and EN0 2.04.1 10 (response to RAI) was provided to the inspector. NOTE: No other RAls noted in the license amendment, and no type A ILRTs performed since 1995.

533 Provide the containment leak rate program Provided containment leak rate program OHara, Tim Williams, Murray Closed No document. documents to inspector.

534 1. Provide copies of NOP E l and M591. 1. Copies of both documents given to Richmond, John Lane, Ken Closed No inspector -9/20/06.

2. Provide list of PMs, surveillances and routine tasks performed on heat exchangers that are in 2. Summary sheet ("List of PMs currently the Heat Exchanger Monitoring Program but not in performed on components included in the the GL 89-13 program. Heat Exchanger Monitoring Program but not covered by GL 89-13 Program") was given to inspector - 9/20/06.

535 1. Provide the CR for HPCl drain line and any 1. Providedthe CR for HPCI drain line and Kaufman, Paul Mulcahy, Frank Closed No associated work requests. the associated work requests.

2. Provide HPCl maintenance rule report. 2. Provided report.

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536 Provide the following IS1 program documentation. 1. Done. Copies of all most recent FW OHara, Tim Pardee, Rich Open-NRC No nozzle exam data provided 1550 hrs 9/21 Reviewing 1.2003 RN nozzle exam data -- RAP 2. Done. Information provided by G. Mileris

2. PDC narrative for replaced FW spargers -- RAP 3. Done. Providedcopy of IS1 Program with

3. Copy of IS1 Program - RAP (DCC) latest DRN update.

4. Copy of Class 1 RlSl Program - RAP (DCC) -

4. Done. See #3 Included in IS1 Program

5. All 4th interval IS1 Program relief requests - RAP 5. Done. Reliefs included in #3, IS1 Program.

& W. LOBO (LIST OF RELIEF REQUEST Provided latest approval status of reliefs (by APPROVAL STATUS) W. Lobo)

6. Recirc system - how RlSl inspection points were 6. Done. Response for T. OHara providedto selected using risk-informedmethodology-- RAP Fred M. 9-25-06.

7.3 examples of how IS1 program has detected 7. See responseto #18 aging management issues in lasts 10 years: -- RAP 8. Done. Provided list from R. Miller

a. also how repairs were performed 9. Done. Copies provided all data 1550 hrs

8. CR search for any aging management issues, 9/2 1 IS1 or otherwise - RONN MILLER 10. Done. Provided most recent three SG

9. Torus IWE exam datasheets -- RAP Pinney reports (to be returned)

10. Torus SG Pinney reports - RAP & DAVE 11. Done. Provided procedure (from 0.

RYDMAN Rydman)

11. Torus recoating procedures (SG Pinney) - 12. Done. Provided Calc. M899 DAVE RYDMAN 13. Done. Provided Amendments 1,2 & 8

12. Torus analysis evaluating pit depths relating 14. Done. Provided response letter BECO 87-them to end-of-life - G. MlLERlS (REF. CALC M- 074 (from D. Ellis) 899) - ordered from DCC 15. Done. Response for T. OHara provided

13. Drywell support and Rx. cavity seal to Fred M. 9-25-06.

arrangement drawings - RAP (SEE AMENDMENT 16. Done. Provided completed sum.

8 SUBMITTAL) procedures from 2001, 2003 and 2006, with

14. GL87-05 response (drywell corrosion issue) -- CR and MR related to 2006 surveillance RAP testing.

15. Torus vent system vent bowl repair data and 17. Torus walk down was conducted on procedures -- RAP Tuesday @2;00 pm. Five CRs issued.

16. Last 2-3 surveillancesdone on Rx cavity flow 18. Done. Provided response for T. OHara switch FS-4803 (PNPS 8.E.19) -- RAP to Fred M. 9-27-06. Additional Information

17. Torus walkdown 2pm Tuesday 9/19/06 RAP -- requested on 10/06/2006. Additional

&JEFF KALB informationprovided below:

18. 3 examples of where IS1 program has previously addressed aging on class I piping. Three examples believed best met the criteria were given to the NRC on Monday October 2, 2006 A review of every IS1 and CR report for the last ten years was petformed to find instances of IS1 inspections identifyingaging issues in Class I systems. Only three examples meeting these criteria were found and all three were given to the NRC on Monday 10/2/2006. The reports were:

1. CR-PNP-2005-01982-identified a W crack and %" linear indication on lug fillet welds.

/tern Request Response Inspector Lead Category Update?

2. CR PNP-2005-01839 identified a loose nut.

3. PR99.1296-wear observed on pipe OD where it rubs on a support.

The IS1 engineer noted that the susceptible 304 SS Class I system piping was replaced in 1985, and most of the Class I systems are SS. As a consequence, the IS1 program identifies few if any aging problems in Class I piping. IS1 is a proven and industry accepted method for identifying aging effects in Class I piping systems.

Thursday, October 05,2006 5:15:02 P

Item Request Response Inspector Lead Category Update?

537 How does Pilgrim treat floor drains as part of As discussed in the PNPS Scoping Report Meyer, Glenn Ivy, Ted Closed NO license renewal. LRPD-01 the floor drains are included in the Radwaste system and the Plumbing and Drains system. The Radwaste system disposes of radioactiveand potentially radioactivewaste and the Plumbing and Drains system disposes of non process plumbing and drainage such as the roof drains.

The radwaste system has the following intendedfunctions for IOCFR54.4(a)(l).

Support maintaining secondary containment.

Support primary containment isolation.

The system has the following intended function for 10CFR54.4(a)(2).

Maintain integrity of nonsafety-related components such that no physical interaction with safety-relatedcomponents could prevent satisfactoryaccomplishmentof a safety function.

The floor drain portion of the radwaste system that are in scope for 54.4(a)(l) are reviewed in aging management reports AMRM-07 and AMRMQO. The portion included for 54.4(a)(2) which is included due to the potential for spatial interaction is reviewed in AMRMBO.

The Plumbing and Drains system has no intended functions for 10CFR54.4(a)(l) or W3).

The system has the following intended function for 10CFR54.4(a)(2).

Maintain integrityof nonsafety-related components such that no physical interaction with safety-relatedcomponents could prevent satisfactory accomplishmentof a safety function.

The portion of the Plumbing and Drains system included for 54.4(a)(2) is reviewed in AMRM-30.

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Item Request Response Inspector Lead Category Update?

538 How does Pilgrim treat crane and hoist boundaries For the large cranes (e.g. Reactor Building & Meyer, Glenn Kalb, Jeff Closed No for license renewal. Turbine Building cranes), the crane rails and girders are the structural boundary for license renewal. That is, the crane rails and girders are included as part of the Structures Monitoring Program. For the smaller jib cranes, hoists or monorails, no distinction is made for structural boundaries. The entire jib crane, hoist and monorail is included as part of the Structures Monitoring Program.

539 Provide a copies of the the following documents: Provided inspector with the following Johnson, Dante Bechen, Gerry Closed No documents:

1. The FAC 2005 self assessment. 1. the FAC 2005 self assessment;

2. The RFO #s 14 & 15 FAC summary reports. 2. the RFO-14 & RFO-15 FAC summary

3. The spreadsheet for RFO # I 5 UT results. reports:

4. Sheets HE, HE-1, GE & GE-1 from Spec M-300. 3. the spreadsheet for RFO-15 UT results; and

4. sheets HE, HE-I, GE, & GE-1 from Specification M-300.

540 On LRA drawing M-220 sheet 3 valve 31-CK-167 is Check valve 31-CK-167 is highlighted as Meyer, Glenn Chan, Laris Closed No shown as higlighted as in scope and subject to being in scope and subject to aging AMR but no other components on this drawing are. management review because it is a primary Why is this valve included and not the others. containment penetration isolation valve for containment penetration X-22. The LRA drawing indicates that the penetration number is X-22.

541 1. Provide all drywell support drawings. 1. Done. Provided requested drawings (L. OHara, Tim Pardee, Rich

2. Provide fibroscope inspection documentation Chan).

(1987) reference in LRA Amendment 2. 2. Done. LRA Amendment references the

3. Is the drywell joint sealing compound inspected inspection conducted in January 1987.

and what is the design life of the compound? Provided copy of Memo NDE87-20/QAD87-(Pardee/G. Dyckman - design info) 129 containing copy of inspection lR87-50-11-1

4. Provide ALL UT datasheets for ALL drywell -

conducted in January 1987 (1/14 15/87); also inspections. provided copy of inspection IRS87-1819

5. Provide procedure for drywell shell to floor joint conducted in November 1987 (11/21 &

inspection. 11/23/87). Information obtained by D.Ellis.

3. Externior drywell joint compound at sand cushion area is not routinely inspected due to access restrictions.

4. Done. Provided all IWE UT data of drywell shell, 1600 9/21

5. Done. Provided procedure ENN-NDE-10.03, PNPS 2.1.8.7 & Engineering Standard ENN-EP-S-001 1700 hrs 9/21 I Ip:

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Item Request Response Inspector Lead Category Update?

542 Provide copies of completed surveillances Information provided Lewis, Shani Burke, Steve Closed No referenced in AMPER Section 4.13.2.8.4.b, Para 2:

Fire suppression water system flush of distribution headers and fire hydrants at least once every 3 years and system functional and full flow tests at least once per operating cycle...

(Ref. 8.8.8; 8.6.12; 8.8.15; and Section 10.8.4.2.2, PNPS UFSAR)

Provide copies of completed procedures referenced in AMPER Section 4.13.1.8.4.b for Visual inspection and functional testing, at least once each operating cycle, of the cable spreading room Halon fire suppression system. (Ref. Attachments 1 and 4, 8.6.22 and Section 10.8.4.4.2, PNPS UFSAR) 543 Provide a sample of system health reports for the Provided the requested reports to the Lewis, Shani Landry, Mathieu Closed No fire protection system. inspector.

544 Provide copies of MRs on grout repair and Provided requested informationto the Chaudhary, Suresh Kalb, Jeff Closed No inspections of the torus wall. inspector.

545 Provide CRs on torus anchor bolt corrosion. Provided copies of the CRs on torus achor OHara, Tim Kalb, Jeff Closed No bolt corrosion and on water intrusion.

546 Provide details of the FW nozzle thermal sleeve Provided a copy of FW drawing M1B-45-1and Kaufman, Paul Mogolesko, Fred Closed No and modification package for installation. partial copies of PDCR79-41 that installed the sparger modifications. Also provided MR80-4587 that documents installion of PDCR79-41.

547 Instrument Air Quality Program 1. provided Richmond, John Rydman, Dave Closed No Provide the following information. 2. provided

1. Current revision of IA program procedure 3. Provided ISA 7.0 which is the standard used

2. SOER 88-01 4. provided

3. ISA 7.3 standard 5. provided

4. Trends of instrument air parameters sampled by 6. None identified the program

5. P&ID showing sample points

6. GE specification for air quality for HCUs, if any.

Item Request Response Inspector Lead Category Update?

548 The inspector requested copies of the following Provided the inspector with the requested OHara, Tim Gaedtke, Joe Closed No items: documents:

1. Provided requested P&IDs

1. Copies of P&ID's that cover the components 2. Provided reports included in the service water system and SW 3.Copies of test procedures and trend results integrity program. provided

2. Last six system health reports for SW. 4. Copies of tests provided

3. Copies of the Thermal test proceduresand the 5. Copies of three condition reports provided trend results for the last three tests on the RBCCW 6. There have been no thru wall leaks on heat exchangers. service water during the last five years. No

4. Copies of the last backwash and monthly informationprovided.

operability tests for RBCCW Hx. 7. Provided copy of inspection reportlvideo

5. Copies of three condition reports the document the effectiveness of the service water integrity program.

6. Condition report summary on service water leaks for the last five years.

7. Copy of last inspection report or video of underwater inspection of the SW bayshtake.

549 Do any IS1 program relief requests affect None of the IS1 relief requests impact OHara, Tim Gaedtke, Joe Closed No components included in the service water integrity components included in the service water program? integrity program.

550 Provide a copy of NRC letter 1.84.148. (This is the Provided a copy of NRC letter 1.84.148 to the Kaufman, Paul Mogolesko, Fred Closed No NRC SER of BWR RN & CRD return line mods at inspector.

Pilgrim).

551 Provide basis for operabilityassociated with CR Provided the basis for operability associated OHara, Tim Mogolesko, Fred Closed No 2006-03479. This CR is similar to CR-2006-1879. with CR 2006-03479 to the inspector.

(Corrosion of torus anchor bolt baseplate assemblies)

Thursday, October 05, 2006 5:15:02 P

/tern Request Response lnspector Lead Category Update?

552 Heat Exchanger Monitoring Program Provided copy of Amendment 8 sections Richmond, John Cox, Alan Closed No showing response to audit question 503.

Provide copy of LRA amendment showing changes in response to TLAA audit question (#503). Provided copy of audit questions 503 and 506 with responses.

Provide copy of associated audit questions involving TLAA for heat exchangers in the Heat Heat exchangers in this program that rely on Exchanger Monitoring Program. other AMPs for managing cracking are the following.

Provide list of heat exchangers in this program that rely on other AMPs for managing cracking. (Post-Amendment8 )

RHR and RHR pump seal cooler heat exchangers (AMRM-02) E207A&B and E203A,B,C,D.

Water Chemistry Control - BWR manages cracking due to SCC/IGA.

One-Time Inspection manages cracking due to fatigue.

Thursday, October 05, 2006 5:15:02 P ge?T*f3<

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Item Request Ins ector Lead Cate o Update?

553 LRPD-02, Section 4.17.B.3.a, quotes from NUREG- PNPS uses a screening analysis of lubricating Richmond, John Cox, Alan Open-NRC No 1801 stating, For components that do not have oil samples. The analysis is used to detect Reviewing regular oil changes, viscosity, neutralization degraded lubricating oil or abnormal wear in number, and flash point are also determined to lubricated machinery. It is used as a verify the oil is suitable for continued use. In screening tool to identify the presence of addition, analytical ferrography and elemental moisture, abnormal wear products, and analysis are performed to identify wear particles. changes in oil chemistry associated with The PNPS oil analysis program appears to be thermal degradation. Results of the screening different from this statement in that a screening analysis are evaluated by a predictive analysis is used to determine the need for analysis maintenance engineer, who compares them to determine some of these parameters. Please with prior results and determines if more explain. Provide justification for differences from detailed analysis is necessary. An off-site the NUREG-1801 program description if laboratory is contracted to perform the more appropriate. detailed analysis.

First weeks inspection debrief item. NUREG-1801 XI.M39, LubricatingOil Analysis, Parameters Monitored/lnspected states, For components with periodic oil changes in accordance with manufacturers recommendations, a particle count and check for water are performed to detect evidence of abnormal wear rates, contaminationby moisture, or excessive corrosion. For components that do not have regular oil changes, viscosity, neutralization number, and flash point are also determined to verify the oil is suitable for continued use. In addition, analytical ferrography and elemental analysis are performed to identify wear particles.

Analytical ferrography and elemental analysis are diagnostic tools used to identify wear particles if the particle count is high.

Therefore, for components that do not have regular oil changes NUREG-1801 recommends that the following parameters be monitored on a regular basis.

1. particle count

2. water content

3. viscosity

4. neutralizationnumber

5. flash point As the screening tool identifies the presence of moisture, abnormal wear products, and changes in viscosity, the first three parameters are monitored on a regular basis at PNPS. If off-site analysis is necessary following the Thursday, October 05, 2006 5:15:02 P

Item Request Response Inspector Lead Category Update?

screening, the samples are analyzed for neutralizationnumber and fuel dilution in addition to the other parameters. The PNPS program is not strictly consistent with NUREG-1801 because neutralizationnumber and flash point (or fuel dilution See Note 1) are not monitored for every oil sample. This inconsistencyis justified because the parameters monitored regularly (presence of moisture, abnormal wear products, and changes in viscosity) are those directly related to age-related degradationof components containing lube oil. As noted in the Mechanical Tools , aging effects are not observed in fuel oil and lubricatingoil systems unless moisture or other contaminants are present. Therefore, continuous monitoring and trending of particle count, water content and viscosity in lubricating oil provides reasonable assurance that the effects of aging will be managed such that applicable components will continue to perform their intended function consistent with the current licensing basis for the period of extended operation.

(Note 1. As indicated in LRA Amendment 5, PNPS measures the % fuel dilution in diesel engine oils which is a more acurate method than flash point for identifying fuel leaks and oil dilution.)

This requires an amendment to the LRA.

LRA Section 8.1.22 is amended as follows (underlined words added, strike-outs deleted)

NUREG-1801 Consistency The Oil Analysis Program at PNPS is consistent with the program described in NUREG-1801,Section XI.M39, LubricatingOil Analysis, with exceptions and enhancements.

Exceptions to NUREG-1801 The Oil Analysis Program at PNPS is consistent with the program described in NUREG-1801,Section XI.M39, LubricatingOil Analysis with the following exceptions.

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Attributes Affected - Exception

3. Parameters Monitoredlnspected- Flash point is not determined for sampled oil (See Note 1).

3. Parameters Monitoredllnspected -

Neutralization number and fuel dilution are not monitored for every oil sample. (See Note 2)

(Note 2: Non Class I mechanical Implementation Guideline and Mechanical Tools, Revision 4, EPRl 1010639,January 2006, Appendix C, "Oil and Fuel Oil")

1. Analyses of filter residue or particle count, viscosity, total acidbase (neutralization number), water content, and metals content provide sufficient information to verify the oil is suitable for continued use.

2. The parameters monitored regularly (presence of moisture, abnormal wear products, and changes in viscosity) are those directly related to age-related degradation of components containing lube oil. As noted in the Mechanical Tools, aging effects are not observed in fuel oil and lubricating oil systems unless moisture or other contaminants are present. Therefore, continuous monitoring and trending of particle count, water content and viscosity in lubricating oil provides reasonable assurance that effects of aging will be managed such that applicable components will continue to perform their intendedfunction consistent with the current licensing basis for the period of extended operation.

Enhancements The following enhancements will be initiated prior to the period of extended operation.

Attributes Affected1Enhancements

1. Scope of Program The Oil Analysis Program will be enhanced to periodically change CRD pump lubricatingoil.

A particle count and check for water will be performed on the drained oil to .detect evidence of abnormal wear rates, 0

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contamination by moisture, or excessive corrosion.

3. Parameters Monitoredllnspected Procedures for security diesel and reactor water cleanup pump oil changes will be enhanced to obtain oil samples from the drained oil. Procedures for lubricating oil analysis will be enhanced to specify that a particle count and check for water are performed on oil samples from the fire water pump diesel, security diesel, and reactor water cleanup pumps.

6. Acceptance Criteria The Oil Analysis Program will be enhanced to proceduralizethe acceptance criteria and corrective actions described in this program description.

Item #589 includes the commitment to perform periodic sampling of the parameters per LRPD-02, Section 4.17.B.3.a.

Close this item to #589.

554 In response to license renewal audit question # The fuel dilution test for diesel fuel oil is Richmond, John Carrol, W Closed No 213, PNPS stated that percent fuel dilution is performed on Pilgrim Diesel Engines X-107A determined in lieu of flashpoint. Please provide B, and X-166 in accordance with the original documents that direct completion of the percent contract agreement with the lube oil analysis fuel dilution determination. lab. The flash point is also analyzed however, the fuel dilution test is a better test and it is used when preventive maintenance engineer reviews test results. On site lube oil screening and laboratory results are compared to the acceptance criteria guidelines provided on the engineering equipment reliability used oil analysis web page. The acceptance criteria for diesel lube oil testing were derived from the ALCO Owners Group recommendations and EPRl predictive maintenance templates for diesel lube oil analysis.

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Rem Request Response Inspector Lead Category Update?

555 Provide a list of components from AMRM-30 that As shown in LRA Table 3.3.2-14-35, Turbine Richmond, John Cox, Alan Closed No credit the Oil Analysis Program. Generator and Auxiliary System Nonsafety-Related Components Affecting Safety-Related Systems Summary of Aging Management Evaluation, the following components credit the Oil Analysis Program for aging management. None of the other (a)(2) tables credit the Oil Analysis Program. For each item in the following list, the environment is lube oil and the aging effect is loss of material.

Component Type Material Filter housing Carbon steel Heat exchanger (shell) Stainless steel Heater housing Carbon steel Orifice Carbon steel Orifice Stainless steel Piping Carbon steel Pump casing Carbon steel Sight glass Carbon steel Sight glass Copper alloy ~ 1 5 %Zn Strainer housing Stainless steel Tank Carbon steel Thermowell Carbon steel Thermowell Stainless steel Tubing Copper alloy 4 5 % Zn Tubing Stainless steel Valve body Carbon steel Valve body Stainless steel AMRM-30, Aging Management Review of Nonsafety-related Systems and Components Affecting Safety-relatedSystems, indicates that the oil-filled components in this system includethose in the turbine generator oil system and the reactor recirculationpump MG set oil system. (Reference P&IDs M210, M221 sheets 1 and 2, M226 sheet 2, M271, M274, and M275.)

Attachment 3 of Procedure3.M.4-17.4, Lubrication Sampling and Change Procedure, shows that turbine generator oil is sampled at the bearings, the clean oil storage tank, the dirty oil storage tank, and the oil conditioner.

Attachment 3 of Procedure 3.M.4-17.4, Lubrication Sampling and Change Procedure, also shows that MG sets are Thursday, October 05, 2006 5:15:02 P Page 16 of 35

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sampled at the oil coolers.

556 Provide proceduresthat accomplish lube oil a. RBCCW Richmond, John Carrol, W Closed No sampling and analysis for the following. The RBCCW pumps P-202A-F have a yearly lube change with no sample. PNPS plans to

a. RBCCW add sample requirementfor consistency with other ENN plants.

b. Diesel fire pump

b. Diesel fire pump

c. Security diesel The diesel fire pump PM procedure 3.M.4-123 takes oil samples for analysis once per every two years per the PM procedure

c. Security diesel The security diesel PM procedure 3.M.3-23.1 changes the oil on a 2year frequency however an oil sample for analysis is not required Copies of referencedprocedureswere provided to inspector.

557 1. Provide qualification test prodedure to qualify 1. Provided qual test procedure and summary OHara, Tim Rydman, Dave Closed No underwater coatings used in the torus for coating of test results for torus coatings to the repair. inspector.

2. Provide the frequency for re-inspectingthe 2. Informationwas provided to inspector.

coating repaired areas in the torus

3. VHS tapes of the 2003 torus dive

3. Provide the most recent torus dive inspection inspections were provided to the inspector.

tapes (2003) for the inspector.

4. No, there have been no tests.

4. Has any testing been performedto demonstrate hat torus coating repairs arrest further corrosion underneaththe repaird area.

558 Provide copies of CR for the radiator housing of the provided Meyer, Glenn Collis, Tom Closed No SBO diesel and on the roof leak for the SBO enclosure.

559 While touring the Aux Bay "B", the inspector CR-PNP-2004-01107 addressing a similar OHara, Tim Chan, Lark Closed No observed a security guard opening the watertight incident for the watertight door (for a longer door and leaving it open. The inspector was period of time) was provided to the inspector.

informed that there was a CR previously written The CR addresses leaving the door open addressing this. The inspector requested a copy of temporarily.

the CR i

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Item Request Response Inspector Lead Cafegory Updafe ?

560 Provide copies of drawings showing underground Copies of drawings showing underground OHara, Tim Bechen, Gerry Closed No piping for the systems included in the Buried Piping piping for systems in the Buried Piping and and Tanks Inspection Program. Tank Inspection Program were provided to the inspector.

561 Perform a CR search covering the past 5 years on CR search performedand the resulting CR OHara, Tim Mogolesko, Fred Closed No leaking underground pipe and tanks. search result list was provided to the inspector.

563 Provide copies of recent system health reports for Provided copies of recent system health Chaudhary, Suresh Kalb, Jeff Closed No system 56 (structures). reports for system 56 to the inspector.

564 Provide copies of recent maintenance rule Provided copies of recent maintenance rule Chaudhary, Suresh Kalb, Jeff Closed No walkdown reports for system 56 (structures), walkdown reports for system 56 to the inspector.

565 The fire pump diesel day tank is not included in the Richmond, John Burke, Steve Closed Yes scope of the diesel fuel monitoring program. The Sampling of the contents of the fire pump inspector requested the basis for not includingthis diesel day tank was not included in the diesel tank since the fuel oil in the tank may not be fuel monitoring program because the program representativeof the EDG storage tanks due to ensures the quality of the oil being supplied to lack of fuel oil turnover. Is the amount of fuel used the tank (from the EDG storage tanks).

in this tank during fire pump diesel testing adequate However, the fuel oil in the EDG storage tanks to ensure the fuel oil is representativeof that may not be representativeof the oil in the fire contained in the EDG storage tanks such that pump diesel day tank.

additional monitoring is not required.

Therefore, to ensure that significant loss of First week's inspection debrief item. material is not occurring, the Diesel Fuel MonitoringProgram will be enhanced to include periodic ultrasonic thickness measurement of the bottom surface of the fire

'pump diesel day tank. The first ultrasonic inspectionof the bottom surface of the fire pump diesel day tank will occur prior to the period of extended operation, following engineering analysis to determine acceptance criteria and test locations. Subsequent test intervals will be determined based on the results of the first inspection.

This requires a change to the LRA. LRA Commitment 38.

Thursday, October 05, 2006 5:15:02 P

Item Request Response Inspector Lead Category Update?

566 The enhancement to sample the securtiy diesel fuel The enhancement to sample the security Richmond, John Potts, Lori Closed Yes oil storage tank only requires a sample for water diesel fuel oil storage tank should provide the content? What is the basis for only sampling for same level of monitoringfor this tank as that water and should any other parameters be provided for the other storage tanks to ensure included? the quality of the oil and preclude aging ,

effects. Therefore, the enhancement is revised to state the following.

The Diesel Fuel Monitoring Program will be enhanced to include quarterly sampling of the security diesel generator fuel storage tank.

Particulates(filterablesolids), water and sediment checks will be performed on the samples. Filterable solids acceptance criterion will be = 10mg/l. Water and sediment acceptance criterion will be = 0.05%.

This requires a change to the LRA.

567 Provide copies of the ASTM analysis standards Provided. Richmond, John Smalley, Paul Closed No used for analyzing fuel oil in the EDG and SBO storage tanks.

568 Provide copies of fuel oil data trends for water & Provided. Richmond, John Smalley, Paul Closed No sediment, Cetane, and particulates for the past two years.

569 The buried piping and tanks inspection program in This statement was meant to indicate OHara, Tim Ivy, Ted Closed Yes section 4.b contains a statement that Prior to verification that an inspectionoccurred within entering the period of extended operation , plant the ten years prior to entering the period of operating experience will be reviewed to verify that extended operation. If an opportunistic an inspection occurred within the past ten years. inspectiondid not occur, a focused inspection No explanation is provided as to what will be done if would be performed prior to the period of an inspection has not occurred prior to the period of extended operation. This point will be clarified extended operation. by insertingthe following after the third sentence of Section 3.1.B.4.b of LRPD-02.

First weeks inspection debrief item.

If an inspectiondid not occur, a focused inspectionwill be performed prior to the period of extended operation.

570 Provide copy of CR for sprinkler valve leak (valve 4- A copy of the CR (#PNP-2006-03550) was Lewis, Shani Burke, Steve Closed No S-89)in RB. provided to the inspector.

Thursday, October 05,2006 5:15:02 P Pagt?=1$*f35a

Item Request Response Inspector Lead Category Update?

571 The following questions are associated with joint Information provided. OHara, Tim Pardee, Rich Open-NRC No sealing compounds (JSC) on drawing C-71. Reviewing

1. Provide a copy of the JSC installation specification.

2. Provide information on service life of the JSC.

3.How is the integrity of the JSC inspected?

First week's inspection debrief item.

572 Provide copy of the Main Stack Inspection Report Provided copy of the Main Stack Inspection Meyer, Glenn Mogolesko, Fred Closed No from 6/2004 (Ref 5.81, LRPD-05). report dated 6/9/04.

573 The inspector noted that the existing Pilgrim The inspector's comment is noted. Entergy Chaudhary, Suresh Kalb, Jeff Closed No Structures Monitoring Procedure (NE 8.02) is not N.E. is developing a fleet wide procedure for adequate relative to providing details for record structures monitoring (ENN-DC-150). At the keeping and trending of concrete cracks noted time of the inspection, this procedure was still during walk downs of Pilgrim structures. in draft form undergoing final review by the N.E. plant sites. ENN-DC-150has provisions First week's inspection debrief Item. which are much more detailed in the areas of walkdown documentation, record keeping and trending of results than what was in the Pilgrim procedure NE 8.02. When implenented later this year, or early next year, the procedure will greatly enhance the structures monitoring program at Pilgrim.

A copy of this draft ENN procedure was provided to the NRC inspector.,

Thursday, October 05, 2006 5:15:02 P Pag/iO'of3;

Item Request Response Inspector Lead Category Update?

574 Provide the basis for concluding that water has not A series of four drains protects the drywell OHara, Tim Dyckman, Gary Open-NRC No entered the sand pocket during past operation of outer surface against leakage from the Reviewing PNPS given the following. refueling cavity.

1. sealant condition unknown 1. Refueling bellows leakage detection drain

2. drain line alarm test failure of 12/28/05 line - A flow switch (FS-4803) monitors for leakage through this 3 drain line. The flow alarm was found nonfunctioningin December 2005. The previous successful test of the alarm was in 2003. RFO 15 was in spring of 2005. Assuming the alarm was failed during RF015, leakage, if any, would have been indicated at the W tell-tale drains described in Item 2.

2. A W tell-tale drain indicates leakage into each of four 8 casings that surround the 2 refueling bellows cavity drains. Blockage of the 3 drain line described in Item 1 allows leakage to enter the 8 casing where it would be indicated by leakage from the W tell-tale drain at a funnel on Elevation 74. These drains exist at four locations. During daily tours, operators have never detected leakage from these tell-tale drains.

3. Top of sand pocket drain. If leakage is not detected from the W tell-tale drains before the four 8 casings fill up and water rises above the % thick form plate that surrounds the ledge, leakage can overflow into the air gap.

A sheet metal plate shields the top of the sand pocket against leakage from above. A series of four 4 drain lines direct water from the top of the sheet metal plate to the torus room floor at Elevation -17. Operators monitor for abnormal conditions during rounds. These drains are also checked by IS1 VT-2 certified inspectors for leakage twice every refuel outage, once after flooding up and again prior to flooding down. No leakage has ever been detected from these drains at PNPS.

4. Sand pocket drains. Drains at the bottom of the sand pocket remove leakage, if any, that enters the sand pocket. Because the drain lines are filled with sand at the sand pocket, visual verification that the lines were unobstructedcould not be done. With no past indications of leakage, corrosive conditions that could lead to drain line obstruction are not Thursday, October 05, 2006 5 3 5 0 2 P Pagg2?kof35

item Request Response inspector Lead Category Update?

expected to have existed. In addition, the drains are 2 lines which are large enough to make blockage due to corrosion unlikely.

CR-PNP-2006-3677written to improve the monitoring for corression.

575 In the nonsafety attached to safety review of The approach used for scoping and screening Meyer, Glenn Ivy, Ted Closed No AMRM-30 Attachment 4 for the compressed air of components for 54.4(a)(2) for nonsafety-system A4.1 states that the components include related SSCs directly connected to safety-bolting, piping, tubing and valves. On LRA drawing related SSCs is a two pronged approach as LRA-M-220sheet 2 at G- 7 there is a nonsafety line described in the PNPS LRA sections connected to safety related piping that connects to 2.1 .I .2.2. The first is to identify those an air dryer and compressor. The air dryer and nonsafety-relatedcomponents within the compressor are not listed as being in scope for structural boundary that are required to nonsafety attached to safety. Since a bounding provide structural support to the safety-related approach was used should the dryer and pressure boundary. The second approach is compressor have been included? to use the bounding approach from NE1 95-10 Appendix F if the structural boundary cannot be identified. At PNPS the structural boundary is quite often indicated on Piping and Instrument drawings thru the use of seismic class 1 boundary flags. These flags indicate the end of the seismic class 1 evaluation such that components downstream are not required to provide structural support.

If these flags were not provided then the bounding approach was used to ensure the first seismic anchor was included.

On LRA drawing LRA-M-220 sheet 2 at G- 7 there is a seismic class 1 boundary flag at valve 31-HO-507 that indicates that the components downstream of this flag are not required to provide structural support. This would include the air dryer and compressor.

Therefore these components are not included in the table 3.1.2 of AMRMSO or LRA table 3.3.2-14-2.

CLOSED TO ITEM # 586.

P Thursday, October 05,2006 5:15:02 P

Item Request Response inspector Lead Category Update?

576 In AMRM-30 attachment 4 section A4.1 for the The vent and drain piping shown on LRA-M- Meyer, Glenn Ivy, Ted Closed No RBCCW system it states that although the majority 215 sheet 2 were included as part of the of the system is already included in AMRM-12, the Radioactive waste system (20) since all of piping that interfaces with the seismic piping near these lines terminate at Radioactive waste the chemical addition tanks requires aging drains. When performingthe aging management review per 54.4(a)(2) for structural management review, these lines were support of safety-relatedcomponents. On drawing conservatively assumed to contain fluid such LRA drawing LRA-M-215 sheet 2 there are many that they were included for potential spatial vent and drain lines off of components in the interactiondue to spray or leakage. As a result RBCCW system. Are these components in scope they did not need to be included as part of the and subject to aging management review for nonsafety attached to safety review in nonsafety attached to safety and if so where are Attachment 4 of AMRM-30. However, this they included. was not clearly described in section 3.1.26 of AMRM-30 and will require a revision to the following sentence in section 3.1.26 with the revision shown in bold.

The liquid filled nonsafety-related components in the system (which conservativelyincludes vent and drain lines that periodicallycontain fluid) whose failure could affect safety-relatedequipment requires aging management review per 54.4(a)(2) due to potential spatial interaction.

These vent and drain lines are included in the PNPS LRA in Table 3.3.2-14-23 as carbon steel and stainless steel piping with an internal environment of untreated water due to the potentialfor exposure to radwaste drainage.

The aging effects will be managed by the Periodic Surveillanceand Preventive Maintenance program and the One Time Inspectionprogram. Therefore a change to the LRA is not required.

CLOSED TO ITEM # 586.

Thursday, October 05, 2006 5:15:02 P PaggZ$of3<

Item Reauest ResDonse InsDector Lead Cateaorv UDdate?

577 Please provide the following information: 1. A copy of the current Pilgrim license Johnson, Dante Ivy, Ted Closed No renewal commitment list was provided to the

1. A current copy of the PNPS commitment list inspector.

showing the enhancement to the system walkdown program. 2. Copies of 4 sample condition reports

2. Copies of a sample of condition reports documenting OE with the system walkdown documentingoperating experience with the system program and the identificationof aging effects walkdown program and the identificationof aging were provided to the inspector.

effects.

3. Provide an explanation of the terms category A 3. Provided applicable pages out of and B as shown in EN-DC-178. procedures EN-DC-178 and EN-DC-143 which explains category 1 & 2. The terms category 1 & 2 replacedthe terms category A

& B.

578 Provide 2 separate copies of procedure 8.M.1-3 Provided 2 separate copies of the Lewis, Shani Das, Swapan Closed No completed surveillance. surveillances completed under 8.M.1-3.

579 Provide copies of repetitive task and last 2 MRs Providedc a copy of Rep Task #P002065. Lewis, Shani Das, Swapan Closed No related to man hole inspections. Also provide one Provided copies of 2 MRs from past MR for an upcoming inspection. inspections and one for an upcoming inspection.

580 1. Provide system walk down plan for RCIC. 1. The system walkdown plan for RCIC was Johnson, Dante Sullivan, Brian Closed No provided ot the inspector.

2. Provide system monitoring plan for HPCI.

2. The system monitoring plan for HPCI was provided ot the inspector.

Thursday, October 05,2006 5:15:02 P

/tern Request Response inspector Lead Category Update?

581 Describe how the main stack foundation is included This area is considered innaccessible under Chaudhary, Suresh Kalb, Jeff Closed Yes in the SMP. Maintenance Rule criteria and is not included in periodic maintenance rule structural inspections because of the difficulties of gaining access to the area. PNPS will perform a one-time inspection of the main stack foundation prior to the period of extended operation.

This requires a revision to the aging management program evaluation report (AMPER), LRPD-02.

This requires an amendment to the LRA.

This is commitment #39 Commitment #39:Include main stack foundation in the One-Time Inspection Program.

Implementation Schedule: June 8, 2012 Source: Letter 2 . 0 6 . M Related LRA Section No. Comments:

B. 1.23/ltern 581 582 The inspector requested copies of 25 selected CRs Copies of the 25 selected CRs were provided OHara, Tim Bechen, Gerry Closed No on buried piping and tanks. to the inspector.

I S  %%we=-

Thursday, October 05,2006 5:15:02 P

Item Request Response Inspector Lead Category Update?

583 LPRD-02 in the one time inspection section does In Attachment 2 of LRPD-02, scope (Attribute Richmond, John Cox, Alan Open-NRC Yes not list AMRM-02 (RHR) or AMRM-12 (RBCCW) 1) of the one-time inspectionactivity for LRPD- Reviewing yet the table the RBCCW heat exchanger is listed. 06, Time-LimitedAging Analyses -

Additionally, in AMRM-12 there are additional heat Mechanical Fatigue will be corrected as exchangers in scope (e.g., RWCU regen and recirc follows (bold words added, strike-outs pump seal cooler) that are not listed in AMRM-30 deleted)by adding RHR seal cooler heat which is referenced in LPRD-02. exchangers (tubes) and recirculationpump seal water coolers (tubes). The entry for RBCCW heat exchanger will be removed since this heat exchanger operates at temperatures below the thresholdfor fatigue..

Non-pipingcomponents without metal fatigue analysis.

RHR heat exchangers (shell and tubes)

RHR seal cooler heat exchangers (tubes)

RHR pump casings HPCl turbine casing RClC turbine casing RBCCW heat exchanger Recirculationpump seal water coolers (tubes)

Heat exchanger shells, pump casings, tanks, and turbine casings susceptible to fatigue cracking, listed in AMRM-30, Nonsafety-related Systems and Components Affecting Safety-relatedSystems.

The other heat exchangers in AMRM-12, Aging Management Review of the Reactor Building Closed Cooling Water System, are not subject to cracking due to thermal fatigue since their temperature remains low.

The list of aging management review reports crediting the One-Time Inspection Program in .

LRPD-02 Section 3.7.A will also be corrected as follows (bold words added).

by adding the following to the list.

This program is credited in the following.

AMRM-02, Residual Heat Removal System AMRM-05, High Pressure Coolant Injection System AMRM-06, Reactor Core Isolation Cooling System AMRM-12, Reactor Building Closed Cooling Water System The table in the program description of LRA Thursday, October 05, 2006 5:15:02 P

Item Request Response Inspector Lead Category Update?

Section B.1.23 will be revised to add a line for verifying the absence of cracking for miscellaneousitems not covered by a fatigue TIAA. The first column will read, Inspection for mechanicalfatigue The second column will read, One-time inspectionactivity will confirm that cracking due to fatigue is not occurring or is so insignificantthat an aging management program is not warranted.

This change requires an amendment to the LRA.

AMRM-07, Standby Gas Treatment System AMRM-27, Condensate Storage AMRM-30, Nonsafety-relatedSystems and Components Affecting Safety-relatedSystems AMRM-33, Reactor Coolant System Pressure Boundary Thursday, October 05,2006 5:15:02 P Page 27 of 35

Item Request Response Inspector Lead Categury Update?

584 What is the manufacturersrecommended service For Field Coating, Tapecoat Co. 7C Cold OHara, Tim Bechen, Gerry Open-NRC No life for coating and wrapping that has been applied Prime and CT Tape Coat were applied. Reviewing to buried piping in accordance with PNPS Specification M306? The Tapecoat Company was contacted.

Conversations with Katie Simon (847-866-8500) yielded the following: TC Cold Prime was discontinued quite a while ago. In general, the Tapecoat products used are not expected to become degraded over time when properly applied.

From Tapecoat Company Information:

Tapecoat 8 CT - Cold Applied Tape CoatingITAPECOAT CT - a 35 mil cold-applied tape coating with a 7 mil polyethylene film backing and 28 mils of adhesive, for ambient temperature below grade application.

Appropriate for coating small to moderate size pipe with a single layer; a 50% overlap may be preferred when coating larger diameter pipe.

Buried Pipe Coating Warranties The coating product alone does not establish the expected service life of a protective coating system. Additional factors such as surface cleanliness, surface preparation, and severity of service (soil conditions) also play a large roll in expected service life. Since the manufacturer does not control applications he does not predict expected service life Thursday, October 05,2006 5:15:02 P

Item Request Response Inspector Lead Category Update?

585 New torus questions; 1. OHara, Tim Mogolesko, Fred Open - Plant No Action

1. Provide basis for the repair criteria of 30 mils . 2. The min wall thickness for the torus is

2. What is torus minimum wall thickness? found on page 83 of 86 of calc M-899 and

3. What is manufacturer's recommended service ranges by node number. A copy of calc M-life for the torus coating? 899 was provided to the inspector. See

4. What is torus coating material? response to question 15 below.

5. What are the coating degradation mechanisms (root cause of pitting)? 3. Review of Manufacturer's Product Data

6. How often is the torus coating inspected? Sheets

7. How much degradation of the coating was A review of the product data sheet for CZ-11 recorded from RF012 to RF014? does not provide any guidance on the

8. What is the criteria for re-inspectionof repaired manufacturers expected service life. The pits? coating product alone does not establishthe

9. What is the pit gauge pin diameter? expected service life of a protective coating

10. Provide back-up for PDCR 99.1 145 inoperable system. Additional factors such as surface designation for torus. cleanliness, surface preparation, and severity

11. Does Pilgrim have any non-repaired torus of service also play a large roll in expected wetted wall test areas? service life and since the manufacturerdoes

12. What is deepest pit found to date? not control applications he does not predict

13. What are the total number of pits found to expected service life.

date?

14. When was torus re-coated? Coating Warranties

15. Provide a copy of calculation M-899. Coating systems may be warranted by the

16. Provide a copy of CB&l original design calc for application contractors for a length of service the drywell (contract #9-8014, 1968). which is generally less than the expected length of service for the level of controls applied during the coating application. The coating system expected service life for a case where inspections and repairs are not pursued after initial installation will be much shorter than the case where follow-up inspectionsand repairs are employed.

4. Pilgrim Torus Interior Coating The date of application of the existing coating is approximately 1981. Carbo Zinc 1 1, as manufactured by Carboline, is a self- curing inorganic zinc primer. The coating acts to sacrificially protect the submerged surfaces on the interior of the Torus, should the coating become breached.

Pilgrim applies an inspection and repair program to the Torus interior coating. The inspectionprogram monitors the condition of the protective coating. With the inspection and repair of failed local areas of Torus coating the expected service life of the coating is not currently limited to a specific time value Thursday, October 05,2006 5:15:02 P

/tern Request Response Inspector Lead Category Update?

but, by virtue of the ability of inorganic zinc to form a passive oxide layer, could reasonably be expected to last 30 to 60 years.

Corrosion defects of limited depth (pits) may be directly repaired in accordance with a qualified underwater repair system. If the corrosion defects exceed a pre set value they require evaluation under the Corrective Action Process as well as repair. The corrective action process will determine the appropriate evaluation and resolution of conditions that exceed limited depth conditions.

Application of an inspection and repair program assures that the Torus will be maintained in accordance with the design requirements and perform acceptably in service.

5. Coating

Description:

The immersed coating, in the Torus, is Carbo-zinc 11, a sacrificial coating, manufactured by Carboline. The dry film coating is comprised of 86% zinc, in the form of flakes, held together by a resin binder, which orient themselves parallel to the steel surface. In immersionservice, a zinc salt (zinc oxide) layer forms on the wetted surface of the coating, which is a very tenacious protective barrier, and seals the wetted surface. A properly applied coating over a properly prepared steel substrate, will last a long time in immersion service. Failure of the coating to protect the steel occurs when the zinc pigments no longer maintain an electrolytic coupling to the steel, or are depleted. The fact that the water in the torus is de-ionized means that it is less chemically aggressive toward the zinc, and improves the longevity of the coating.

Coating DegradationMechanisms:

When the zinc salt layer is subjected to mechanical damage, the outer layer of zinc depletes away and the next lower layer forms a new protective barrier of the zinc salt.

Opportunities for corrosion to form include:

Mechanical damage, which exposes the underlying steel substrate to oxygen in the water.

Improper surface preparation, such as failure Thursday, October 05,2006 5:l 502 P PagB300?35@

lfem Request Response lnspecfor Lead Category Update?

to completely remove any existing oxidation or prior coatings, before the new coating application.

Improper maintenance of the prepared surface, which allows oxidation to form prior to coating.

Improper coating application, which results in pinhole-size voids in the coating, through which water and oxygen can make contact with the steel.

INFORMATION ON TORUS COATING The as-found condition of the torus shell as of RFO-12 and RFO-14 contained the following types, and surface areas, of degradation:

DEGRADATION MECHANISM - RFO 12 DEGRADED SURFACE AREA RFO 14 -

DEGRADED SURFACE AREA Localized Corrosion and Mechanical Damage - 164 sq. ft/4228 Locations -E159 sq.

ft 6438 Locations

-

Tiger Striping 386 sq. ft - 391 sq. ft Coating Rust Through - 407 Locations - 482 Locations

-

Total as-found corrosion area 550 sq. ft. -

550 sq. ft.

Repaired corrosion area - 41.75 sq. ft. - 56.74 sq. ft.

This data shows that the as-found degraded surface area during RFO 12 was about the same as the as-found degraded surface area during RFO 14. One notable observation is that the number of locations, where degradation was found, increased by approximately 50%.

At the beginning of RFO 12, the average Dry Film Thickness (DFT) of the coating was approximately 7.0 mils (minl max 3.1 / 15 mils). RFO 14 data indicates an unappreciable reduction in DFT.

The threshold for coating repairs is any pitting corrosion identified, in the base metal of the vessel that exceed 32 mils in depth. During RFO 12, after desludging, 1 1 0 pits were found 833 Thursday, October 05, 2006 31502 P eir37Of35

/tern Request Response Inspector Lead Category Update?

that exceeded 32 mils. During RFO 12, 840 repairs were made. The repairs were made to the pits that exceeded 32 mils and where areas of rust through of the inorganic zinc coating were identified directly adjacent to underwater epoxy repairs applied during previous outages. Because surplus time was available after the required repairs were completed, additional repairs were made, to other corroded areas where the pits did not exceed 32 mils in depth. This resulted in a total coating repair of 41.75 square feet.

During RFO 14, after desludging, 63 pits were found that exceeded 32 mils. This reduction in identified pitting was attributed to the extra repairs made during RFO 12. During RFO 14, 504 repairs were made. This resulted in a total coating repair of 56.74 square feet. This time, the repairs were confined only to pits that exceeded 32 mils and where areas of rust through of the inorganic zinc coating was identifieddirectly adjacent to underwater epoxy repairs applied during previous outages. There was no surplus time to make additional repairs during RFO 14.

6. The torus coating is 100% inspected every 2nd refuelingoutage. The coating was last inspected durnig RFOl4.

7. See response to subpart question 5 above.

8. See response to subpart question 6 above.

9. The gage used is a Starrett Model No. 643 dial depth indicator gage.

This gage has a knife-edge base and a needle point contact which has been hardened and ground. The knife-edge base has a cutout so that the conical point can be precisely positioned for close work. Point is 1/2" (12.7 mm) long with a 40" included angle.

In action, the inspector gently pushes the point down to read zero with the base and then pushes down to make the needle point contact the workpiece to take the measurement. Gage features a Starrett No.25-131 AGD Dial Indicator.

Lx Thursday, October 05,2006 5:15:02 P

Item Request Response Inspector Lead Cafegory Update?

A copy of the page from the gage vendor manual containing the above description and showing an exploded view of the gage was provided to the inspector.

I O . Requested informationwas provided to the inspector.

11.

12.

13.

14. The torus was re-coated around 1981.

15. A copy of CB&l Calc M-899was provided to the inspector.

16. A copy of the original design calculation for the drywell was provided to the inspector.

Thursday, October 05,2006 5:15:02 P

/tern Request Response Inspector Lead Category Update?

586 During the review of components included the Attachment 4 to AMRM-30 identifies the Meyer, Glenn Ivy, Ted Closed Yes aging management review report AMRM-30 Aging component types that are subject to aging Management Review of Nonsafety-relatedSystems management review and the drawings that and Components Affecting Safety-relatedSystems include these component types. It does not it appears that Attachment 4 does not provide list the specific components or sufficiently sufficient detail and guidance to determine the explain the criteria used to determine which actual components that need to be included in the components were included for the nonsafety assigned aging management programs. How will attached to safety review. This information is the site be able implement the programs needed to needed to ensure that the aging management manage the components aging effects with the programs for these components can be current guidance provided in AMRM-30? implemented. In order to provide sufficient detail to accomplish aging management program implementation, AMRMBO will be revised to either provide a descriptionof the nonsafety-related components subject to aging management review in the systems reviewed in Attachment 4 or provide a descriptionof the specific criteria used to determine the components subject to aging management review in Attachment 4 that would allow independent determinationof the appropriate components to include in the applicable aging management programs .

Confirmationof the screening results included in Attachment 4 to AMRM-30 will also be performed as part of this effort using the appropriatecriteria.

Additionally the change to AMRMBO in item 576 needs to be performed.

587 The NRC inspector discovered a typographical CR PNP-2006-03683 was written. A review Lewis, Shani Cox, Alan Closed No error in the Pilgrim elevtrical screening and aging was performed that determinedthe error has management report (AMRE-01). (A reference was no effect on the intent of AMRE-01. In made to J.A. FitzPatrick, rather than Pilgrim). addition, the license renewal application has been verified to not contain the same error.

588 Provide lists of cranes in scope of license renewal. Provided Attachment 2 of Procedure 3.M.1-14 Meyer, Glenn Cox, Alan Closed No AMRC-04 refers to lists in procedures3.M.1-14 and and Attachment 7 of Procedure 3.M.7-5.

3.M.7-5.

Thursday, October 05, 2006 5: 15:OZ P Page 34 of 35

Item Request Response Inspector Lead Category Update?

589 The PNPS Oil Analysis Program is not defined in Prior to the period of extended operation, the Richmond, John Cox, Alan Closed Yes controlled documents. In addition, periodic PNPS Oil Analysis Program will be enhanced sampling is not performed for all of the parameters by documenting program elements 1 through identified under the Parameters 7 in controlled documents. The program Monitored/lnspectedattribute of NUREG-1801, elements will include enhancements identified Section XI.M39, Lubricating Oil Analysis. in the PNPS license renewal application and subsequent amendments to the application.

The program will include periodic sampling for the parameters specified under the Parameters Monitoredlnspectedattribute of NUREG-1801,Section XI.M39, Lubricating Oil Analysis. The controlled documents will specify appropriate acceptance criteria and corrective actions in the event acceptance criteria are not met. The basis for acceptance criteria will be defined.

This requires an amendment to the LRA and will be a new commitment to enhance the PNPS program.

Thursday, October 05,2006 5:15:02 P Pag23&f3$

LR REQUEST LR# 5 69 NRC Inspector OHara, Tim LR Text The buried piping and tanks inspection program in section 4.b contains a statement that Prior to entering the period of extended operation , plant operating experience will be reviewed to verify that an inspection occurred within the past ten years. No explanation is provided as to what will be done if an inspection has not occurred prior to the period of extended operation.

First weeks inspection debrief item.

LR Response This statement was meant to indicate verification that an inspection occurred within the ten years prior to entering the period of extended operation. If an opportunistic inspection did not occur, a focused inspection would be performed prior to the period of extended operation. This point will be clarified by inserting the following after the third sentence of Section 3.1 .B.4.b of LWD-02.

If an inspection did not occur, a focused inspection will be performed prior to the period of extended operation.

&

L 17 Support Cox, Alan Cateaorv Open - NRC Reviewing Wednesday, October 04, -3006 Page I of I

• LR REQUEST LR# 536 NRC Inspector O'Hara, Tim LR Text Provide the following IS1 program documentation.

1.2003 FW nozzle exam data -- RAP

2. PDC narrative for replaced F W spargers -- RAP

3. Copy of IS1 Program - RAP (DCC)

4. Copy of Class 1 RISI Program - RAP (DCC)

5. All 4th interval IS1 Program relief requests - RAP & W. LOBO (LIST OF RELIEF REQUEST APPROVAL, STATUS)

6. Recirc system - how RISI inspection points were selected using risk-informed methodology --

RAP 7.3 examples of how IS1 program has detected aging management issues in lasts 10 years: --

RAP

a. also how repairs were performed

8. CR search for any aging management issues, IS1 or otherwise - RONN MILLER

9. Torus TWE exam datasheets -- RAP

10. Torus SG Pinney reports - RAP & DAVE RYDMAN 1 1. Torus recoating procedures (SG Pinney) - DAVE RYDMAN

12. Torus analysis evaluating pit depths relating them to end-of-life - G. MILERIS (REF. CALC M-899) - ordered from DCC

13. Drywell support and Rx. cavity seal arrangement drawings - RAP (SEE AMENDMENT 8 SUBMITTAL)

14. GL87-05 response (drywell corrosion issue) -- RAP

15. Torus vent system vent bowl repair data and procedures -- RAP

16. Last 2-3 surveillances done on Rx cavity flow switch FS-4803 ( P N P S 8.E.19) -- RAP

17. Torus walkdown 2pm Tuesday 9/19/06 -- RAP & JEFF KALB 18.3 examples of where IS1 program has previously addressed aging on class I piping.

LR Response 1. Done. Copies of all most recent F W nozzle exam data provided I550 hrs 9/2 1

2. Done. Information provided by G. Mileris

3. Done. Provided copy of IS1 Program with latest DRN update.

4. Done. See #3 - Included in IS1 Program

5. Done. Reliefs included in #3, IS1 Program. Provided latest approval status of reliefs (by W.

Lobo)

6. Done. Response for T. O'Hara provided to Fred M. 9-25-06.

7. See response to #I8

8. Done. Provided list from R. Miller

9. Done. Copies provided all data 1550 hrs 9/21

10. Done. Provided most recent three SG Pinney reports (to be returned) 1 1. Done. Provided procedure (from D. Rydman)

12. Done. Provided Calc. M899

13. Done. Provided Amendments 1,2 & 8

14. Done. Provided response letter BECO 87-074 (from D. Ellis)

15. Done. Response for T. O'Hara provided to Fred M. 9-25-06.

16. Done. Provided completed surv. procedures from 2001,2003 and 2006, with CR and M R related to 2006 surveillance testing.

17. Torus walk down was conducted on Tuesday @2:00 pm. Five CRs issued.

18. Done. Provided response for T. O'Hara to Fred M. 9-27-06. Additional Information requested on 10/06/2006. Additional information provided below:

Tliursday, October 05, 2006 Page 1 of 2

Three examples believed best met the criteria were given to the NRC on Monday October 2, 2006 A review of every IS1 and CR report for the last ten years was performed to find instances of IS1 inspections identifying aging issues in Class I systems. Only three examples meeting these criteria were found and all three were given to the NRC on Monday 10/2/2006. The reports were:

1. CR-PNF-2005-01982- identified a W crack and W linear indication on lug fillet welds.

2. CR PNF-2005-01839 identified a loose nut.

3. PR99.1296-wear observed on pipe OD where it rubs on a support.

The IS1 engineer noted that the susceptible 304 S S Class I system piping was replaced in 1985, and most of the Class I systems are SS. As a consequence, the IS1 program identifies few if any aging problems in Class I piping. IS1 is a proven and industry accepted method for identifying aging effects in Class I piping systems.

Lead 21 Suuuort Woods, Steve Category Open - NRC Reviewing Tliursday, October OS, 2006 Page 2 of 2