ML15120A389

Lr Hearing - Draft Telephone Call Summary

ML15120A389
Person / Time
Site:	Indian Point
Issue date:	04/30/2015
From:	Office of Nuclear Reactor Regulation
To:
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Download: ML15120A389 (17)

Text

IPRenewal NPEmails From: Wentzel, Michael Sent: Thursday, April 30, 2015 1:36 PM To: Louie, Richard (rlouie@entergy.com)

Subject:

Draft Telephone Call Summary Attachments: 043015, Summary of Telephone Conference Call Held Between NRC and Entergy Concerning the RAIs Pertaining to the Indian Point LRA Safety Review.docx

Rich, Attached is a draft of the phone call summary for call earlier today. We agreed to revise the wording in RAI 3.0.3-3 based on the concern raised on the call. Also, I wanted to confirm that a 90-day response time works for us. Please let me know if you have any comments. Also, if you could provide me a list of Entergys participants, I would appreciate it.

Thanks, Mike Michael Wentzel Project Manager NRR/DLR/RPB2 (301) 415-6459 michael.wentzel@nrc.gov 1

Hearing Identifier: IndianPointUnits2and3NonPublic_EX Email Number: 5128 Mail Envelope Properties (C0A338EE37A11447B136119705BF9A3F02881643E977)

Subject:

Draft Telephone Call Summary Sent Date: 4/30/2015 1:36:02 PM Received Date: 4/30/2015 1:36:03 PM From: Wentzel, Michael Created By: Michael.Wentzel@nrc.gov Recipients:

"Louie, Richard (rlouie@entergy.com)" <rlouie@entergy.com>

Tracking Status: None Post Office: HQCLSTR02.nrc.gov Files Size Date & Time MESSAGE 552 4/30/2015 1:36:03 PM 043015, Summary of Telephone Conference Call Held Between NRC and Entergy Concerning the RAIs Pertaining to the Indian Point LRA Safety Review.docx 102259 Options Priority: Standard Return Notification: No Reply Requested: No Sensitivity: Normal Expiration Date:

Recipients Received:

UNIT TED STATES S NUC CLEARREGU ULATORY CO OMMISSION N WASHING GTON, D.C. 205555-0001 LICENSE EE: Enterggy Nuclear Operations, O Inc.

FACILITY Y: Indian n Point Nucle ear Generating Unit Noss. 2 and 3 SUBJEC CT: SUMM MARY OF TELEPHONE E CONFERE ENCE CALL HELD ON APRIL30,A 20 015, BETW WEEN THE U.S. U NUCLE EAR REGUL LATORY CO OMMISSION AND ENTE ERGY NUCL LEAR OPER RATIONS, IN NC. CONCER RNING THE E DRAFT REQU UEST FOR ADDITIONA A AL INFORMA ATION FOR THE REVIE EW OF THE INDIAAN POINT NUCLEAR GENERATING G UNIT NOS S. 2 AND 3, LICENSE RENE EWAL APPL LICATION, SET S 2015-01 1 (TAC NOS S. MD5407 ANDA MD540 08)

The U.S.. Nuclear Re egulatory Co ommission (N NRC) staff and represen ntatives of Enntergy Nucleear Operations, Inc., (Enntergy)held a telephone conference call on April 30, 2015,to discuss and d clarify the e NRC staffs request foor additional information (RAI) conce erning the Indian Point Nuclear Generating G Unit U Nos. 2 and a 3 licensse renewal applicationsa afety review.

Enclosurre 1 providess a listing of the participaants and Enclosure 2 co ontains a listing of the RAAIs discusse ed with Enterrgy, includingg a brief desscription of thhe status.

Entergy had h an oppo ortunity to coomment on this t summaryy.

Michael We entzel, Project Manager Projects Braanch 2 Division of License L Rennewal Office of Nuuclear Reacttor Regulatioon Docket Nos.

N 50-247 and 50-286 Enclosurre:

As stated d cc w/enccl: Listserv

• concurrence via e-mail OFFICE LA:DLR PM:RPB2:DLR BC:RPB1:DLR PM:RPB2:DLR NAME MWentzel YDiaz MWentzel DATE

SUMMARY

OF TELEPHONE CONFERENCE CALL HELD ON APRIL30, 2015, BETWEEN THE U.S. NUCLEAR REGULATORY COMMISSION AND ENTERGY NUCLEAR OPERATIONS, INC. CONCERNING THE DRAFT REQUEST FOR ADDITIONAL INFORMATION FOR THE REVIEW OF THE INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 AND 3, LICENSE RENEWAL APPLICATION, SET 2015-01 (TAC NOS. MD5407 AND MD5408)

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PUBLIC RidsNrrDlr Resource RidsNrrDlrRpb1 Resource RidsNrrDlrRpb2 Resource RidsNrrDlrRarb Resource RidsNrrDlrRasb Resource RidsNrrDlrRapb Resource RidsNrrDlrRerb Resource RidsNrrDlrRsrg Resource RidsOgcMailCenter Resource MWentzel JWeil, OCA JGavula MGray, RI CHovanec ABurritt, RI WHolsten DonaldJackson, RI YDiaz MModes, RI DMorey NSheehan, RI OPA DPickett DScrenci, RI OPA STurk, OGC DTifft, RI BMizuno, OGC NMcNamara, RI DRoth, OGC GNewman, RI BHarris, OGC JSStewart, RI SBurnell, OPA BPinson, RI DMcIntyre, OPA

TELEPHONE CONFERENCE CALL INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 AND 3 LICENSE RENEWAL APPLICATION LIST OF PARTICIPANTS APRIL30, 2015 PARTICIPANTS: AFFILIATIONS:

Jim Gavula U.S. Nuclear Regulatory Commission (NRC)

Chris Hovanec NRC Bill Holsten NRC Michael Wentzel NRC Rich Louie Entergy Nuclear Operations, Inc. (Entergy)

Entergy Entergy Entergy Entergy Entergy Entergy Entergy Entergy Entergy ENCLOSURE 1

TELEPHONE CONFERENCE CALL CONCERNING DRAFT REQUEST FOR ADDITIONAL INFORMATION (RAI), SET 2015-01 RELATED TO INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 AND 3 (IP2 and IP3)

LICENSE RENEWAL APPLICATION DOCKET NOS. 50-247 AND 50-286 REGARDING LR-ISG-2012-02 APRIL 30, 2015 The U.S. Nuclear Regulatory Commission (NRC) staff and representatives of Entergy Nuclear Operations, Inc., (Entergy)held a telephone conference call on April 30, 2015,to discuss and clarify the following requests for additional information (RAIs) concerning the license renewal application safety review.

RAI 3.0.3-3

Background

Entergy Nuclear Operations Inc. (Entergy), in a letter dated December 16, 2014, responds to RAI 3.0.3-1 and addresses the issues contained in LR-ISG-2012-02, "Aging Management of Internal Surfaces, Fire Water Systems, Atmospheric Storage Tanks, and Corrosion Under Insulation. Regarding LR-ISG-2012-02, Section A, Recurring Internal Corrosion, the response states that reviews of past plant-specific operating experience identified recurring internal corrosion due to general, pitting, and crevice corrosion that resulted in through-wall leaks at least once in each of three refueling cycles in the last 10 years for both units. For the service water system, the response states that minor corrosion issues still occur, but these do not compromise the intended functions of the service water system. In discussing through-wall leaks for cement-line carbon steel piping or stainless steel and copper alloy piping, the response also states that based on operating experience, such leaks have no impact on system performance and have not threatened the structural integrity of the piping or the safety function of nearby equipment.

Issue During its review, the staff identified plant-specific operating experience that appears to contradict statements in the RAI response regarding the significance of the corrosion issues associated with the service water system. In this regard, Licensee Event Report (LER) 286/2011-003, Technical Specification Required Shutdown and a Safety System Functional Failure for a Leaking Service Water Pipe Causing Flooding in the SW [service water] Valve Pit Preventing Access for Accident Mitigation, dated April 25, 2011, states: After further evaluation, it was concluded there was a loss of safety function, and It was concluded that this condition was a safety system functional failure. The LER statements appear to be inconsistent with the statement in the December 2014 response, regarding no impact of system performance.

In addition, LER 286/2002-001, Operation in a Condition Prohibited by Technical Specifications Due to an Inoperable Service Water Pipe Caused by a Leak that Exceeded the Allowable Outage Time,dated July 5, 2002,states, Engineering evaluation of data collected concluded that the leaking pipe did not provide sufficient structural integrity for the piping to meet code allowables for pipe thinning and through wall leaks and therefore was inoperable. Although this ENCLOSURE 2

LER is beyond the 10-year operating experience review window conducted for RAI 3.0.3-1, the staff notes that this operating experience was not included in the license renewal application in the discussion for the operating experience of the Service Water Integrity Program. Also, the staff notes that by letter dated June 5, 2008, Entergy responded to RAI AUX-1, which relates to the staffs questions on the operating experience summaries for several aging management programs, including the Service Water Integrity Program. For IP3 service water degradation, the 2008 response discusses the detection of loss of material during inspections from 2001 to 2004 and states that these conditions did not result in a loss of system intended function.

Engineering review of external corrosion and a pinhole leak did not result in any operability concerns. Based on LER 286/2002-001, the significance of past operating experience, regarding structural integrity and operability, may not have been adequately characterized by the statements made in the 2008 RAI response.

Request Explain and reconcile the information related to loss of safety function contained in the December 2014 response to RAI 3.0.3-1 and LER 286/2011-003. In addition, explain and reconcile the information related to the structural integrity and operability in the 2008 response to RAI AUX-1 and LER 286/2002-001.

Discussion: Entergy requested the staff to change the wording in the discussion of the issue because they felt it mischaracterized the apparent discrepancy under discussion. As a result, the staff revised the first sentence in the discussion of the issue to state:

During its review, the staff identified plant-specific operating experience indicating that corrosion issues did compromise the intended function of the service water system.

RAI 3.0.3-4

Background

Entergy letter dated December 16, 2014, responds to RAI 3.0.3-1 and addresses the issues contained in LR-ISG-2012-02. Regarding LR-ISG-2012-02, Section A, Recurring Internal Corrosion, the response states that reviews of past plant-specific operating experience identified at least one through-wall leak in each of three refueling cycles in the last 10 years for both units due to general, pitting, and crevice corrosion. For the service water system, the response states that minor corrosion issues still occur, but these do not compromise the intended functions of the service water system. In discussing through-wall leaks for cement-line carbon steel piping or stainless steel and copper alloy piping, the response also states that based on operating experience, such leaks have no impact on system performance and have not threatened the structural integrity of the piping or the safety function of nearby equipment.

The response subsequently includes an enhancement to the Service Water Integrity Program to incorporate the actions used to manage the minor corrosion issues in the service water system. The enhancement, to be implemented by 2019, consists of revising procedures to evaluate through-wall leaks under the corrective action program and to inspect portions of the buried service water by robotic crawler or manual crawl-through.

Recent LERs (286/2014-002, 247/2013-004, and 286/2011-003) discuss additional leaks in the service water system piping. The first LER (286/2014-002) states that Procedure 3-PT-R185B (Primary Auxiliary Building SW Piping and Valve Flush) was developed specifically to address recurring problems with leaks in stagnant vent and drain piping and that the procedure

is the main line of defense for preventing future leaks in small bore carbon steel piping socket welds. The staff notes that the initial Service Water Integrity Program previously included periodic flushing of infrequently used loops to manage loss of material in service water components. The second LER (247/2013-004) discusses replacement of certain portions of Series 300 stainless steel piping (which replaced the original carbon steel piping) in the service water system with highly corrosion resistant material. The replacement plan was developed after deficiencies were identified in 2008. The third LER (286/2011-003) discusses the loss of safety function for a portion of the service water system and states that the Generic Letter (GL) 89-13 program (the basis for the Service Water Integrity Program) will be revised to prioritize inspection frequencies of service water welds.

The significance of the degradation identified in the third LER (286/2011-003) prompted the staff to review the responses to Generic Letter 89-13 for IP2 and IP3. The staff noted a difference between the current licensing basis for the two responses. The February 2, 1990, response for IP2 discussed an in-place QA radiographic program that randomly inspects 10 percent of the service water piping welds annually, whereas the September 9, 1992, response for IP3 includes ultrasonic inspections of non-cement lined portions and visual inspections using a robotic crawler with a high resolution camera. The staff notes that a 1991 status update for IP2 on various Action Items for GL 89-13 states: We have initiated an internal visual inspection program for underground service water piping. This program utilizes pipe crawling video equipment to inspect and record the condition of the cement-lined underground pipe.

Issue Given the enhancements to the Service Water Integrity Program proposed in the December 16, 2014 letter, the current details of the program implementation are unclear to the staff. Since the IP2 and IP3 responses to GL 89-13 both refer to using remote crawlers and one response specifically addresses underground service water piping, it is not clear to the staff how the current enhancement for internally inspecting buried service water piping (to be implemented prior to 2019) differs from the program that (based on the current licensing basis) was previously in place. In addition, regarding the other currently proposed enhancement to the Service Water Integrity Program (evaluating leakage under the corrective action program), the need for revised procedures to evaluate through-wall leaks under the corrective action program implies that leakage currently may not be evaluated under the corrective action program. In this regard, too, it is not clear to the staff how the proposed enhancement differs from the program that was previously in place, given that LRA Section B.0.3 states the corrective action controls of the Entergy (10 CFR Part 50, Appendix B) Quality Assurance Program are applicable to all aging management programs and activities.

Based on the operating experience discussed in the above LERs, enhancements to the Service Water Integrity Program have been implemented beyond the version of the program that was evaluated by the staff in NUREG-1930, Safety Evaluation Report Related to the License Renewal of Indian Point Nuclear Generating Unit Nos. 2 and 3. For LER 286/2011-003, the program apparently did not adequately manage the effects of aging because an intended function of the system was not maintained consistent with the current licensing basis. SRP-LR Section A.1.2.3.10 states that a past failure would not necessarily invalidate an aging management program because the feedback from operating experience should have resulted in appropriate program enhancements or new programs. In that regard, it is not clear to the staff what changes have been made to the program over the years as a result of past operating experiences or what changes have been made to the prior commitments for GL 89-13.

Request

1) Provide a description and chronological history of any enhancements that have been made to the Service Water Integrity Program, from the version of the program reviewed by the staff as documented in NUREG-1930, as a result of Indian Point site-specific operating experience. If no enhancements have been made, then discuss the meaning of the statement in LER 286/2011-003 regarding changes that will be made to the GL 89-13 program. In addition, clarify whether Procedure 3-PT-R185B was revised as a result of the extent of condition review discussed in LER 286/2014-002, and if it was not revised, discuss how the recurring problems with leaks developing in stagnant vent and drain connection piping and valves (identified in the extent of condition review) are being addressed.

2) Clarify whether (and if so, when) any changes have been made to previously docketed licensing commitments for the IP2 and IP3 responses to GL 89-13, and provide information as to whether (and if so, when) that the NRC has been informed of any changes.

3) For the two proposed enhancements in the response to RAI 3.0.3-1, clarify the differences between the new enhancement activities and the activities in the previously implemented program.

4) Provide the following details for the current Service Water Integrity Program:

a) the amount and timing of any past (and if they are to be credited, any planned) service water system piping replacements; b) trend data from the past 10 years for the number of leaks caused by age-related degradation; c) the number and frequency of volumetric inspections being performed to both track known degradation locations and identify additional degradation locations; d) the type (internal or external), amount, and frequency of visual inspections being performed; e) the criteria used to determine locations for and adjustments to the number and frequency of volumetric and visual inspections, including any predictive methodology.

In responding to Request No. 1 and Request No. 4, parts c, d, and e, state whether these actions will continue during the timely renewal period and period of extended operation; and revise the Service Water Integrity Program and corresponding Updated Final Safety Analysis Report supplement accordingly.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.

RAI 3.0.3-5

Background

The response to RAI 3.0.3 1 dated December 16, 2014, states that the fire protection water and city water systems have experienced recurring internal corrosion (RIC), as defined in LR-ISG-2012-02. With regard to the fire protection water system, the response states, [l]ocalized corrosion has resulted in minor through-wall leaks that have no impact on system performance and do not threaten the structural integrity of the piping or the safety function of nearby equipment. No changes were proposed to the Fire Water System Program to address RIC.

With regard to the city water system, the response states, [h]owever, based on past operating experience, they [through wall leaks] do not compromise the intended functions of these or any other system, and do not warrant aging management program activities beyond those provided by established aging management programs and the corrective action program.

Issue Past performance does not provide reasonable assurance that throughout the period of extended operation, internal general corrosion will be revealed by a through-wall leak prior to the general corrosion potentially impacting the structural integrity of the system. Nor does it provide reasonable assurance that larger through-wall flaws sufficient to challenge the pressure boundary function will not occur. It is also unclear to the staff that a sufficient representative sample exists for the carbon steel piping to demonstrate that general corrosion is progressing slowly enough that it will not prevent an in-scope component from performing its current licensing basis intended function during the period of extended operation.

Although to date through-wall leaks have not affected the safety function of nearby equipment, the staff lacks sufficient information to conclude with reasonable assurance that this will be the case throughout the period of extended operation.

Request

1) State the basis and justification for concluding that existing inspection data are sufficient to demonstrate that general corrosion is progressing slowly enough that it will not prevent an in-scope component from performing its current licensing basis intended function during the period of extended operation.

2) State the basis and justification for concluding that through-wall leaks will not impact the safety function of nearby equipment throughout the period of extended operation.

3) Provide the staff with sufficient quantitative data for it to reach the same conclusions.

Alternatively, propose periodic inspections in response to SRP-LR Section 3.3.2.2.8, Loss of Material due to Recurring Internal Corrosion.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.

RAI 3.0.3-6

Background

As amended by letter dated December 16, 2014, LRA Section B.1.14 states an exception to the detection of aging effects program element. This exception states that adhesion testing will not be conducted on the internal surfaces of fire water storage tanks in accordance with ASTM D 3359, Standard Test Methods for Measuring Adhesion by Tape Test, as required by NFPA 25 Section 9.2.7. The justification for the exception states in part that holiday testing and wall thickness measurements are conducted. It also states that adhesion testing, in accordance with ASTM D 3359, would not be conducted because the recommended type of adhesion testing is destructive and test results are variable.

Issue

An alternative to adhesion testing was not proposed, and beyond citing that holiday testing and wall thickness measurements will be conducted if coating defects are detected, no basis for the exception was provided. Holiday testing and wall thickness measurements would not detect potential peeling, delamination, or blistering, or the extent of these aging mechanisms.

Request State how potential peeling, delamination, or blistering, or the extent of these aging mechanisms, would be detected by holiday testing or ultrasonic wall thickness measurements, or propose an alternative to the adhesion testing cited in NFPA 25.

Discussion: Entergy requested the staff to revise the discussion of the issue to be consistent with a similar RAI issued for the review of the Grand Gulf Nuclear Station LRA review. As a result, the staff revised the issue discussion to state:

An alternative to adhesion testing was not proposed.

RAI 3.0.3-7

Background

As amended by letter dated December 16, 2014, LRA Section B.1.14 states an exception to the detection of aging effects program element. The exception states that preaction valve testing is not conducted with the control valve fully open for the electric tunnels as specified by NFPA 25 Section 13.4.3.2.3.

Issue The staff lacks sufficient information to conclude that adequate flow to detect potential flow blockage will be achieved during the test. The staff also noted that NFPA 25 Section 13.4.3.2.2.5 allows air to be used as a test medium when the nature of the protected property is such that water cannot be discharged.

Request State and justify the basis for why flow rates sufficient to detect flow blockage will be achieved during preaction valve testing.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.

RAI 3.0.3-8

Background

As amended by letter dated December 16, 2014, an enhancement to LRA Section B.1.14 was revised to state that the acceptance criteria used during the internal inspection of foam-based fire suppression tanks will be signs of abnormal corrosion.

Issue

The staff lacks sufficient information to complete its evaluation of the acceptance criteria portion of this enhancement because abnormal corrosion is not described.

Request State the magnitude of corrosion that would be considered unacceptable during the inspection of internal surfaces of foam-based fire suppression tanks.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.

RAI 3.0.3-9

Background

As amended by letter dated December 16, 2014, an enhancement to LRA Section B.1.14 states that sprinkler heads will be replaced if they show signs of abnormal corrosion, excessive loading, leakage, or if the glass bulb heat responsive element is empty. LRA Section B.1.14 was also amended to state that charcoal filter unit nozzles will be inspected for abnormal corrosion when the charcoal is replaced.

Issue The staff notes that NFPA 25, Sections 5.2.1.1.2(2) and 5.2.1.1.4 state that sprinklers that exhibit corrosion, not abnormal corrosion should be replaced.

Request a) Describe the degree of corrosion that would be found acceptable during a visual inspection of a sprinkler and justify why this degree of corrosion would not impact the performance of the sprinkler (e.g., water distribution).

b) Describe the degree of corrosion that would be found acceptable during a visual inspection of charcoal filter nozzles and justify why this degree of corrosion would not impact the performance of the charcoal filter deluge system.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.

RAI 3.0.3-10

Background

As amended by letter dated December 16, 2014, an enhancement to LRA Section B.1.14 states that air flow testing will be conducted during each refueling outage through the foam system open head nozzles to ensure there is no blockage. It also states that if blockage is detected, the system will be cleaned and retested.

Issue

The staff notes that LR-ISG-2012-02 AMP 27, Table 4a recommends that an operational discharge pattern test be conducted annually in accordance with NFPA 25 Section 11.3.2.6, Table 4a footnote 6 states that, [w]here the nature of the protected property is such that foam cannot be discharged, the nozzles or open sprinklers shall be inspected for correct orientation and the system tested with air to ensure that the nozzles are not obstructed. A justification was not provided for testing every refueling outage in lieu of annual testing.

Request Provide a justification as to why the frequency for testing the foam system open head nozzles every refueling outage in lieu of annually is acceptable.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.

RAI 3.0.3-11

Background

As amended by letter dated December 16, 2014, an enhancement to LRA Section B.1.14 states that in buildings with multiple wet piping systems, one third of the systems will be inspected every five years such that all systems will be inspected during each 15-year period.

Issue A justification was not stated for inspecting one-third of the systems where there are multiple wet pipe systems in lieu of every other system as cited in NFPA 25 Section 14.2. In addition, the enhancement does not state whether all the systems in a building will be inspected if foreign organic or inorganic material is found in any system in that building.

Request Provide a justification as to why testing one-third of the systems every 5 years and not testing all the systems in a building when foreign organic or inorganic material is found in any system in that building is sufficient to provide reasonable assurance that the wet fire water system piping and piping components will meet their current licensing basis intended functions during the period of extended operation.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.

RAI 3.0.3-12

Background

As amended by letter dated December 16, 2014, LRA Section B.1.14 states, [i]n addition to NFPA codes, portions of the water-based fire protection system (a) that are normally dry but periodically subject to flow (e.g., dry-pipe or preaction sprinkler system piping and valves) and (b) that cannot be drained or allow water to collect are subject to augmented testing and inspections.

Issue

LRA Sections A.1.14 and B.1.14 do not state what augmented testing will be conducted. In addition, the staff noted that there were no enhancements associated with this program requirement.

Request a) State what augmented testing and inspections will be conducted for fire protection-water systems that are normally dry but periodically subject to flow (e.g., dry-pipe or preaction sprinkler system piping and valves) that cannot be drained or allow water to collect.

b) State whether an enhancement is necessary to incorporate these augmented tests and inspections.

c) Revise the LRA Section A.1.14 or B.1.14 as necessary.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.

RAI 3.0.3-13

Background

As amended by letter dated December 16, 2014, LRA Sections A.2.1.13 and A.3.1.13 state that the enhancements to the Fire Water System Program will be implemented by December 31, 2019.

Issue As stated in RAI 3.0.3-12, it is not clear whether an enhancement is necessary to address augmented testing for fire protection-water systems that are normally dry but periodically subject to flow (e.g., dry-pipe or preaction sprinkler system piping and valves) that cannot be drained or allow water to collect. SRP-LR Table 3.0-1, as amended by LR-ISG-2-12-02, states that the augmented testing should commence 5 years prior to the period of extended operation. Given that IP2 is beyond the expiration of its initial license (September 2013) and IP3 will be beyond its initial license period in December 2015, the staff questions why the augmented testing would not commence sooner than December 31, 2019.

Request State and justify the basis for why the augmented testing for fire protection-water systems that are normally dry but periodically subject to flow (e.g., dry-pipe or preaction sprinkler system piping and valves) that cannot be drained or allow water to collect will not commence until December 31, 2019.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.

RAI 3.0.3-14

Background:

By letter dated December 16, 2014, the Aboveground Steel Tanks Program was enhanced to develop or revise program implementation documents to incorporate the inspection details that are tabulated in the program description. The tabulated tank inspection techniques and frequencies are provided for each applicable material, environment, and aging effect. The enhancement will be implemented prior to December 31, 2019. An exception was also added to the program stating that the timing of the inspections will not be consistent with the guidance in LR-ISG-2012-02. The exception noted that the implementation schedule for the inspections could not be consistent with LR-ISG-2012-02 because of the date that the guidance was issued.

The enhancement will be implemented prior to December 31, 2019. The initial operating license for Unit 2 expired in September of 2013. The initial operating license for Unit 3 will expire in December of 2015.

LR-ISG-2012-02 was issued in November of 2013. The implementation schedule in SRP-LR Table 3.0-1, as amended by LR-ISG-2-12-02, for GALL Report AMP XI.M29 states that the program is implemented and inspections begin 10 years before the period of extended operation. Additionally, Table 4a, in GALL Report AMP XI.M29, as amended by LR-ISG-2012-02, provides inspection frequencies that begin 10 years prior to the period of extended operation.

Issue: LRA Sections A.2.1.1, A.3.1.1, and B.1.1 state that the program enhancements will be implemented prior to December 31, 2019. Given that the inspections recommended to be performed prior to entering the period of extended operation have not occurred, IP2 is beyond the expiration of its initial license (September 2013), and IP3 will be beyond its initial license period in December 2015, it is unclear to the staff why the inspections in the enhancement might not be implemented until late 2019 rather than earlier.

Request:

State the basis and justify why implementation of inspections described in the program description do not need to be implemented until December 31, 2019.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.

RAI 3.0.3-15

Background:

By letter dated December 16, 2014, LRA Table 3.3.2-14-IP2, City Water, Summary of Aging Management Review, was revised. The table includes an AMR item for steel tanks exposed to an internal environment of treated water that was revised to manage the aging effect of loss of material using the Aboveground Steel Tanks Program instead of the Periodic Surveillance and Preventative Maintenance Program. This AMR item cites generic note G and plant specific note 305. Plant specific note 305 states that This treated water environment includes water that has been treated but is not maintained by a chemistry control program, such as water from the city water system. There is no environment in NUREG-1801 that will support a useful comparison for this line item.

Section IX.D, Selected Definitions & Use of Terms for Describing and Standardizing Environments, of GALL Report, revision 2, provides descriptions of treated water and raw water. Treated water includes demineralized water or water containing corrosion inhibitors.

Raw water includes potable water and water used for drinking or other personal use.

GALL Report AMP XI.M29, Aboveground Metallic Tanks, as amended by LR-ISG-2012-02 provides different guidance for managing the loss of material for steel tanks exposed to treated water and raw water. The differences are illustrated in Table 4a, Tank Inspection Reconditions, and AMR line items 3.3.1-129 and 3.3.1-137.

Issue: The environment of city water is being categorized as treated water; however, city water appears to more closely resemble raw water. The aging management of loss of material for steel tanks exposed to treated water is not equivalent to that exposed to raw water in that steel exposed to treated water may use a one-time inspection to verify aging effects, whereas for steel exposed to raw water it is recommended that periodic inspections be conducted.

Request: State the basis and justify why city water is being categorized as treated water instead of raw water. Additionally, state the basis and justify why steel tanks exposed to city water are being managed for loss of material in accordance with LR-ISG-2012-02 inspection guidance for treated water instead of raw water.

Discussion: Entergy stated that they understood what information the NRC staff was requesting.