ML18332A145
| ML18332A145 | |
| Person / Time | |
|---|---|
| Issue date: | 11/01/2018 |
| From: | Advisory Committee on Reactor Safeguards |
| To: | |
| References | |
| NRC-3972 | |
| Download: ML18332A145 (142) | |
Text
Official Transcript of Proceedings NUCLEAR REGULATORY COMMISSION
Title:
Advisory Committee on Reactor Safeguards Docket Number: (n/a)
Location: Rockville, Maryland Date: Thursday, November 1, 2018 Work Order No.: NRC-3972 Pages 1-142 NEAL R. GROSS AND CO., INC.
Court Reporters and Transcribers 1323 Rhode Island Avenue, N.W.
Washington, D.C. 20005 (202) 234-4433
1 1
2 3
4 DISCLAIMER 5
6 7 UNITED STATES NUCLEAR REGULATORY COMMISSIONS 8 ADVISORY COMMITTEE ON REACTOR SAFEGUARDS 9
10 11 The contents of this transcript of the 12 proceeding of the United States Nuclear Regulatory 13 Commission Advisory Committee on Reactor Safeguards, 14 as reported herein, is a record of the discussions 15 recorded at the meeting.
16 17 This transcript has not been reviewed, 18 corrected, and edited, and it may contain 19 inaccuracies.
20 21 22 23 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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1 1 UNITED STATES OF AMERICA 2 NUCLEAR REGULATORY COMMISSION 3 + + + + +
4 658TH MEETING 5 ADVISORY COMMITTEE ON REACTOR SAFEGUARDS 6 (ACRS) 7 + + + + +
8 THURSDAY 9 NOVEMBER 1, 2018 10 + + + + +
11 ROCKVILLE, MARYLAND 12 + + + + +
13 The Advisory Committee met at the Nuclear 14 Regulatory Commission, Three White Flint North, Rooms 15 1C3 & 1C5, 11601 Landsdown Street, at 8:30 a.m.,
16 Michael L. Corradini, Chairman, presiding.
17 18 COMMITTEE MEMBERS:
19 MICHAEL L. CORRADINI, Chairman 20 PETER RICCARDELLA, Vice Chairman 21 RONALD G. BALLINGER, Member 22 CHARLES H. BROWN, JR. Member 23 MARGARET SZE-TAI Y. CHU, Member 24 VESNA B. DIMITRIJEVIC, Member 25 WALTER L. KIRCHNER, Member NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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2 1 JOSE MARCH-LEUBA, Member 2 JOY L. REMPE, Member 3 GORDON R. SKILLMAN, Member 4
5 DESIGNATED FEDERAL OFFICIAL:
6 KENT HOWARD 7
8 9
10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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3 1 AGENDA 2 Opening Remarks by the ACRS Chairman . . . . . . 4 3 Waterford Steam Electric Station, Unit 3 License 4 Renewal Application . . . . . . . . . . . 8 5 River Bend Nuclear Generating Station, Unit 1 6 License Renewal Application . . . . . . . 31 7 Adjourn . . . . . . . . . . . . . . . . . . . . . 83 8
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4 1 P R O C E E D I N G S 2 8:29 a.m.
3 CHAIRMAN CORRADINI: Okay, why don't we 4 get started? The meeting will come to order now.
5 This is the first day of the 658th meeting of the 6 Advisory Committee on Reactor Safeguards.
7 During today's meeting, the Committee will 8 consider the following, the Waterford Steam Electric 9 Station Unit 3 license renewal application, River Bend 10 Nuclear Generating Station Unit 1 license renewal 11 application, preparation for the meeting with the 12 Commission in December, and preparation of ACRS letter 13 reports.
14 The ACRS was established by statute and is 15 governed by the Federal Advisory Committee Act, or 16 FACA. As such, this meeting is being conducted in 17 accordance with the provisions of FACA. That means 18 the Committee can only speak through its published 19 letter reports. We hold meetings to gather 20 information to support our deliberations.
21 Interested parties who wish to provide 22 comments can contact our offices requesting time after 23 the Federal Register notice describing a meeting is 24 published. That said, we also set aside 10 minutes 25 for extemporaneous comments from members of the public NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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5 1 attending or listening to our meetings on the line.
2 Written comments are also welcome. Today, Mr. Ken 3 Howard is the designated federal official for the 4 initial portion of the meeting.
5 The ACRS section of the U.S. NRC public 6 website provides our charter, bylaws, letter reports, 7 and full transcripts of all our full and subcommittee 8 meetings, including all slides presented at those 9 meetings.
10 We've received no written comments or 11 requests to make oral statements from members of the 12 public regarding today's session, and also there will 13 be a phone bridge line open and on mute. To preclude 14 interruption of the meeting, it will be on a listen in 15 only mode during the presentations and Committee 16 discussions.
17 I also want to remind everybody to please 18 silence their devices, all your various types of 19 devices. Make sure we don't have any beeps, or bops, 20 or rings.
21 Also, this is a temporary room where we 22 hold our meetings and the audio, I'll just say, is 23 challenging, so my suggestion is when you turn on the 24 mic, make sure you have the green light on and you 25 kind of have to speak into it, otherwise you kind of NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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6 1 drift away for those listening in on the phone line or 2 the bridge line.
3 A transcript of portions of the meeting is 4 being kept and it's requested that the speakers use 5 one of the microphones, identify themselves, and speak 6 with sufficient clarity and volume so we can be 7 readily heard.
8 I'll turn the meeting over to Member 9 Skillman.
10 MEMBER SKILLMAN: Mr. Chairman, thank you.
11 This is plant week at ACRS. Yesterday, we did alkali-12 silica reaction for Seabrook, and today we're 13 privileged to have the team from Entergy, two teams, 14 one for Waterford 3 license renewal for 20 years, and 15 the second meeting will be River Bend team license 16 renewal for 20 years.
17 So thank you, everybody, and now I'm going 18 to turn the meeting over to Joe Donoghue as he 19 introduces the meeting, Joe?
20 MR. DONOGHUE: Good morning. Thank you, 21 Member Skillman. Thank you, Chairman Corradini and 22 members of the ACRS full Committee. I'm Joe Donoghue.
23 I'm the Deputy Director in the Division of Materials 24 and License Renewal at NRR, and next to me is George 25 Wilson, the Director.
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7 1 We sincerely appreciate the opportunity to 2 brief the Committee on the status review of the 3 Waterford license renewal application.
4 As you know, the staff presented the 5 results of their review of the Waterford renewal 6 application to the ACRS Subcommittee, the License 7 Renewal Subcommittee on September 20 of this year.
8 There were no follow ups from the meeting on 9 Waterford.
10 The license renewal presentations today 11 will be led by the following staff, Phyllis Clark, and 12 at the table will be Dr. Allen Hiser, our Senior 13 Technical Advisor. With me is Eric Oesterle. He's a 14 Chief of the Projects Branch in our Division, and in 15 the audience are other staff who conducted the review, 16 and management as well.
17 We look forward to a productive discussion 18 today with the full Committee, and as always, we will 19 address any questions on our reviews that you may 20 have. We look forward to receiving your 21 recommendation letter on our review.
22 At this time, I'd like to turn the 23 presentation over to the Entergy team and their Site 24 Vice President, Mr. John Dinelli, to introduce his 25 team and commence their presentation.
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8 1 MR. DINELLI: Thank you. Good morning.
2 My name is John Dinelli and I'm the Site Vice 3 President at the Waterford 3 Steam Electric Station 4 responsible for the safe and reliable operation of the 5 facility.
6 This is an important day for Waterford.
7 We at Entergy have been working for several years to 8 get ready for the period of extended operation at 9 Waterford.
10 In today's presentation, you will hear 11 about major equipment upgrades as well as the 12 establishment of fleet aging management programs in 13 support of that effort.
14 We have with us today from Waterford, 15 Brian Lanka, the Director of Engineering, John 16 Jarrell, the Senior Manager of Operations, and Garry 17 Young, Director of License Renewal. We also have 18 other project and technical personnel in attendance 19 should their input be necessary.
20 And today's agenda for this presentation 21 it to describe the Waterford Station, plant status, 22 and our licensing history. We will also address major 23 equipment upgrades, both completed and planned, that 24 will help us prepare for the extended period of 25 operation. In addition, we will discuss the license NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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9 1 renewal project itself.
2 We want to thank you for the opportunity 3 today. This is a very important day and a major 4 milestone for Waterford 3 and for Entergy. Now I'll 5 turn it over to John Jarrell.
6 MEMBER SKILLMAN: Before you do that, 7 please, John, let me ask you a question. In the 8 spirit of shadow of the leader, what shadow do you 9 cast at your site regarding Appendix B to 10 CFR 50, 10 your QA program and programs?
11 MR. DINELLI: Mr. Skillman, the QA program 12 is a vital component to the safe operation of the 13 facility, so the way I cast my shadow for the 14 organization is to fully support the QA organization 15 and all of the functions that they serve.
16 I'll come through my experience that if 17 you have a healthy adherence to that program and all 18 aspects of that program, that it will ultimately drive 19 station performance.
20 So by showing my employees, my directors, 21 managers, and station employees that adherence to that 22 and following through with that program is important, 23 it makes it important to them, and overall makes us a 24 better operating facility.
25 MEMBER SKILLMAN: Thank you, sir. Thank NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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10 1 you.
2 MR. JARRELL: Okay, good morning. Again, 3 I want to thank the members of the ACRS for meeting 4 with us today. My name is John Jarrell. I'm the 5 Senior Manager of Operations at Waterford 3. I want 6 to give a little description of the site.
7 First of all, Waterford 3 is located about 8 25 miles upriver from New Orleans in St. Charles 9 Parish. We are a combustion engineering design and 10 EBASCO was our contractor and constructor. We do have 11 a dry containment.
12 I would like to apologize. We are having 13 some technical difficulties as you can see.
14 All right, our turbine generator is a 15 Westinghouse turbine generator. Our ultimate heat 16 sink is a combination of dry and wet cooling tower 17 fans which are independent from the Mississippi River.
18 It is a relatively unique design.
19 Our licensed thermal power limit is 3,716 20 megawatts thermal and the staff complement is 21 currently approximately 751 employees.
22 As of this morning, the plant was at 100 23 percent power. We are in our 18-month refueling 24 cycle. We are in the rack or oversight process action 25 matrix column one. Our last refueling outage was NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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11 1 spring of 2017 and we are preparing for an outage 2 refuel 22 which will occur early 2019.
3 MEMBER SKILLMAN: For the last several 4 fuel cycles, what has been your approximate capacity 5 factor?
6 MR. JARRELL: Our capacity factor has been 7 over 90 percent, so we've had a good operating history 8 and 90 percent was our capacity factor as of August of 9 this year.
10 MEMBER SKILLMAN: Thank you.
11 MR. JARRELL: Our licensing history is our 12 construction permit. We were permitted for 13 construction in 1974. We received our operating 14 license on March 16 of 1985 and we went commercial in 15 September of 1985 as well.
16 We had an eight percent power upgrade in 17 April of 2005, and we submitted our license renewal 18 application on March 16 of 2016, and our current 19 license is set to expire December 18 of 2024.
20 So with that, I'd like to turn it over to 21 our Engineering Director, Brian Lanka. He'll go over 22 some major equipment upgrades at the site.
23 MR. LANKA: I'm Brian Lanka. I'm the site 24 Engineering Director. First, I want to start by 25 saying Entergy and Waterford are committed through our NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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12 1 nuclear strategy plan to make Waterford 3 reliable for 2 extended operation. To that means, we have a long 3 range plan focused on improving plant safety and 4 equipment performance.
5 The station has completed replacement of 6 our four active coolant pump motors. We have 7 proactively added design margin by increasing our 8 diesel generator fuel capacity. We've increased that 9 capacity by approximately 35 percent.
10 We have also addressed reliability by 11 replacing our safety-related static uninterruptible 12 power supplies, and in January, we'll complete a 13 modification that will put a swing system in to 14 further increase reliability.
15 In 2013, the station has replaced both the 16 reactor head and the steam generator. Both use more 17 resilient materials. The reactor head eliminated all 18 LI600 material on the head.
19 The station has also replaced the 20 traveling screen system to further reduce debris from 21 entering the condenser and protecting our new steam 22 generator.
23 This is a picture of our new traveling 24 screens. These are Geiger screens. They are zero 25 carryover screens. They actually rotate in a circular NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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13 1 motion versus carryover. These are pictures of our 2 new steam generators going in in 2013. We replaced 3 the LI600 tubes with LI690, and this is a picture of 4 the reactor heads going in. We replaced all of the 5 top, the coils, and everything on top of the head as 6 well.
7 Going forward, we had the following -
8 CHAIRMAN CORRADINI: Can I ask a quickie?
9 MR. LANKA: Sure, go ahead.
10 CHAIRMAN CORRADINI: On your, you had gone 11 through this list, and now I've lost it. You said you 12 added more capacity for your fuel storage tanks. What 13 does that change your capacity for running the diesel 14 generators from and to?
15 MR. LANKA: We added approximately 10,000 16 gallons, so we had an additional margin -- we're 17 required to have a seven-day supply because this is 18 additional margin so we can run more surveillance 19 without having to go back and fill it up.
20 CHAIRMAN CORRADINI: So seven becomes 14 21 or seven becomes 10?
22 MR. LANKA: We still use seven. We just 23 lowered the capacity, but if you look at it the way 24 you're explaining it, we probably gained a couple of 25 days.
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14 1 CHAIRMAN CORRADINI: Okay, thank you.
2 MR. LANKA: Okay, going forward, in 3 January, we will be retubing our condenser with SEA-4 CURE, which is a more resilient material. We'll also 5 be upgrading our cathodic protection system based on 6 the new SEA-CORE material.
7 CHAIRMAN CORRADINI: I wasn't at the 8 meeting, so I apologize if I'm stopping you and this 9 is old news. What is the material for the condenser?
10 MR. LANKA: SEA-CURE.
11 CHAIRMAN CORRADINI: What is that?
12 MR. LANKA: It's a high-end stainless 13 steel.
14 CHAIRMAN CORRADINI: High end.
15 MR. LANKA: It's very resilient.
16 CHAIRMAN CORRADINI: Okay, thank you. Is 17 there any more interesting technology? Is there any 18 surface treatment to the tubes or is this alloy steel 19 untreated on the surface?
20 MR. LANKA: It's untreated.
21 CHAIRMAN CORRADINI: Untreated, thank you.
22 MR. LANKA: We are also working to replace 23 our core protection calculators. This system is part 24 of our reactor coolant protection system which 25 actually monitors the core. We have plans to replace NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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15 1 our turbine control system and our safety-related 2 chillers, and lastly, to improve safety and 3 reliability, we have several ongoing upgrades of our 4 motors, fans, and associated motor control centers for 5 our ultimate heat sink.
6 I'm going to turn it over now to Garry 7 Young who will go over the license.
8 MR. YOUNG: Okay, thank you. I'm Garry 9 Young, the Director of License Renewal for the Entergy 10 nuclear fleet, and I'd like to give you some 11 background on our license renewal process, including 12 the approach for the integrated plan assessment and 13 for preparing the license renewal application.
14 We have a dedicated corporate team working 15 on license renewal for all of the Entergy nuclear 16 plants. This team, with almost two decades of 17 experience with all aspects of aging management and 18 license renewal, has prepared more than a dozen 19 license renewal applications over the past several 20 years.
21 In addition to the corporate team, a plant 22 team of Waterford experts in design, systems 23 engineering, and plant programs was established for 24 this license renewal project. The plant team provided 25 the needed input, review, and oversight of all the NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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16 1 engineering and environmental reports that were 2 created.
3 Entergy used the NRC-approved guidance in 4 NEI 95.10 to prepare the project specific procedures 5 and guidelines. These procedures have been used on 6 our previous license renewal projects and are 7 routinely updated based on lessons learned, industry 8 operating experience, and changes to NRC guidance.
9 The site specific aging management review 10 results for Waterford were compared to the GALL 11 Report, which is NUREG-1801, Revision 2, as part of 12 the license renewal application development, and I'll 13 talk more about the comparison of the programs with 14 the GALL Report on a later slide. The LRA was 15 submitted to the NRC in March of 2016.
16 The NRC review process culminated in the 17 Waterford safety evaluation report which was issued in 18 August of 2018 with no open items and no confirmatory 19 items. We appreciate the extensive and thorough work 20 of the NRC staff in reaching this important milestone 21 in the license renewal application review process.
22 Next slide.
23 This slide summarizes the aging management 24 programs credited for license renewal. We have 41 25 aging management programs that include 12 new programs NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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17 1 and 29 existing programs, most of which are or will be 2 consistent with the GALL Report with a handful of 3 exceptions as shown on this slide.
4 Some examples of the 12 new programs are 5 the buried and underground piping and tanks inspection 6 program, the non-EQ cables and connections, aging 7 management programs, and one-time inspection programs.
8 Some aspects of these new programs have 9 been implemented, but they are considered new programs 10 because a significant number of changes must be made 11 or have only recently been made to make them 12 consistent with the program descriptions in the GALL 13 Report.
14 For example, the Waterford buried piping 15 program was initiated in response to the 2009 NEI 16 initiative, but significant changes are necessary to 17 incorporate the latest NRC guidance which includes the 18 interim staff guidance issued in 2015.
19 For clarity in describing the program, 20 Entergy classified it as a new program that would be 21 consistent with the program description in the most 22 recent NRC guidance.
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18 1 of the Waterford aging management programs reaps the 2 benefits of lessons learned, from the Entergy 3 operating experience review program, and the 4 corrective action program.
5 28 of the existing programs have been 6 compared to the GALL programs, and only a few 7 exceptions have been taken. These exceptions include 8 such things as revised inspection intervals based on 9 the Waterford refueling outage schedules and 10 referencing NRC regulatory guides and industry 11 standards that are later revisions than those 12 referenced in the GALL Report which was published in 13 2010.
14 And finally, we have one existing plant 15 specific program which is the period surveillance and 16 preventive maintenance program. This program includes 17 a variety of aging management activities that could 18 not readily fit within the scope of the GALL Report 19 programs. Next slide.
20 On the topic of commitment management and 21 controlling the commitments that we've made for 22 license renewal, Entergy has a fleet program that 23 covers management of commitments for all our nuclear 24 plants.
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19 1 management program for our previous license renewal 2 projects, including projects for plants that have 3 implemented license renewal commitments and are 4 successfully operating in the period of extended 5 operation.
6 For each Waterford license renewal 7 commitment, the commitment management program 8 identifies the actions needed to implement the 9 commitments and identifies the owner responsible for 10 implementation.
11 Assignments will include actions such as 12 creation of implementing procedures for new aging 13 management programs and incorporating enhancements to 14 existing aging management programs. So this completes 15 my portion of the presentation. Thank you.
16 MEMBER MARCH-LEUBA: Can I ask you a 17 question? You may not be the right person. Are you, 18 any of you familiar with the term alkali-silica 19 reaction, concrete aging mechanism? Does it affect 20 your plant?
21 MR. YOUNG: No, we did look into that 22 because that is an industry issue of importance, but 23 we found that there was no indication of ASR at 24 Waterford.
25 MEMBER MARCH-LEUBA: Thank you.
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20 1 MR. DINELLI: Thank you. So I just want 2 to thank the Committee once again and assure the 3 Committee that Entergy is committed to the long term 4 operation and continuous improvement of our facility.
5 We will manage the effects of our aging, 6 evaluate time limited aging analysis under the 7 evaluations governed by 10 CFR 54, and we meet the 8 provisions for issuance of a license renewal.
9 So once again, I want to thank you for 10 this opportunity on this important day, and I look 11 forward to any further discussions.
12 MEMBER SKILLMAN: John, thank you.
13 Colleagues, any questions for the Entergy Waterford 3 14 team? Okay, team change out? Joe, back to you.
15 MR. DONOGHUE: Thank you, Chairman 16 Corradini. In my opening remarks, I introduced 17 Phyllis Clark as the project manager, and Allen Hiser 18 is our senior technical advisor involved in license 19 renewal, and Lois James who is the project manager 20 assisting in this project. Go ahead.
21 MS. CLARK: Good morning, Chairman 22 Corradini and the members of the ACRS.
23 MEMBER SKILLMAN: You may have to get 24 closer to the mic.
25 MS. CLARK: Okay, thanks, okay. My name NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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21 1 is Phyllis Clark and I'm the project manager for the 2 license renewal safety review for the Waterford Steam 3 Electric Station Unit 3, or I'll refer to it as 4 Waterford.
5 We are here today to discuss the staff's 6 review of the Waterford license renewal application as 7 documented in the safety evaluation report, SER, which 8 was issued August 17, 2018.
9 Joining me here at the table is Allen 10 Hiser, Senior Technical Advisor for License Renewal, 11 aging management, and Ms. Lois James, Senior Safety 12 Project Manager from the Division of Material and 13 License Renewal, DMLR.
14 Seated in the audience and joining by 15 phone are members of the technical staff who 16 participated in the review of the license renewal 17 application and conducted onsite audits and 18 inspection. Next slide.
19 I will begin the presentation with a 20 general overview of the staff's review and then 21 present the staff's conclusions. Next slide.
22 On March 23, 2016, Entergy Operations, 23 Inc. submitted a license renewal application or LRA 24 for Waterford which has a combustion engineering 25 pressurized water reactor, PWR, nuclear steam electric NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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22 1 steam supply system with licensed thermal power of 2 3,716 megawatts thermal. The staff conducted two 3 onsite audits and one inspection at the site.
4 During the scoping and screening 5 methodology audit, the audit team reviewed the 6 applicant's scoping and screening methodology, 7 selected examples of component material and 8 environmental combinations, the corrective action 9 program, administrative and confirmatory action 10 process as described in the LRA, and the training of 11 personnel who participated in the development of the 12 LRA. The results of the audit are documented in the 13 report dated November 10, 2016.
14 During the aging management program 15 audits, the audit team examined the applicant's aging 16 management program of AMPs, related documentation, and 17 operating experience to verify the applicant's claim 18 of consistency with corresponding AMPs in the generic 19 aging lessons learned report or GALL Report. The 20 staff reviewed the initial 41 AMPs and documented the 21 results in the report dated May 9, 2017.
22 Region IV conducted a 71.02 inspection in 23 January and February of 2017 and documented the 24 results in a report dated March 31, 2017.
25 Based on the inspection results, the NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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23 1 Region IV team had reasonable assurance that Entergy's 2 program in place or planned as described in their 3 commitment table will manage the aging effects and 4 ensure the intended safety functions of safety, 5 structure, and components within the scope of the 6 rule. Next slide.
7 The Waterford final SER was issued on 8 August 17, 2018. During the staff's in-depth 9 technical review of the LRA, 119 RAIs were issued, 25 10 of which were follow-up RAIs. The final SER will be 11 published as a NUREG report following the issuance of 12 the renewed license.
13 The ACRS Subcommittee was held on 14 September 20, 2018 and there were no follow-up items 15 for the staff. Next slide.
16 MEMBER REMPE: I have a question. I did 17 not participate in the Subcommittee either, but I'm 18 just curious about the number of RAIs. Is this 19 typical? Is it going down as we go through more of 20 these plants and license renewal or how does this 21 compare to other -
22 MS. JAMES: Hello, my name is Lois James.
23 If I may, this is a low number. I worked on two other 24 plants that we had over 300, 360, 380, so the 119 is 25 relatively low for my recollection of history.
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24 1 MEMBER REMPE: In your opinion, is that 2 because this is a great licensee or is that because 3 everyone's understanding the process and the 4 expectations of the process?
5 MS. JAMES: I think at this point, it 6 would be understanding the process. We only have 7 about three or four left, I think, maybe five, and so 8 one of the things our management has been stressing is 9 that they need to look at old RAIs or previously 10 issued RAIs and make sure those get addressed, and I 11 think in general for license renewal, we're finding 12 that.
13 MEMBER REMPE: Great, thank you.
14 MR. OESTERLE: This is Eric Oesterle, 15 Chief of the License Renewal Projects Branch. So to 16 add to what Lois had mentioned, yes, the understanding 17 of the process is getting better, and one of the 18 things that the staff has been doing is communicating 19 expectations to applicants ahead of time that they 20 should be looking at RAIs that staff has issued on 21 previous applications.
22 And applicants have done that, and so 23 they've already answered questions then ahead of time 24 that we asked before, and so the number of questions 25 that we end up having to ask, you know, has NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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25 1 continuously trended downwards. And also as you'll 2 see in the next presentation on River Bend, we came in 3 around the same level of RAIs as on Waterford.
4 MEMBER SKILLMAN: I would like to make a 5 comment here. I've been looking at these for seven 6 years. I believe that the individuals who have been 7 preparing the license renewal applications have worked 8 hard to make sure that the initial submittal is 9 strong, accurate, and thorough.
10 And as Garry Young said when he introduced 11 himself, he's done about 12 of these, so I think 12 there's some credit to be given to Garry and the crew 13 that did this. They're getting better at this 14 process.
15 But it also may point to the degree to 16 which the plant owners have protected the material 17 condition of the plant, and from my experience, that's 18 critical. This plant is not falling down around 19 peoples' heads and shoulders.
20 This is a plant that's in good condition 21 because people have been taking care of it, but those 22 two need to go side by side in order to get to a very 23 low number of RAIs, and credit to the staff for having 24 a thick magnifying glass and being able to say, "This 25 is a low number." That's not by accident. It took an NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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26 1 awful lot of effort.
2 MR. OESTERLE: Yeah, we definitely agree 3 with your remarks, and we'll add that what we heard at 4 the Subcommittee meeting on September 20 was from the 5 regional inspector that the plant was in good material 6 condition.
7 MS. CLARK: In the next few slides, I'll 8 present the results of the staff's review as described 9 in the SER. SER Section 2 describes the scoping of 10 the system structures and components or SSCs and 11 screening of structures and components to identify 12 those subject to an aging management review of AMR.
13 The staff reviewed the applicant's scoping 14 and screening methodology, procedures, quality control 15 applicable to the LAR development, and training of its 16 personnel.
17 The staff also reviewed the various 18 summaries of the safety-related SSCs, non-safety SSCs 19 affecting safety functions, and the SSCs relied upon 20 to perform functions applicable to Waterford in 21 compliance with the Commission regulation for fire 22 protection, environmental qualifications, station 23 blackout, pressurized thermal shock, and anticipated 24 transience without a scram.
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27 1 the scoping and screening audit and additional 2 information provided by the applicant, the staff 3 concludes that the applicant's scoping and screening 4 methodology and implementation were consistent with 5 the standard review plan and the requirements of 10 6 CFR Part 54.
7 SER Section 3 and its subsections cover 8 the staff's review of the applicant's programs 9 managing aging in accordance with 10 CFR 54.21A3.
10 Sections 3.1 through 3.6 include the AMR items in each 11 of the general system areas within the scope of 12 license renewal. For a given AMR item, the staff 13 reviewed the item to determine whether it is 14 consistent with the GALL Report.
15 For AMR items not consistent with the GALL 16 Report, the staff reviewed the applicant's evaluation 17 to determine whether the applicant has demonstrated 18 that there is reasonable assurance that the effects of 19 aging will be adequately managed so that the intended 20 functions will be maintained consistent with the 21 current licensing basis for the period of extended 22 operation. Next slide.
23 The LAR described a total of 41 AMPs, 12 24 new, 29 existing, and one plant specific. This slide 25 identifies the applicant's disposition of these AMPs NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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28 1 in the left column and the staff's disposition in the 2 right column. The AMPs were evaluated by the staff's 3 consistency with the GALL Report.
4 During the staff's review, the applicant 5 changed the disposition of three AMPs based on NRC 6 requests for additional information. These AMPs are 7 in-service inspection changed from consistent in the 8 original LRA to consistent with enhancements.
9 Reactor vessel surveillance changed from 10 consistent in the original LRA to consistent with 11 enhancements and exceptions. Steam generator 12 integrity changed from consistent in the original LRA 13 to consistent with enhancements.
14 SER Section 4 identifies time limiting 15 aging analysis to TLAAs. Section 4.1 documents the 16 staff's evaluation of the applicant's identification 17 of applicable TLAAs.
18 The staff evaluated the applicant's basis 19 for identifying those plant specific or generic 20 analyses that need to be identified as TLAAs and 21 determined that the applicant has provided an adequate 22 list of TLAAs as required by 10 CFR 54.21C1.
23 Sections 4.2 through 4.7 document the 24 staff's review of the applicable Waterford TLAAs for 25 the areas shown on this slide. Based on its review NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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29 1 and the information provided by the applicant, the 2 staff concludes that either one, the analysis is valid 3 for the period of extended operation, two, the 4 analysis has been projected to the end of the period 5 of extended operation, or three, the effects of aging 6 on the intended functions will be adequately managed 7 for the period of extended operation as required by 10 8 CFR 21.C1 Subparagraphs I, ii, and iii respectively.
9 The staff finds that the requirements of 10 10 CFR 54.29A have been met for the license renewal of 11 Waterford. This concludes the staff's presentation.
12 We're available for any further questions from the 13 full Committee.
14 MEMBER SKILLMAN: Phyllis, thank you.
15 MS. CLARK: Thanks.
16 MEMBER SKILLMAN: Colleagues, any 17 questions for the staff in the matter of Waterford 3, 18 please?
19 MEMBER BALLINGER: Well, I have a 20 question, but it's for Entergy. We had an 21 unanticipated transient over here and the question is 22 does Entergy have other experience with SEA-CURE 23 tubing for condensers? Yeah, what experience does 24 Entergy have with SEA-CURE for tubing material for 25 condensers?
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30 1 MR. LANKA: This is Brian Lanka. Entergy, 2 to my knowledge, has not installed SEA-CURE yet. We 3 have installed titanium Fitzpatrick when we did own 4 them, but we have reached out to the industry, and 5 other utilities are using SEA-CURE.
6 MEMBER BALLINGER: Thank you.
7 MEMBER SKILLMAN: Colleagues, any other 8 question or questions for the staff in the matter of 9 Waterford 3?
10 MEMBER MARCH-LEUBA: Well, since nobody is 11 asking the question, do you evaluate ASR for Waterford 12 or ask any questions about it?
13 DR. HISER: I would expect that we looked 14 through the operating experience at Waterford, and we 15 did walk downs during the AMPs audit, and obviously 16 there were no indications of ASR identified.
17 MEMBER MARCH-LEUBA: Thank you.
18 MEMBER SKILLMAN: So with that, Allen, and 19 Phyllis, and Lois, thank you very much. And Mr.
20 Chairman, we're back to you.
21 CHAIRMAN CORRADINI: Okay, so here's what 22 we're going to do. We have the challenges of the 23 room, so we have to stick with the published schedule, 24 which means we cannot take up River Bend until 10:30 25 when it is scheduled. We're going to essentially go NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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31 1 off the record and we're going to look at the draft 2 letter report for Waterford now.
3 (Whereupon, the above-entitled matter went 4 off the record at 9:03 a.m. and resumed at 10:44 a.m.)
5 CHAIRMAN CORRADINI: Okay, why don't we 6 come back into session? We're going to now take on 7 our second subject which is the River Bend Station 8 license renewal, so I'll turn it back over to Member 9 Skillman. Dick, do you want to take it over?
10 MEMBER SKILLMAN: Yes, ladies and 11 gentlemen, thank you. We are picking up the second 12 license renewal application discussion. In this 13 discussion, we will hear from leaders from the River 14 Bend Station owned and operated by Entergy South. And 15 without further ado, I'm going to turn the microphone 16 over to Joe Donoghue from the NRC staff for the 17 remainder of this session, Joe?
18 MR. DONOGHUE: Thank you, Member Skillman, 19 and thank you, Chairman Corradini, and members of the 20 ACRS full Committee.
21 I'm Joe Donoghue. I'm the Deputy Director 22 of the Division of Materials and License Renewal in 23 the Office of Nuclear Reaction Regulations. We 24 sincerely appreciate the opportunity to brief the ACRS 25 full Committee on the River Bend license renewal NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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32 1 review that we've done.
2 As you know, the staff presented the 3 results of their review on the River Bend application 4 to the ACRS License Renewal Subcommittee on September 5 20 of this year. There were two follow-up items from 6 that meeting and the staff is prepared to discuss them 7 today.
8 The license renewal presentation today 9 from the staff will be led by Emmanuel Sayoc, and we 10 have other staff who will be participating in that 11 participation, Dr. Allen Hiser, our Senior Technical 12 Advisor for License Renewal.
13 Also here is Eric Oesterle, Chief of the 14 Project Branch in our Division, and in the audience 15 and on the phone, we have other technical staff and 16 management to support the presentation.
17 We look forward to a productive discussion 18 today with the full Committee, and as always, we'll 19 address any questions on our review that you may have, 20 and we look forward to receiving your recommendation 21 letter to support issuing the renewed license.
22 I'd like to turn the presentation over to 23 the Entergy team and their Site Vice President, Bill 24 Maguire, to introduce his team and commence their 25 presentation.
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33 1 MR. MAGUIRE: Thank you, Mr. Donoghue.
2 Good morning, Mr. Chairman and members of the ACRS.
3 My name is Bill Maguire. I'm the Site Vice President 4 at River Bend Station. We very much appreciate the 5 opportunity to present -
6 PARTICIPANT: I just think you got to get 7 close to it.
8 MR. MAGUIRE: Okay, I'll move the 9 microphone up. Is this better? Great, thank you.
10 Good morning. My name is Bill Maguire. I am the Site 11 Vice President at River Bend Station. We very much 12 appreciate the opportunity to review our license 13 renewal application with the Committee.
14 We have dedicated significant resources at 15 Entergy in the application presentation and 16 preparation, and we believe it got a very thorough 17 review by the staff, a very rigorous and detailed 18 review.
19 For this morning's discussion, we have 20 with us Mr. James Henderson. He's our Engineering 21 Director. He'll be talking about some of the plant 22 upgrades that we've done to ensure long-term reliable 23 operation of the station, Mr. Tim Schenk, our 24 Regulatory Assurance Manager, he'll go over the 25 background of the station, and Mr. Garry Young, our NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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34 1 Fleet Director for License Renewal.
2 Again, we thank you for this opportunity 3 today, and we welcome your questions and look forward 4 to discussion, and I'll turn over the presentation to 5 Mr. Tim Schenk.
6 MEMBER SKILLMAN: Before you do, Bill, 7 thank you for being here. Please speak to us on the 8 same topic that I asked the VP from Waterford 3, and 9 that is you are the exec at this site. You do cast a 10 shadow as the leader, and what is your vision of the 11 shadow that you cast relative to Appendix B to 10 CFR 12 10, your QA program?
13 MR. MAGUIRE: Well, thank you, Mr.
14 Skillman. I have a strong passion for our nuclear 15 independent oversight organization. That's how we 16 meet the Appendix B regulation, as well as our 17 commitment to a robust corrective action program.
18 Our nuclear oversight manager is a strong 19 leader with multi-site, multi-discipline experience.
20 He has reporting to him a robust organization that 21 represents all of the disciplines at the station, 22 engineering, operations, maintenance, technical team.
23 I have a responsibility to provide to him 24 a few members of the teams that are rotate 25 assignments, so we pick high quality personnel. For NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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35 1 example, we currently have a current senior reactor 2 operator license holder to rotate to the team to 3 ensure we get a good technical, rigorous review of our 4 control room operations, our field operations.
5 We also have a robust corrective action 6 program as I mentioned. As of this morning, we've 7 generated over 5,830 condition reports here to date, 8 so we have a very low threshold for problem 9 identification.
10 We also have in our Entergy management 11 model an articulated value for safety, and the tool 12 that we use to implement safety is what we call the 13 PDC model or prevention, detection, correction model, 14 and certainly we correct a number of issues at the 15 station through the corrective action program, but the 16 model is biased toward prevention and detection 17 activity.
18 So our operators are performing rounds, 19 our engineers are doing system health reports, all 20 intended to be out in the detection and prevention 21 mode so that our plant runs safely and reliably.
22 MEMBER SKILLMAN: Thank you, please 23 proceed.
24 MR. SCHENK: Thank you, Bill. This is Tim 25 Schenk. I'm the Regulatory Assurance Manager at River NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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36 1 Bend Station. River Bend is located in Louisiana, 2 West Feliciana Parish, approximately 24 miles north, 3 northwest of Baton Rouge.
4 It's a General Electric and Triple S 5 design. Stone and Webster was the constructor. We're 6 boiling water reactors six type. We have a General 7 Electric mark three containment and a GE turbine 8 generator.
9 Our ultimate heat sink is an independent 10 wet cooling tower. We have a closed circulating water 11 system with mechanical draft cooling towers, and we're 12 licensed to 3,091 megawatts thermal and our 13 approximate staff is 820 at this time.
14 Currently, our plant status is actually 75 15 percent power as of 0600 this morning. We had a 16 planned control rod pattern adjustment overnight and 17 we'll be ascending in power throughout the day today.
18 We're on a 24-month operating cycle in our 19 reactor oversight process. We're a column one plant.
20 Our last refueling outage was in the spring of 2017.
21 That was refueling outage number 19. Our next 22 refueling outage is scheduled for the spring of 2019 23 and that will be refueling outage number 20.
24 MEMBER SKILLMAN: Tim, what is your 25 capacity factor, please?
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37 1 MR. SCHENK: Our capacity factor for this 2 cycle is 84.5 percent.
3 MEMBER SKILLMAN: Are you experiencing 4 some equipment problems that are pushing you back from 5 90, 92, 94 percent?
6 MR. SCHENK: The biggest impact in our 7 capacity factor this cycle was a planned outage that 8 we took in January of 2018 to address fuel leaks.
9 MEMBER SKILLMAN: Yes, sir, thank you.
10 MEMBER MARCH-LEUBA: I was going to ask 11 about that. What fuel do you use? Who is your fuel 12 vendor, GE?
14 MEMBER MARCH-LEUBA: GNF, you use GNF too?
15 MR. SCHENK: Yes.
16 MEMBER MARCH-LEUBA: And you were having 17 leakage problems?
18 MR. SCHENK: Yes, sir, we have experienced 19 fuel leaks through this cycle.
20 MEMBER MARCH-LEUBA: Okay, thank you.
21 MEMBER SKILLMAN: Thank you. Please 22 continue.
23 MR. SCHENK: Some of the River Bend 24 licensing history, we received our construction permit 25 in 1977 and our operating license was in 1985, and we NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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38 1 commenced commercial operation in 1986. We were 2 operating initially at 2,894 megawatts thermal.
3 We received our first power up rate in the 4 year 2000 and went to 3,039 megawatts thermal, and 5 then we did another power up rate in 2003 for thermal 6 power optimization and that's where we're currently 7 at, 3,091 megawatts thermal.
8 Our license renewal application was 9 submitted in May of 2017 and our current operating 10 license will expire in August of 2025.
11 MEMBER REMPE: Do you have any plans for 12 other upgrades or MELLA+ separation or anything like 13 that?
14 MR. SCHENK: No, ma'am.
15 MEMBER REMPE: Why not?
16 MR. MAGUIRE: I can answer that. So while 17 the plant has the reactor capacity to add additional 18 megawatts from the plant, we would have to provide 19 additional balance of plant support to give that 20 margin, and right now, the economics would support us 21 using other forms of generation rather than adding 22 capacity to our existing plant.
23 MEMBER REMPE: Thank you.
24 MR. SCHENK: All right, with that, I'd 25 like to turn it over to our Engineering Director, NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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39 1 James Henderson.
2 MR. HENDERSON: Good morning. My name is 3 James Henderson. I am the Engineering Director at 4 River Bend Station. I want to go over a couple of 5 items. The first will be our major equipment upgrades 6 for the facility, and then we'll go over our planned 7 upgrades going forward.
8 The first thing that Entergy has done is 9 done a very good job of making sure we have major 10 investments looking at the long-term health and 11 reliability of the station, not just from an equipment 12 liability perspective, but also a safe and reliable 13 operation of the facility.
14 The first item is an upgrade to our 15 digital electro hydraulic control system. We'll have 16 a picture further on in the slide presentation and 17 we'll discuss further that upgrade that was performed.
18 We also have an upgrade for our control building 19 chilled water controls.
20 Those digital controls help with our 21 operators interface as well as diagnostics for 22 understanding and ability to troubleshoot and really 23 get in front of one of our safety-related chilled 24 water systems.
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40 1 circulating water piping. That coupled with quality 2 soil as well as our cathodic protection system really 3 helped improve the overall health for our circ water 4 system, and also the further bullets look at our 5 modernization of the plant, so -
6 MEMBER SKILLMAN: Excuse me, sir. Let me 7 ask this question and I'm curious from a personal 8 perspective. Is the mud or the dirt in which that 9 circ water piping prehistoric Mississippi mud that 10 attacks the piping?
11 And I ask that because I spent many years 12 in the Susquehanna River basin fighting this very 13 issue, so I'm wondering if it's the nature of the 14 water, or the nature of the dirt, or the combination.
15 Could you speak a little bit to it, please?
16 MR. HENDERSON: Yes, I could. Actually 17 it's the quality of the soil itself that's actually 18 helpful for our protection of that underground piping.
19 Unlike the Susquehanna plant that you mentioned, the 20 soil is actually one of our key barriers to maintain 21 the quality and structural integrity of the 22 underground piping.
23 So we've seen from that soil, in not only 24 the coating that we've done, vast improvements as far 25 as our corrosion programs.
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41 1 MEMBER SKILLMAN: Did you add different 2 soil to protect the pipe?
3 MR. HENDERSON: No, we did not. It's the 4 same soil.
5 MEMBER SKILLMAN: Okay, thank you.
6 MEMBER RICCARDELLA: Have you had leakage 7 issues?
8 MR. HENDERSON: We have not, and we do 9 underground inspections whenever we have any 10 opportunity to go in, not only just with our normal 11 requirements as a part of our program, and all of 12 those inspections have been satisfactory.
13 MEMBER SKILLMAN: Please proceed. Thank 14 you.
15 MR. HENDERSON: The next slide in our 16 presentation shows a representation of our digital 17 electro hydraulic control system. Those upgrades 18 eliminated on the order of 90 single point 19 vulnerabilities from the facility.
20 It also gave the interface for the 21 operations team to be able to not only perform 22 testing, but better diagnostic for the generation of 23 the plant and ensure that we don't have challenges 24 there.
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42 1 center breakers. This is just another example of 2 modernization to the plant. This dealt with a lot of 3 obsolescence that we had with some of our breakers in 4 the facility. Those have been changed and this has 5 improved overall reliability as well as our safety-6 related power performance.
7 The next slide is carbon steel piping 8 replacement. The system that's depicted here is our 9 reactor water cleanup system. We've gone in and 10 replaced carbon piping with new carbon piping as well 11 as chromoly.
12 That's helped improve the overall 13 reliability of our reactor water cleanup system as 14 well as a fact perspective, really helping the 15 reliability of the system.
16 The next slide goes through our major 17 equipment upgrades that are planned, the first being 18 our turbine building chiller replacements. Those will 19 complete in 2019. This is really to help with 20 generation as well as reliability for the station.
21 Our turbine chillers not only supply our turbine 22 building, but they also supply our main steam tunnel 23 associated with our reactor vessel.
24 MEMBER SKILLMAN: Jim, would you go back 25 a slide, please? For the reactor water cleanup piping NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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43 1 that was replaced, was this piping degradation 2 identified in your flow accelerated corrosion program?
3 MR. HENDERSON: Yes, it was.
4 MEMBER SKILLMAN: Oh, it was?
5 MR. HENDERSON: Yes, it was.
6 MEMBER SKILLMAN: And is this a 40-year 7 replacement that you are providing?
8 MR. HENDERSON: The replacement time 9 frame, I do not have that.
10 MEMBER SKILLMAN: No, no, how long is this 11 new piping going to be good for?
12 MR. HENDERSON: It will last for the 40 13 years.
14 MEMBER SKILLMAN: And does this pipe and 15 its attachments remain in your FAC program?
16 MR. HENDERSON: Yes, they do.
17 MEMBER SKILLMAN: Okay, thank you.
18 MEMBER BROWN: Could you go back another 19 slide? Right there, are those -- excuse me, I've got 20 to learn to do this too. Are those breakers digital 21 controls?
22 MR. HENDERSON: They are not. They have 23 indications as far as diagnostics for breaker amperage 24 and those things, but they are specifically at the 25 bucket of the breaker. They do not communicate with NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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44 1 the main control room or any other areas.
2 MEMBER BROWN: Okay, no internet 3 connections or anything like that?
4 MR. HENDERSON: That's correct.
5 MEMBER BROWN: Okay, that's fine. I might 6 have asked that earlier, but I forgot.
7 MR. HENDERSON: No worries.
8 MEMBER BROWN: Thank you.
9 MR. HENDERSON: The next item we'll talk 10 about is the spent fuel pool neutron absorber upgrade.
11 There's a slide going forward for a picture of that.
12 We also have condenser upgrades that will be taking 13 place in 2021. Similar to Waterford 3, we'll be going 14 with the secure piping for our retube.
15 We also have service water cooling heat 16 exchanger refurbs, our Fancy Point switchgear 17 upgrades. That's our offsite power source that comes 18 to the facility really making sure we have the 19 reliability and redundancy of offsite power coming to 20 the facility. That's an upgrade scheduled.
21 We also will be discussing the feedwater 22 strainer. I have a picture in the slide show for it 23 and that's related to the fuel failures that we've 24 seen that have been predominantly caused by foreign 25 material, and also our feedwater level control system NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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45 1 upgrades to a digital system which will eliminate 2 several of the single point vulnerabilities and 3 obsolescence concerns with our feedwater level control 4 system.
5 The next slide depicts our neutron 6 absorber prototype inserts. Currently we have 60 of 7 these inserts installed. They will help improve 8 neutron absorption in our spent fuel pool.
9 We've done the analysis for both seismic 10 as well as thermal impacts of having those inserts 11 into the core. Our plan is to in 2020, have an 12 engineering change that allows to take credit for 13 those as a part of our licensing basis.
14 MEMBER SKILLMAN: Jim, you said into the 15 core. I think what you meant is in the spent fuel 16 pool.
17 MR. HENDERSON: Spent fuel pool, that's 18 correct.
19 MEMBER SKILLMAN: Okay, thank you.
20 MEMBER REMPE: What material is that?
21 MR. HENDERSON: It's boron aluminum.
22 MEMBER RICCARDELLA: And is that going to 23 allow you to load more fuel in the condenser packing?
24 MR. HENDERSON: It will, and the intent 25 will be with the installation that we begin now, when NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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46 1 we get to 2020 with all of the analysis, we'll be able 2 to see what kind of additional capacity we'll have 3 based upon the inserts that we have in the spent fuel 4 pool.
5 MEMBER BALLINGER: You had boraflex before 6 that?
7 MR. HENDERSON: Yes, we did. We have the 8 boraflex inserts.
9 All right, our next slide depicts 10 strainers that will be installed in our feedwater 11 system. This is one of two strainers that will go in 12 the last point in our feedwater injection into the 13 vessel. We've had foreign material intrusion impacts 14 to our fuel. We have addressed the sources of those 15 foreign material.
16 This will be a preventive measure to allow 17 another means of collecting foreign material prior to 18 it getting into the vessel so that we don't have, 19 going forward, fuel failures at our facility. This 20 depiction is actually not the one that we're 21 installing, but this is just a representation of what 22 we'll have.
23 MEMBER MARCH-LEUBA: And you're planning 24 to install this during the next outage?
25 MR. HENDERSON: Yes.
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47 1 MEMBER MARCH-LEUBA: This was not part of 2 these reviews operating, I mean, on the scheduled 3 outages you had last cycle, right?
4 MR. HENDERSON: That's correct. This will 5 be in our next refueling outage in the spring of 2019.
6 And the final upgrade that I will discuss 7 is our feedwater level control. This will be a 8 digital upgrade. We have taken actions to bridge and 9 alleviate some of the concerns with our analog system 10 that we've had for feedwater level control. This will 11 improve with the SPV elimination as well as operator 12 interface, the ability to control reactor water level.
13 Some of the things that we're doing at the 14 station one is looking at OE from the industry as far 15 as impacts not only from a cyber security perspective 16 for installation of the system, but also the 17 effectiveness of the level control going forward, so 18 this is an item that we have on target for the station 19 as well.
20 With that, I'll turn over the presentation 21 to Garry Young.
22 MR. YOUNG: Okay, thank you. I'm Garry 23 Young, Director of License Renewal for the Entergy 24 nuclear fleet and I'd like to give you some background 25 on our license renewal process, including the approach NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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48 1 for the integrated plan assessment and for preparing 2 the license renewal application.
3 We have a dedicated corporate team working 4 on license renewal for all of the Entergy nuclear 5 plants, and this team with almost two decades of 6 experience with all aspects of aging management and 7 license renewal has prepared more than a dozen license 8 renewal applications over the past several years.
9 In addition to the corporate team, a plant 10 team of River Bend experts in design, systems 11 engineering, and plant programs was established for 12 this license renewal project. The plant team provided 13 needed input, review, and oversight of all the 14 engineering and environmental reports that were 15 created.
16 Entergy used the NRC-approved guidance in 17 NEI 95.10 to prepare the project specific procedures 18 and guidelines. These procedures have been used on 19 our previous license renewal projects and are 20 routinely updated based on lessons learned, industry 21 operating experience, and changes to NRC guidance.
22 The site specific aging management review 23 results for River Bend were compared to the GALL 24 Report, NUREG-1801, Revision 2, as part of the 25 application development, and I'll talk more about the NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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49 1 comparison of aging management programs with the GALL 2 Report on a later slide.
3 The license renewal application was 4 submitted to the NRC in May of 2017 and the NRC used 5 a new review process for the River Bend application 6 that included some efficiency improvements based on 7 lessons learned from previous NRC reviews.
8 This has proven to be a successful effort 9 by the NRC staff and has resulted in a planned 18-10 month review schedule rather than the typical 22-month 11 review schedule. Okay, next slide.
12 The NRC review process culminated in the 13 River Bend safety evaluation report which was issued 14 in August of 2018 with no open items and no 15 confirmatory items. We appreciate the extensive and 16 thorough work of the NRC staff in reaching this 17 important milestone in the license renewal application 18 review process. Okay, next slide.
19 This slide summarizes the aging management 20 programs credited for license renewal. We have 43 21 aging management programs that include 12 new programs 22 and 30 existing programs that are or will be 23 consistent with the GALL Report programs with a 24 handful of exceptions that are shown on this slide.
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50 1 the buried and underground piping and tanks inspection 2 program, the non-EQ cables and connections aging 3 management programs, and one-time inspection programs.
4 Some aspects of these new programs have 5 been implemented, but they are considered new programs 6 because a significant number of changes must be made 7 or have only recently been made to make them 8 consistent with the program descriptions in the GALL 9 Report.
10 For example, the River Bend buried piping 11 program was initiated in response to a 2009 NEI 12 initiative, but significant changes are necessary to 13 incorporate the latest NRC guidance which includes 14 interim staff guidance issued in 2015.
15 For clarity in describing the program, 16 Entergy classified it as a new program that would be 17 consistent with the program description in the most 18 recent NRC guidance.
19 MEMBER MARCH-LEUBA: What is the plant 20 specific program, the last bullet?
21 MR. YOUNG: That's the period surveillance 22 and preventive maintenance program.
23 MEMBER MARCH-LEUBA: That's not in other 24 plants?
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51 1 plants. It's an existing program and we use it when 2 we have some, for example, some preventive maintenance 3 activities that we can credit for aging management 4 such as inspections during some period frequency for 5 maintenance.
6 MEMBER MARCH-LEUBA: Yeah, but there's 7 nothing special about River Bend. All Entergy plants 8 have that?
9 MR. YOUNG: All of the Entergy plants have 10 it, yes.
11 MEMBER MARCH-LEUBA: Okay, I just was 12 reading something wrong in that bullet.
13 MR. YOUNG: Okay, the 30 existing programs 14 have been compared to the GALL programs, and only a 15 few exceptions have been taken. These exceptions 16 include such things as revised inspection intervals 17 based on the River Bend refueling outage schedules and 18 referencing NRC regulatory guides and industry 19 standards that are later revisions than those 20 referenced in the GALL Report which was published in 21 2010.
22 And then the last one is the plant 23 specific program which is the period surveillance and 24 preventive maintenance program. Okay, next slide.
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52 1 controlling the commitments that we've made for 2 license renewal, Entergy has a fleet program that 3 covers management of commitments for all our nuclear 4 plants.
5 We have successfully used this commitment 6 management program for our previous license renewal 7 projects, including projects for plants that have 8 implemented license renewal commitments and are 9 successfully operating in the period of extended 10 operation.
11 For each River Bend license renewal 12 commitment, the commitment management program 13 identifies the actions needed to implement the 14 commitments and identifies the owner responsible for 15 implementation.
16 Assignments will include actions such as 17 creation of implementing procedures for new aging 18 management programs and incorporating enhancements to 19 existing aging management programs, and this completes 20 my portion of the presentation and I'll turn it back 21 over to Bill.
22 MR. MAGUIRE: Thank you, Garry. In 23 summary, Entergy is committed to the long-term safe 24 and reliable operation of the River Bend facility.
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53 1 with 10 CFR 54. Entergy has evaluated time limited 2 aging analysis that require evaluation under 10 CFR 54 3 and we have met the provisions of 10 CFR 54 for 4 issuance of a renewed license. That concludes our 5 remarks pending your questions.
6 MEMBER SKILLMAN: Bill, thank you.
7 Colleagues, any questions, please, for the River Bend 8 management team?
9 MEMBER KIRCHNER: Could you go back to, 10 you mentioned issues with fuel leakage and then you 11 showed us a picture of a strainer, feedwater strainer.
12 What was the program or analysis that you did? Did 13 you see debris or crud on the fuel that was the cause 14 of the leakage and that led you to this planned step 15 to install a feedwater strainer or can you give us 16 some more detail on that issue, please?
17 MR. HENDERSON: Yes, so we've done 18 analysis for the fuel that has been removed from the 19 core with indications of fuel failure, and all of the 20 indications show or are indicative of foreign material 21 and debris.
22 The actions that I discussed earlier about 23 pinpointing the specific causes of those were very 24 foreign material potential systems that got into the 25 vessel, including our feedwater system and our NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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54 1 feedwater sparger probe, so those all have direct feed 2 into the vessel to cause a foreign material concern, 3 so that's where we narrowed down and pinpoints to go 4 address and correct.
5 The whole purpose of the strainer itself 6 was more of a prevention perspective to give us an 7 additional robust barrier between getting items 8 through our feedwater system into the vessel and cause 9 a potential fuel failure.
10 MEMBER BALLINGER: Was this foreign 11 material from the system or from maintenance which 12 introduced the foreign material into the system?
13 MR. HENDERSON: It was -- the first of it 14 was due to a failure of one of our feedwater 15 regulating valves.
16 MEMBER BALLINGER: Okay.
17 MR. HENDERSON: There was a Variseal 18 within that that failed and went in. The other item 19 was because of a conductivity probe that had broken 20 off and their operating experience about conductivity 21 probes breaking. That conductivity probe made its way 22 into our feedwater sparger and made a hole into the 23 sparger.
24 MEMBER BALLINGER: So these are from 25 systems? They're not from like a wire brush or NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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55 1 something?
2 MR. HENDERSON: No, that's correct. It is 3 not from maintenance practices.
4 MR. MAGUIRE: And this measure would not 5 have prevented the feed reg valve from failing or the 6 probe from failing, but it would have prevented those 7 components from getting into the reactor vessel and 8 causing fuel defects.
9 MEMBER KIRCHNER: So if I could follow up, 10 so the fuel failure was induced by this debris getting 11 caught in the fuel at a grid spacer or some place?
12 MR. MAGUIRE: Yes, sir.
13 MEMBER KIRCHNER: Or was it blocking the 14 channel, the flow into the bundle?
15 MR. MAGUIRE: It's at the grid spacer.
16 It's debris induced threading of the cladding of the 17 fuel that's causing the defects.
18 MEMBER KIRCHNER: So it wasn't a dry out 19 problem per se. It was more of an inter-middle 20 interaction kind of problem?
21 MR. MAGUIRE: You are correct.
22 MEMBER KIRCHNER: Did the first grid 23 spacer pick up the debris?
24 MR. MAGUIRE: We have -
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56 1 the cooler?
2 MR. MAGUIRE: The GNF comes with a fuel 3 defender, and the fuel defender provides a tortuous 4 path at the bottom of the fuel bundle so that if you 5 did have some debris entering the reactor core, the 6 probability of it getting inside the channel is low.
7 If it were to get past the defender, it 8 could get stuck at any number of the spacers along the 9 longitudinal length of the fuel bundle, and we have 10 seen defects at different heights in the fuel bundle, 11 typically at a spacer grid.
12 MEMBER KIRCHNER: Thank you.
13 MEMBER RICCARDELLA: You mentioned 14 feedwater sparger damage. Did this require 15 replacement of the sparger or just repair?
16 MR. HENDERSON: During our next refueling 17 outage, we have a clam shell, for lack of better 18 terms, that we're going to put over the sparger itself 19 which will repair the sparger and the hole that we 20 have indications of an issue with.
21 MEMBER MARCH-LEUBA: Just curious because 22 we have time, how do you know it was broken? I mean, 23 you saw it on the last refueling outage?
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57 1 over the area, and we identified the -
2 MEMBER MARCH-LEUBA: During refueling, it 3 was visual?
4 MR. HENDERSON: That's correct.
5 MEMBER RICCARDELLA: Was it the little 6 sparger nozzle, the little elbows, one of those or the 7 main pipe, sparger piping?
8 MR. HENDERSON: Yeah, if you can imagine 9 the actual sparger elbow, right on the side of the 10 elbow was where the hole had -
11 MEMBER REMPE: Okay, thank you.
12 MEMBER SKILLMAN: Colleagues, any further 13 questions for the River Bend executive team? Hearing 14 none, Joe, change out time. Entergy team, thank you.
15 MR. DONOGHUE: Chairman Corradini and 16 Committee, we're just about ready with our staff 17 presentation. As I said before, Emmanuel Sayoc, the 18 project manager who led this, will lead the 19 presentation. Allen Hiser, who you saw earlier today, 20 he's our senior technical advisor for license renewal, 21 and Angela Wu is a project manager that helped with 22 this review. Take it away.
23 MEMBER SKILLMAN: So, Angela, Emmanuel, 24 Allen, let's go. Thank you very much for being here 25 and let's go.
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58 1 MR. SAYOC: Good morning, Chairman 2 Corradini and members of the ACRS. My name is 3 Emmanuel Sayoc and I am the license renewal project 4 manager for the River Bend Station Unit 1 safety 5 review.
6 We are here today to discuss the staff's 7 review of the River Bend license renewal application 8 or LRA as discussed in the safety evaluation report 9 issued on August 16, 2018. Joining me here at the 10 table are Dr. Allen Hiser, senior technical advisor, 11 and Ms. Angela Wu, project manager from the Division 12 of Materials and License Renewal.
13 Seated in the audience are members of the 14 technical staff who participated in the review of the 15 license renewal application and conducted the onsite 16 audits and inspections. Next slide.
17 I will begin the presentation with a 18 general overview of the staff's review. Next, I will 19 touch upon follow-up items from the ACRS Subcommittee 20 meeting of September 20, 2018. As there were no open 21 items or confirmatory items in the SER, I will proceed 22 to the staff's review, follow-up items, and 23 conclusions. Next slide.
24 On May 25, 2017, Entergy Louisiana, LLC 25 and Entergy Operations, Inc., collectively referred to NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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59 1 as Entergy or the applicant, submitted an application 2 for renewal of River Bend operating license for an 3 additional 20 years.
4 Consistent with prior license renewal 5 reviews, the staff conducted the three standard audits 6 as shown in the slide, the operating experience audit, 7 the scoping and screening methodology audit, and the 8 aging management audit.
9 These audits were performed from NRC 10 headquarters, and the regional 71.02 inspection as 11 well as portions of the AMP audit were performed 12 onsite at River Bend.
13 During the operating experience audit, the 14 team conducted an independent search of plant 15 operating experience information to determine whether 16 the applicant's LRA aging management program can 17 adequately manage the associated aging effects. The 18 operating experience audits were documented in a 19 report dated January 18, 2018.
20 During the scoping and screening 21 methodology audit, the team reviewed the applicant's 22 administrative controls governing the scoping and 23 screening methodology and the technical basis for 24 selecting scoping and screening results. The scoping 25 and screening methodology audits were documented in a NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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60 1 report dated January 8, 2018.
2 During the AMP audits, the team examined 3 applicant's aging management programs and related 4 documentation to verify that the applicant's programs 5 are consistent with those described in the GALL Report 6 and with plant conditions and operating experience.
7 The staff documented the results in a report dated 8 January 29, 2018.
9 Region IV conducted a 71.02 inspection in 10 February and March 2018 and documented their results 11 in a report dated May 7, 2018.
12 Based on the inspection results, the 13 Region IV team had reasonable assurance that the 14 Entergy programs in place or planned as described in 15 their commitment table will manage the aging effects 16 and ensure the intended safety function of systems, 17 structures, and components within the scope of the 18 rule. Next slide, please.
19 The River Bend final SER was issued on 20 August 16, 2018. With the staff's in-depth technical 21 review of the LRA, a total of 119 RAIs were issued, 15 22 of which were follow-up RAIs. The final SER will be 23 issued with the renewed license and published as a 24 NUREG report.
25 The ACRS License Renewal Subcommittee NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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61 1 meeting was held on September 20, 2018. There were 2 two follow-up items from that meeting which I will 3 discuss later in the presentation. Next slide, 4 please.
5 In the next few slides, I will present the 6 results of the staff's review of the LAR as described 7 in the SER. SER Section 2 described the scoping of 8 SSCs and the screening of structures and components to 9 identify those subject to AMR.
10 The staff reviewed the applicant's scoping 11 and screening methodology, procedures, quality 12 controls applicable to the LAR development, and 13 training of its project personnel.
14 The staff also reviewed the various 15 summaries of safety-related systems, structures, and 16 components or SSCs, non-safety SSCs affecting safety 17 functions, and SSCs relied upon to perform functions 18 applicable to River Bend in compliance with the 19 Commission's regulations for fire protection, 20 environmental qualification, station blackout, and 21 anticipated transience without scram.
22 Based on the review results from the 23 scoping and screening audit and additional information 24 provided by the applicant, the staff concludes that 25 the applicant's scoping and screening methodology and NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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62 1 implementation were consistent with the standard 2 review plan and the requirements of 10 CFR Part 54.
3 Next slide, please.
4 SER Chapter 3 and its subsections cover 5 the staff's review of the applicant's programs for 6 managing aging in accordance with 10 CFR 54.21A3.
7 Sections 3.1 through 3.6 include AMR items 8 in each of the general system areas within the scope 9 of license renewal. For a given AMR item, the staff 10 reviewed the item to determine whether it is 11 consistent with the GALL Report.
12 For the AMR items not consistent with the 13 GALL Report, the staff reviewed the applicant's 14 evaluation to determine whether the applicant has 15 demonstrated reasonable assurance that the effects of 16 aging will be adequately managed so that the intended 17 functions will be maintained consistent with the 18 current licensing basis for the period of extended 19 operation. Next slide, please.
20 The LRA described a total of 43 aging 21 management programs, 11 new, 31 existing, and one 22 plant specific. This slide identifies the applicant's 23 disposition of AMPs in the left column and the staff's 24 disposition of AMPs on the right column.
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63 1 with the exception of the plant specific AMP were 2 evaluated by the staff for consistency with the GALL 3 Report Rev 2.
4 Overall, the staff concluded that 22 AMPs 5 were consistent with the GALL Report. These included 6 12 new programs, 10 existing programs. In addition, 7 13 programs were consistent with enhancements, two 8 consistent with exceptions, and five were consistent 9 with enhancements and exceptions. Next slide, please.
10 SER Section 4 identifies time-limited 11 aging analysis or TLAAs. Section 4.1 documents the 12 staff's evaluation of the applicant's identification 13 of applicable TLAAs.
14 The staff evaluated the applicant's basis 15 for identifying those plant specific or generic 16 analyses that need to be identified as TLAAs and 17 determined that the applicant has provided an accurate 18 list of TLAAs as required by 10 CFR 54.21C1.
19 Sections 4.2 through 4.7 document the 20 staff's review of applicable TLAAs as shown. Based on 21 its review and the information provided by the 22 applicant, the staff concludes that either one, the 23 analysis remain valid for the period of extended 24 operation, two, the analysis has been projected to the 25 end of the period of extended operation, or three, the NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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64 1 effects of aging on the intended functions will be 2 adequately managed for the period of extended 3 operation as required by 10 CFR 54.21C1 Subparagraphs 4 I, ii, and iii respectively. Next slide.
5 I will now discuss the two follow-up items 6 from the Subcommittee meeting. With regards to the 7 ACRS request for clarification on SER Section 8 2.1.4.2.1, the staff verified that the plant drain 9 system was the only non-safety SSC providing support 10 for safety functions under 10 CFR 54.4A1.
11 LRA Section 2.1.1.2.1, function failures 12 for non-safety related SSCs states that the systems 13 and structures required to support a safety function 14 are classified as safety related and have been 15 included in the scope of license renewal in accordance 16 with 10 CFR 54.4A1.
17 As a result, only one safety-related SSC 18 supporting a safety function was identified. That is 19 the plant drain system which supports maintaining 20 suppression pool inventory for use following a loss of 21 coolant accident and was therefore included within the 22 scope of license renewal in accordance with 10 CFR 23 54.4A2.
24 As verified by the staff, the plant drain 25 system is the only non-safety system credited in the NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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65 1 LRA for supporting a safety function and it's not just 2 an example. Next slide, please.
3 The second follow-up item was related to 4 the EDG crankcase vent lines. At the September 20 5 ACRS Subcommittee meeting, a concern was raised 6 regarding applicant's response to RAI 2.3.3.16-1.
7 The staff agreed that further 8 clarification of the applicant's RAI response was 9 warranted and the applicant agreed to supplement their 10 original RAI response to provide that clarification.
11 A supplemental response has been submitted 12 and the staff has completed its review and found it 13 acceptable. The staff has also updated the relevant 14 section of its SER and provided that to the ACRS.
15 In its supplemental RAI response, the 16 applicant clarified that with respect to the 17 application of the scoping criteria of 10 CFR 54.4A1, 18 the purpose of the vent pipe for Division I and II 19 emergency diesel engine is to vent the gases from the 20 diesel generator to the outdoors.
21 Upon loss of the vent pipe pressure 22 boundary, the gases would exhaust into the room, but 23 the diesel would continue to perform its function.
24 When the diesel is in operation, the room ventilation 25 system is in service venting the room.
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66 1 Therefore, the loss of pressure boundary 2 of this vent pipe has no impact on the diesel or 3 personnel and it has no safety function. The function 4 of venting the crankcase to the outdoors is not 5 necessary for the diesel to operate under emergency 6 conditions.
7 The applicant also clarified that the 8 Division III diesel engine removes the crankcase gases 9 via the engine and its exhaust line. In addition, 10 periodic surveillance testing confirms adequate 11 control of crankcase gases for Division I, II, and III 12 diesel engines.
13 With respect to the application of scoping 14 criteria of 10 CFR 54.4A2, non-safety related SSCs 15 whose failure could impact SSCs proving safety 16 function, the applicant clarified that for the 17 Division I and II emergency diesel engines, the non-18 safety related engine vent lines are not subject to 19 aging management review under 54.4A2 because the vent 20 lines contain no liquids that would impact other 21 components in the room from leakage or spray.
22 The vent lines are installed with seismic 23 supports that are subject to aging management review 24 and included in the structures monitoring program.
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67 1 unanalyzed load on the connection to the safety-2 related diesel engine that would render it unable to 3 perform its intended safety function under both normal 4 and seismic conditions.
5 The staff found these clarifications to 6 provide sufficient justification as to why the 7 Division I and II emergency diesel engine vent lines 8 are not within the scope of license renewal per the 9 criteria of 10 CFR 54.4A.
10 The staff updated the relaxant section of 11 the SER to include this clarification, has provided 12 that update to the ACRS, and considers this issue 13 fully resolved. Next slide, please.
14 In conclusion, on the basis of its safety 15 review, the staff finds that the requirements of 10 16 CFR 54.29A are met for the license renewal of River 17 Bend Station Unit 1. This concludes my presentation.
18 Now, if there are any questions, the staff would like 19 to take them at this time.
20 MEMBER SKILLMAN: Thank you, Manny.
21 Colleagues, any questions for the staff that conducted 22 the review here for River Bend?
23 MEMBER MARCH-LEUBA: I should have asked 24 the applicant the same question. Any concrete aging, 25 ASR concrete aging issues identified?
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68 1 MR. SAYOC: Yes, I have Brian Wittick 2 here, the Chief of the Structural Branch to further 3 elaborate.
4 MR. WITTICK: Yes, my name is Brian 5 Wittick. I'm the Branch Chief of the Structural 6 Engineering Branch that did the review. Similar to 7 Waterford, in reviewing their application, given the 8 amount of work we were doing on ASR at the time, we 9 were particularly sensitive to that particular effect, 10 and so we did a careful review of the operating 11 experience and corrective action program to verify 12 whether or not there was any indications of ASR for 13 River Bend. There were none.
14 And while we were onsite for other audit 15 activities, Angie Buford, who briefed you yesterday, 16 did walk downs in the plant and specifically did look 17 for any indications of ASR and found none.
18 MEMBER MARCH-LEUBA: Yeah, that's what I 19 was going to say, that just looking at the licensee 20 reports, maybe you wouldn't find anything. What you 21 need is a walk down through all the concrete 22 structures with somebody with a trained eye, and it 23 doesn't need to be the staff. It has to be the 24 licensee, the one that's looking for those clear 25 indications.
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69 1 MR. WITTICK: Correct.
2 MEMBER MARCH-LEUBA: And it doesn't cost 3 that much money. You just need to have a trained eye.
4 MEMBER REMPE: So when you looked for 5 indications, you not only looked for cracks, but you 6 also looked for any unexplained building movement, 7 right?
8 MR. WITTICK: Well, I'm not the structural 9 expert, but when she did her sampling inspections, she 10 said she specifically looked for any indications of 11 ASR and found none.
12 MEMBER REMPE: Thank you.
13 MEMBER KIRCHNER: Emmanuel, I wanted to go 14 back to the fuel question that I raised. So how does 15 this fit into your review? Obviously there was an 16 issue that the applicant has taken what appear to be 17 some appropriate corrective actions to address it.
18 How does that impact -- How does this fit into your 19 review, an issue like that where you have an operating 20 plant and they're seeking an extension or a renewal?
21 We were corrected earlier that plant 22 equipment upgrades aren't the same as committed 23 upgrades, but it seems like the applicant has 24 identified the strainer as one means to prevent 25 foreign objects from getting into the fuel, into the NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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70 1 core. So how does this -- how do you address that 2 issue as part of this license renewal process?
3 MR. SAYOC: I appreciate the question. As 4 far as the fuel issue and the strainers, that's not 5 within the scope of license renewal. That's a Part 50 6 operating within their scope. Does anybody else want 7 to elaborate from the staff?
8 DR. HISER: Yeah, so really this is not a 9 part of our review. We are focused on passive, long-10 lived systems, structures, and components, and the 11 fuel does not fit within that.
12 MEMBER KIRCHNER: I understand that. So 13 it's under the existing license under 10 CFR 50, but 14 when an issue -- maybe this is a more generic 15 question, not specific just to this plant, but when 16 you have an issue like that that's of concern, how 17 does that factor into your LRA review?
18 DR. HISER: If it's a, if it's operating 19 experience related to an item that's within the scope 20 of license renewal, then we would consider whether 21 that operating experience is consistent with the 22 boundaries of the appropriate GALL aging management 23 program, and if it exceeds the boundaries, then the 24 plant normally would implement some enhancement to 25 their program to adequately manage that aging effect NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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71 1 in the future.
2 For example, they may do more extensive 3 inspections. Instead of visual examination, they may 4 do ultrasonic. They may do inspections more 5 frequently than the GALL AMP would indicate.
6 MEMBER KIRCHNER: My concern is that this 7 falls kind of betwixt and between. It appears that 8 the applicant has a plan in place to address it, but 9 it is an aging effect if indeed parts or pieces get 10 into the primary system and then find their way into 11 the core.
12 Those parts are displaced because of 13 aging, or corrosion, or migration, whatever. How do 14 you -- you know, I understand you have these AMPs and 15 all of the GALL Report, but, I mean, this is a real 16 issue obviously for the existing license, but it also 17 suggests that there may be aging effects that impact 18 the license -
19 MEMBER SKILLMAN: I'd like to weigh in on 20 this. Well, let me chime in. I loaded eight lead 21 test assemblies one time. We thought we had found the 22 magic path through the swamp of fuel. All eight of 23 them fell apart. We had parts and pieces all over 24 TMI-1.
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72 1 design issue, the fuel, and we worked our way through 2 that very painfully as a team, worked our way through 3 that. So when a probe fails or a device fails, it's 4 not necessarily an aging issue. It can be simply a 5 mechanical failure.
6 So I think to try to couple the events 7 that triggered the installation of the feedwater 8 filter with AMP probably isn't cricket. From time to 9 time, the plants get older, things happen, or you 10 install a new device and the device doesn't function 11 the way it was advertised and you deal with it.
12 So I'm adverse to connecting what has 13 happened to the fuel at River Bend, if you will, to 14 either a failed AMP or lack of clairvoyance on the 15 plant staff. That fires some emotion in me that -
16 MEMBER KIRCHNER: That's not where I was 17 going with this. I'm just interested in exploring 18 this interface. You have something that has happened 19 due to aging of the plant. Either a component wears 20 out prematurely -- I mean, it wasn't an expected 21 failure, I don't think.
22 MEMBER SKILLMAN: Okay.
23 MEMBER KIRCHNER: So the plant is 24 operating. It's aging. Things will break. I 25 understand that. I was just concerned that this kind NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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73 1 of falls in a gap, an interesting gap. The fuel did 2 not fail because of the defect in the fuel design. It 3 was caused by something in the plant that had aged or 4 failed, and it's just an interesting -- I'm just 5 checking to see how this gets factored into the 6 license renewal.
7 MR. DONOGHUE: So Member Kirchner, this is 8 Joe Donoghue. I'm going to use a different example to 9 tell you our thought process, but before I get there, 10 what our expectation is is something like this gets 11 factored into the plant's programs to evaluate and 12 determine the cause. I can let them speak to that in 13 any detail, but leading to another example, the 14 Anchor/Darling valve problem.
15 When that occurred, one of the things that 16 we did working with the Division of Engineering was to 17 try to fully understand the cause of that to see if it 18 was an aging-related mechanism, to see if it needed to 19 be part of our license renewal, a normal, regular 20 license renewal protocol, and we determined not.
21 And I'll tell you that, you know, this is 22 an -- you're right. It's worth -- we have to look at 23 these and think about them, and pull the string on 24 what the cause is and see if it's an aging-related 25 one.
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74 1 And there's a list of other issues, and 2 I'll be as -- I'll illustrate it this way. In 3 George's office, the Director who is here, when there 4 are material-related issues that occur, he's got them 5 listed on his white board in his office, and for this 6 reason, we evaluate them.
7 We work closely with the Division of 8 Engineering. And if we determine, if it's determined 9 that it's an aging-related mechanism for a passive 10 component, we then have to consider how it's going to 11 be dealt with in a normal review protocol. Allen, do 12 you have more?
13 DR. HISER: The only other thing I would 14 say is passive long-lived, it's within the scope of 15 license renewal, and if it's not within the scope of 16 license renewal, it is not a part of our review, but 17 that does not obviate the plant needing to make 18 effective corrective actions to remediate a situation, 19 identify root cause, and things like that. That is 20 still -- that's a Part 50 process that is incumbent on 21 the plant.
22 MEMBER KIRCHNER: I know it's under the 23 existing license. I appreciate that, but let me ask 24 you, does the aging management program for reactor 25 vessels, internals, and coolant system, would that NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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75 1 pick this up going forward?
2 MR. MEDOFF: Hello, this is Jim Medoff of 3 the staff. I was the staff reviewer for the 4 applicant's reactor vessel internals program. We did 5 come across one example of a situation exactly what 6 you're talking about which was mentioned earlier in 7 the presentation, which was the hole in the feedwater 8 sparger.
9 As we've said, that is a Part 50 issue, 10 but we did assess whether it could potentially impact 11 the aging management programs. We did do our 12 appropriate due diligence. We turned it over to the 13 Division of Operating Reactor Licensing and with the 14 Region. We had several calls with the applicants on 15 the operating experience to determine whether there 16 would be any impacts on aging.
17 For instance, if you had a part that was 18 generated as a loose part, could it vibrate against 19 the reactor vessel or any of the internals and cause 20 them to wear away, which would be an aging effect, so 21 we did evaluate that. So it's not like we ignored 22 this.
23 We do evaluate specifically those effects 24 and our conclusion is after talking with the licensee, 25 hearing what the licensee had to say with us over the NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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76 1 phone, and in phone calls with counterparts that were 2 involved from the Division of Engineering and with the 3 regional office, we concluded there were no impacts, 4 that even though it was Part 50 driven event, that 5 could cause like an aging effect later on in one of 6 the components that was scoped in for renewal and 7 screening in for an aging management review.
8 In regards to the fuel assemblies, those 9 are never scoped for renewal. Those are -- they may 10 be scoped in for renewal, but they're never subject to 11 an aging management review because they're passive and 12 long lived. So operating experience involved with 13 those types of things would never come away. We 14 always leave it as a Part 50 issue.
15 MEMBER BALLINGER: So what you're saying 16 is this is a River Bend specific issue, not a BWR 17 generic issue? There's no other experience out in the 18 fleet where similar debris production has occurred?
19 MR. MEDOFF: No, I'm not saying that. I'm 20 saying because the fuel assemblies, they may be scoped 21 in for renewal, and they're not subject to AMR because 22 they're replaced on a specified time frame set by 23 their core offload, so experience like that would 24 never been considered for its impacts on aging because 25 they're not subject to AMR.
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77 1 MEMBER BALLINGER: Yeah, I'm not talking 2 about the fuel. I'm talking about the structure. So 3 have there been other similar cases where these 4 components have produced debris which ended up in the 5 vessel?
6 DR. HISER: I'm not aware of any. There 7 may be, but they have not -
8 MEMBER BALLINGER: But that would -
9 DR. HISER: They would be on a plant 10 specific basis. If the plant had a history of doing 11 that, then again, through the Part 50 original 12 operating license context, then they would take 13 appropriate measures to ensure that that doesn't 14 happen, that -
15 MEMBER BALLINGER: Okay, but I'm talking 16 about other plants as well. In other words, in other 17 BWRs, you're saying that this is a unique -- these 18 debris production devices were unique to this plant 19 and not to some other, and not likely to occur in 20 other similar plants?
21 DR. HISER: I don't know that I would say 22 either one of those. I'm not aware of other plants 23 that had these kinds of filters, and maybe River Bend 24 could comment on that, and there may be other plants 25 that have had issues with this.
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78 1 MEMBER BALLINGER: Okay.
2 MEMBER MARCH-LEUBA: All BWRs have leakage 3 at one time in their lives. I mean, this is a common 4 thing. It's not specific to River Bend.
5 MR. HENDERSON: This is James Henderson, 6 Engineering Director for River Bend. When we did look 7 at the conductivity probe failure that had the hole in 8 the sparger that caused some of the debris to get into 9 the vessel, there was Dresden that had a similar OE 10 where a conductivity probe had broken and caused an 11 issue in their feedwater spargers as well, so there is 12 industry operating experience for that.
13 MEMBER MARCH-LEUBA: Yeah, but you did 14 take positive steps by buying the GNF fuel with the 15 filter at the bottom because you know that fuels pass 16 in your system, and we found out there were not 17 sufficient enough, but you put in the additional 18 filter which is even better?
19 MR. HENDERSON: That's correct.
20 MEMBER MARCH-LEUBA: And the only thing I 21 can blame you for is during the license renewal, 22 you're trying to take credit for that filter when it 23 doesn't really belong there. That filter wasn't 24 really used for operating concerns. It has nothing to 25 do with the license renewal. You were just so proud NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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79 1 of it that you wanted to show us the picture, but it 2 didn't belong in this presentation.
3 MR. HENDERSON: The intent of the 4 inclusion in the presentation was just to show the 5 upgrades that we have planned for the station.
6 MEMBER MARCH-LEUBA: Yeah, so we're 7 confused because you put it in there when it really 8 doesn't belong.
9 MR. HENDERSON: I understand.
10 MEMBER KIRCHNER: Okay, thank you.
11 MEMBER SKILLMAN: Colleagues, any other 12 questions for the NRC staff, please?
13 MEMBER DIMITRIJEVIC: I have a question on 14 this follow up on the vent for the diesel generator 15 room. Is there any other electrical equipment there 16 like, you know, intermediate basks or controls? Is 17 there any, other than the diesel generator, is there 18 any other electrical equipment in that room, and if 19 yes, was then the room heat up calculation performed 20 to show that that can operate without the vent?
21 MR. SAYOC: Yes, I appreciate the 22 question. This is regarding the second follow up, 23 right, the emergency diesel generator grid lines?
24 MEMBER DIMITRIJEVIC: Right, right.
25 MR. SAYOC: Okay, I'd like to call upon NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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80 1 Mr. Dave Nold to elaborate on the follow-up item.
2 Thank you, David.
3 MR. NOLD: This is David Nold with the 4 Containment and Ventilation Systems Branch. With 5 respect to other equipment, safety-related equipment 6 in the area of the vent lines, is that what you're 7 talking about?
8 According, well, all I had to do was rely 9 on the answer of the supplemental response, was the 10 fact that these pipes do not leak. They do not 11 contain fluid. There's no potential impact there.
12 MEMBER DIMITRIJEVIC: My concern was about 13 other electrical equipment in this diesel generator 14 room, like a bask which the diesel generator connects 15 to and goes to the emergency switch or the controls 16 for the diesel generator. Is there any other 17 electrical equipment which can be sensitive to 18 temperature? That's my concern.
19 MR. NOLD: Temperature.
20 MEMBER DIMITRIJEVIC: Yes.
21 MR. HENDERSON: This is James Henderson 22 with River Bend Station, Engineering Director. For 23 the emergency diesel generator room, there are no 24 other switch gears that are in the room. It is only 25 the diesel generator. There's a control room that is NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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81 1 next to the room. It's separated by a fire-rated 2 door, but that room only has auxiliaries that support 3 the diesel generator function.
4 MEMBER DIMITRIJEVIC: And which 5 auxiliaries are in that room?
6 MR. HENDERSON: It's related to -- there's 7 an equipment room, the air compressors associated with 8 the diesel, some of the jacket water pumps. Those 9 power supplies come within that diesel generator room.
10 It's not a cross-divisional, other power supplies or 11 electrical buses there.
12 MEMBER DIMITRIJEVIC: And none of this 13 equipment is sensitive to the temperature heat up in 14 the room?
15 MR. HENDERSON: That's correct.
16 MEMBER DIMITRIJEVIC: All right, so is 17 this the case in other applications? Did you always 18 see the venting to the diesel generator room is out of 19 the scope? We just had Waterford this morning, so, I 20 mean, I was just wondering. Did they also exclude it?
21 MR. NOLD: When I first got feedback on 22 this issue, I did do a search of other license 23 renewal, the SEs. I couldn't find anything that this 24 ever has been surfaced before this question, so it is 25 unique as far as I know.
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82 1 MEMBER DIMITRIJEVIC: All right.
2 MEMBER SKILLMAN: Colleagues, any other 3 questions for the staff? Hearing none, Manny, thank 4 you, and Mike, back to you.
5 CHAIRMAN CORRADINI: Okay, what we're 6 going to do is take a break for lunch and come back at 7 1:00. We're off the record after this discussion 8 because we'll be going through our draft slides to 9 report to the Commission for our December meeting. So 10 we'll be back here, the Committee will be back here at 11 1:00.
12 For those on River Bend that want to see 13 and be present for the letter making session, that 14 will probably be something around 2:00 to 2:15.
15 You're more than welcome to stay and listen to us 16 prepare slides for the Commission, but I sense that 17 you might have other profitable things to do.
18 MEMBER REMPE: Mike, just to make sure 19 that we're in compliance -
20 CHAIRMAN CORRADINI: We're in compliance.
21 I checked.
22 MEMBER REMPE: Did you adjust -
23 CHAIRMAN CORRADINI: Yes.
24 MEMBER REMPE: Okay.
25 MEMBER MARCH-LEUBA: And we're off the NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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83 1 record for the rest of the week, so he can go home?
2 CHAIRMAN CORRADINI: I just said that.
3 Yeah, he's off. We're off the record.
4 (Whereupon, the above-entitled matter went 5 off the record at 11:49 a.m.)
6 7
8 9
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Waterford 3 License Renewal
Entergy Presenters Name Title John Dinelli Site Vice President, Waterford 3 Brian Lanka Director, Engineering John Jarrell Sr. Manager, Operations Garry Young Director, License Renewal 1
Agenda
- Background
- Site Description
- Plant Status
- Licensing History
- Major Equipment Upgrades
- License Renewal Project
- Aging Management Programs and Commitments
- Conclusion 2
Waterford 3 Site Description
- Located on Mississippi River 25 miles upriver from New Orleans in St. Charles Parish
- Combustion Engineering NSSS
- EBASCO (AE and constructor)
- Dry containment 3
Waterford 3 Site Description
- Westinghouse turbine generator
- Ultimate heat sink is combination dry & wet cooling towers independent from river
- Licensed thermal power is 3716 MWT
- Staff complement is approximately 751 4
Waterford 3 Plant Status
- Plant Status
- 100% power
- Refueling cycle - 18 months
- ROP action matrix Column 1
- Last Refueling Outage
- RF21 (Spring 2017)
- Next Refueling Outage
- RF22 (Early 2019) 5
Waterford 3 Licensing History Construction Permit November 14, 1974 Operating License March 16, 1985 Commercial Operation September 24, 1985 8% Power Uprate April 15, 2005 LRA Submitted March 16, 2016 Operating License Expiration December 18, 2024 6
Major Equipment Upgrades Completed
- Replaced reactor coolant pump motors
- Added emergency diesel generator fuel storage tanks
- Upgraded static uninterruptable power supplies
- Replaced intake structure traveling screens
- Replaced steam generators
- Replaced reactor vessel head
- Replaced refueling machine 7
Photos - New Traveling Screens 8
Photos - New Steam Generators 9
Photos - New Reactor Head 10
Major Equipment Upgrades Planned
- Retube main condensers
- Replace core protection calculators
- Upgrade turbine controls
- Replace essential chillers
- Ultimate heat sink (UHS) improvements
- Replace UHS motor control center 11
Waterford 3 License Renewal Project
- Experienced, multi-discipline Entergy team (corporate and site personnel) prepared the license renewal application (LRA)
- Incorporated lessons learned from previous applications
- Used NEI 95-10 guidance
- Scoping and screening process
- Aging management reviews
- LRA format and content
- Used Revision 2 of NUREG-1801 12
Safety Evaluation Report
- SER issued August 17, 2018
- No open items
- No confirmatory items 13
Aging Management Programs
- 41 Aging Management Programs
- 12 new programs
- 10 consistent
- 2 consistent with exceptions
- 28 existing programs
- 6 consistent
- 19 consistent with enhancements
- 3 consistent with exceptions and enhancements
- 1 existing plant-specific program with enhancements 14
Program Commitment Implementation
- Regulatory commitments in the commitment management system to track enhancements to existing programs and implementation of new programs
- Entergy has significant experience with license renewal commitment implementation
Conclusion
- Entergy is committed to the long-term operation and continuous improvement of our facilities
- Entergy will manage the effects of aging in accordance with 10 CFR 54.21(a)(1)
- Entergy has evaluated time-limited aging analyses that require evaluation under 10 CFR 54.21(c)
- Entergy has met the provisions of 10 CFR 54 for issuance of a renewed license 16
Advisory Committee on Reactor Safeguards Waterford Steam Electric Station, Unit 3 Safety Evaluation Report (SER)
November 1, 2018 Phyllis Clark, Project Manager Office of Nuclear Reactor Regulation
Presentation Outline
- Overview of Waterford license renewal review
- SER Section 2, Scoping and Screening Review
- SER Section 3, Aging Management Review
- SER Section 4, Time-Limited Aging Analyses
- Conclusion 2
License Renewal Review:
Audits and Inspections Audit / Inspection Dates Location Scoping & Screening June 13 - 16, 2016 Onsite Methodology Audit Aging Management July 11 - July 29, 2016 Onsite Program (AMP) Audits Region IV 71002 Inspection: Scoping and January 30 - February 16, 2017 Onsite Screening and AMPs 3
SER Overview
- Final SER issued August 17, 2018
- Waterford SER contains no open items
- 119 RAIs issued
- 25 of which were follow-up RAIs
- ACRS License Renewal Subcommittee meeting held September 20, 2018 4
SER Section 2
- Structures and Components Subject to Aging Management Review (AMR)
- Section 2.1, Scoping and Screening Methodology
- Section 2.2, Plant Level Scoping Results
- Sections 2.3, 2.4, 2.5, Scoping and Screening Results 5
SER Section 3
- Aging Management Review (AMR) Results
- Section 3.0, Use of the Generic Aging Lessons Learned Report
- Section 3.1, Reactor Vessel, Internals, and Reactor Coolant System
- Section 3.2, Engineered Safety Features Systems
- Section 3.3, Auxiliary Systems
- Section 3.4, Steam and Power Conversion Systems
- Section 3.5, Structures and Component Supports
- Section 3.6, Electrical and Instrumentation and Controls Components 6
SER Section 3 3.0.3 - Aging Management Programs (AMPs)
Applicants Original Disposition Final Disposition of AMPs of AMPs in SER
- 12 new programs
- 12 new programs 10 consistent 10 consistent 2 consistent with exceptions 2 consistent with exceptions
- 29 existing programs
- 29 existing programs
- 9 consistent - 6 consistent
- 17 consistent with - 19 consistent with enhancements enhancements
- 2 consistent with - 3 consistent with enhancements enhancements and exceptions and exceptions
- 1 plant specific - 1 plant specific 7
SER Section 4
- Time-Limited Aging Analyses (TLAAs)
- 4.1, Identification of TLAAs
- 4.2, Reactor Vessel Neutron Embrittlement
- 4.3, Metal Fatigue
- 4.4, Environmental Qualification of Electric Equipment
- 4.5, Concrete Containment Tendon Prestress
- 4.6, Containment Liner Plate, Metal Containments, and Penetrations Fatigue Analysis
- 4.7, Other Plant-Specific TLAAs 8
Conclusion
- On the basis of its review, the staff finds that the requirements of 10 CFR 54.29(a) have been met for the license renewal of Waterford Steam Electric Station, Unit 3.
9
River Bend Station License Renewal
Entergy Presenters Name Title Bill Maguire Site Vice President James Henderson Director, Engineering Tim Schenk Manager, Regulatory Assurance Garry Young Director, Fleet License Renewal 1
Agenda
- Background
- Site Description
- Plant Status
- Licensing History
- Major Equipment Upgrades
- License Renewal Project
- License Renewal Application (LRA)
- Aging Management Programs and Commitments
- Conclusion 2
RBS Site Description
- Located in West Feliciana Parish, Louisiana, approximately 24 miles north-northwest of Baton Rouge, Louisiana
- General Electric NSSS - Stone & Webster (constructor)
- BWR-6, GE Mark III containment
- GE turbine generator 3
RBS Site Description
- Ultimate heat sink is independent wet cooling tower
- Closed circulating water system with mechanical draft cooling towers
- Licensed thermal power - 3091 MWt
- Staff complement - approximately 820 4
RBS Plant Status
- Plant Status
- 100% power month cycle
- ROP action matrix Column 1
- Last Refueling Outage
- RF19 (Spring 2017)
- Next Refueling Outage
- RF20 (Spring 2019) 5
RBS Licensing History Construction Permit March 25, 1977 Operating License November 20, 1985 Commercial Operation June 16, 1986 5% Power Uprate November 2000 Power Uprate License January 31, 2003 Amendment (1.7% Thermal Power Optimization)
LRA Submitted May 25, 2017 Operating License Expiration August 29, 2025 6
Major Equipment Upgrades Completed
- Upgraded digital EHC turbine controls
- Upgraded control building chiller controls
- Recoated underground circulating water piping
- Replaced inverters
- Replaced carbon steel piping
- Upgraded normal service water cooling tower
- Replaced 4th point feedwater heaters
- Upgraded 480 V load center breakers 7
Photos - Digital EHC Human Machine Interface for EHC on the H13-P680 Panel 8
Photos - 480 V Loadcenter Breakers 9
Photos - Carbon Steel Piping Replacement Carbon Steel Piping Replacement in RF-18 and RF-19 Old Carbon Steel removed New Carbon Steel Piping New Carbon Steel Piping 10
Major Equipment Upgrades Planned
- Turbine building chiller replacements
- Spent fuel pool neutron absorber upgrade
- Condenser upgrades
- Service water cooling heat exchanger refurbishment
- Fancy Point switchyard upgrades
- Recirculation pump power cable replacement
- Feedwater strainer
- Feedwater level control 11
Photos - Neutron Absorber Prototype Inserts Start of absorber insertion Full insertion. Ready to retract tool 12
Photos - Feedwater Strainer 13
Photos - Feedwater Level Controls 14
RBS MajorLicense Renewal Equipment Project Upgrades
- Experienced, multi-discipline Entergy team (corporate and site personnel) prepared the license renewal application (LRA)
- Incorporated lessons learned from previous applications
- Used NEI 95-10 guidance
- Scoping and screening process
- Aging management review
- LRA format and content
- Used Revision 2 of NUREG-1801
- 18-month NRC review schedule 15
Safety Evaluation Report
- SER issued August 2018
- No open items
- No confirmatory items 16
Major Aging Equipment Management Upgrades Programs and Regulatory Commitments
- 43 Aging Management Programs
- 12 new programs
- 12 consistent without exception
- 30 existing programs
- 10 consistent without exception
- 13 consistent with enhancements
- 2 consistent with exceptions
- 5 consistent with exceptions and enhancements
- 1 existing plant-specific program with enhancements 17
Program Commitment Implementation
- Regulatory commitments in the commitment management system track enhancements to existing programs and implementation of new programs
- Entergy has significant experience with license renewal commitment implementation
Conclusion
- Entergy is committed to the long-term operation and continuous improvement of our facilities.
- Entergy will manage the effects of aging in accordance with 10 CFR 54.21(a)(1)
- Entergy has evaluated time-limited aging analyses that require evaluation under 10 CFR 54.21(c)
- Entergy has met provisions of 10 CFR 54 for issuance of a renewed license.
19
Advisory Committee on Reactor Safeguards Full Committee River Bend Nuclear Generating Station Safety Evaluation Report (SER)
November 1, 2018 Emmanuel Sayoc, Project Manager Office of Nuclear Reactor Regulation
Presentation Outline
- Overview of River Bend license renewal review
- Follow-Up Items from Sub-committee Meeting
- Conclusion 2
License Renewal Review:
Audits and Inspections Audit / Inspection Dates Location Operating Experience October 2 - 13, 2017 Rockville Audit Scoping & Screening October 24 - 26, 2017 Onsite Methodology Audit Aging Management October 16 - November 8, 2017 NRC HQ Program (AMP) Audits November 6 - 10, 2017 Onsite Region IV 71002 February 26 - March 2, 2018 Onsite Inspection: Scoping, March 19 - 23, 2018 Screening, and AMPs 3
SER Overview
- Final SER issued August 16, 2018
- No open items or confirmatory items
- Total of 119 RAIs issued
- 15 follow-up RAIs
- ACRS License Renewal Subcommittee meeting held September 20, 2018 4
SER Section 2
- Structures and Components Subject to Aging Management Review (AMR)
- Section 2.1: Scoping and Screening Methodology
- Section 2.2: Plant-Level Scoping Results
- Sections 2.3, 2.4, 2.5: Scoping and Screening Results 5
SER Section 3
- Aging Management Review (AMR) Results
- Section 3.1: Aging Management of Reactor Vessel, Internals, and Reactor Coolant System
- Section 3.2: Aging Management of Engineered Safety Features
- Section 3.3: Aging Management of Auxiliary Systems
- Section 3.4: Aging Management of Steam and Power Conversion Systems
- Section 3.5: Aging Management of Containments, Structures and Component Supports
- Section 3.6: Aging Management of Electrical Commodity Group 6
SER Section 3 3.0.3 - Aging Management Programs (AMPs)
Applicants Disposition of AMPs Final Disposition of AMPs in SER
- 11 new programs
- 12 new programs All consistent All consistent
- 31 existing programs
- 30 existing programs 12 consistent 10 consistent 13 consistent with enhancements 13 consistent with enhancements 2 consistent with exceptions 2 consistent with exceptions 4 consistent with enhancements 5 consistent with enhancements and exceptions and exceptions
- 1 plant-specific existing program
- 1 plant-specific existing program 7
SER Section 4
- Time-Limited Aging Analyses (TLAAs)
- 4.1: Identification of TLAAs
- 4.2: Reactor Vessel Neutron Embrittlement Analyses
- 4.3: Metal Fatigue Analyses
- 4.4: Environmental Qualification of Electric Equipment
- 4.5: Concrete Containment Tendon Prestress Analyses
- 4.6: Containment Liner Plate, Metal Containment, and Penetrations Fatigue Analyses
- 4.7: Other Plant-Specific TLAAs 8
Non-Safety SSC Supporting Safety SSC Function
- Follow-up Item:
- In SER Section 2.1.4.2.1 is the plant drains system the only system under category - Nonsafety-Related Systems, Structures, or Components (SSCs) Providing Functional Support for Safety Related SSC Functions, or was it an example?
- Response:
- The plant drains system was the only SSC falling under said category.
9
RAI 2.3.3.16-1: EDG Crankcase Vent Lines Not Subject to AMR
- Follow-up Item:
- ACRS identified concern re: RAI response regarding the Division I &
II Emergency Diesel Engine (EDG) vent lines being not necessary for the diesels to operate under emergency conditions.
- Information provided in initial RAI response did not clearly provide technical justification as to why the vent lines did not have either 54.4(a)(1) or (a)(2) function.
- Resolution:
- Applicant provided additional clarification via an RAI supplement dated October 9, 2018.
- The RAI supplement included sufficient clarification for the staff to concur that the subject EDG vent lines do not meet the criteria of 54.4(a)(1) or (a)(2) for inclusion within the scope of license renewal.
10
Conclusion On the basis of its review, the staff finds that the requirements of 10 CFR 54.29(a) have been met for the license renewal of River Bend Station, Unit 1.
11