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
NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 www.nealrgross.com 1
1 2
3 DISCLAIMER 4
5 6
UNITED STATES NUCLEAR REGULATORY COMMISSIONS 7
ADVISORY COMMITTEE ON REACTOR SAFEGUARDS 8
9 10 The contents of this transcript of the 11 proceeding of the United States Nuclear Regulatory 12 Commission Advisory Committee on Reactor Safeguards, 13 as reported herein, is a record of the discussions 14 recorded at the meeting.
15 16 This transcript has not been reviewed, 17 corrected, and edited, and it may contain 18 inaccuracies.
19 20 21 22 23
1 UNITED STATES OF AMERICA 1
NUCLEAR REGULATORY COMMISSION 2
+ + + + +
3 658TH MEETING 4
ADVISORY COMMITTEE ON REACTOR SAFEGUARDS 5
(ACRS) 6
+ + + + +
7 THURSDAY 8
NOVEMBER 1, 2018 9
+ + + + +
10 ROCKVILLE, MARYLAND 11
+ + + + +
12 The Advisory Committee met at the Nuclear 13 Regulatory Commission, Three White Flint North, Rooms 14 1C3 & 1C5, 11601 Landsdown Street, at 8:30 a.m.,
15 Michael L. Corradini, Chairman, presiding.
16 17 COMMITTEE MEMBERS:
18 MICHAEL L. CORRADINI, Chairman 19 PETER RICCARDELLA, Vice Chairman 20 RONALD G. BALLINGER, Member 21 CHARLES H. BROWN, JR. Member 22 MARGARET SZE-TAI Y. CHU, Member 23 VESNA B. DIMITRIJEVIC, Member 24 WALTER L. KIRCHNER, Member 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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2 JOSE MARCH-LEUBA, Member 1
JOY L. REMPE, Member 2
GORDON R. SKILLMAN, Member 3
4 DESIGNATED FEDERAL OFFICIAL:
5 KENT HOWARD 6
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 AGENDA 1
Opening Remarks by the ACRS Chairman......
4 2
Waterford Steam Electric Station, Unit 3 License 3
Renewal Application 8
4 River Bend Nuclear Generating Station, Unit 1 5
....... 31 6
Adjourn..................... 83 7
8 9
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4 P R O C E E D I N G S 1
8:29 a.m.
2 CHAIRMAN CORRADINI: Okay, why don't we 3
get started? The meeting will come to order now.
4 This is the first day of the 658th meeting of the 5
Advisory Committee on Reactor Safeguards.
6 During today's meeting, the Committee will 7
consider the following, the Waterford Steam Electric 8
Station Unit 3 license renewal application, River Bend 9
Nuclear Generating Station Unit 1 license renewal 10 application, preparation for the meeting with the 11 Commission in December, and preparation of ACRS letter 12 reports.
13 The ACRS was established by statute and is 14 governed by the Federal Advisory Committee Act, or 15 FACA. As such, this meeting is being conducted in 16 accordance with the provisions of FACA. That means 17 the Committee can only speak through its published 18 letter reports. We hold meetings to gather 19 information to support our deliberations.
20 Interested parties who wish to provide 21 comments can contact our offices requesting time after 22 the Federal Register notice describing a meeting is 23 published. That said, we also set aside 10 minutes 24 for extemporaneous comments from members of the public 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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5 attending or listening to our meetings on the line.
1 Written comments are also welcome. Today, Mr. Ken 2
Howard is the designated federal official for the 3
initial portion of the meeting.
4 The ACRS section of the U.S. NRC public 5
website provides our charter, bylaws, letter reports, 6
and full transcripts of all our full and subcommittee 7
meetings, including all slides presented at those 8
meetings.
9 We've received no written comments or 10 requests to make oral statements from members of the 11 public regarding today's session, and also there will 12 be a phone bridge line open and on mute. To preclude 13 interruption of the meeting, it will be on a listen in 14 only mode during the presentations and Committee 15 discussions.
16 I also want to remind everybody to please 17 silence their devices, all your various types of 18 devices. Make sure we don't have any beeps, or bops, 19 or rings.
20 Also, this is a temporary room where we 21 hold our meetings and the audio, I'll just say, is 22 challenging, so my suggestion is when you turn on the 23 mic, make sure you have the green light on and you 24 kind of have to speak into it, otherwise you kind of 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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6 drift away for those listening in on the phone line or 1
the bridge line.
2 A transcript of portions of the meeting is 3
being kept and it's requested that the speakers use 4
one of the microphones, identify themselves, and speak 5
with sufficient clarity and volume so we can be 6
readily heard.
7 I'll turn the meeting over to Member 8
Skillman.
9 MEMBER SKILLMAN: Mr. Chairman, thank you.
10 This is plant week at ACRS. Yesterday, we did alkali-11 silica reaction for Seabrook, and today we're 12 privileged to have the team from Entergy, two teams, 13 one for Waterford 3 license renewal for 20 years, and 14 the second meeting will be River Bend team license 15 renewal for 20 years.
16 So thank you, everybody, and now I'm going 17 to turn the meeting over to Joe Donoghue as he 18 introduces the meeting, Joe?
19 MR. DONOGHUE: Good morning. Thank you, 20 Member Skillman. Thank you, Chairman Corradini and 21 members of the ACRS full Committee. I'm Joe Donoghue.
22 I'm the Deputy Director in the Division of Materials 23 and License Renewal at NRR, and next to me is George 24 Wilson, the Director.
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7 We sincerely appreciate the opportunity to 1
brief the Committee on the status review of the 2
Waterford license renewal application.
3 As you know, the staff presented the 4
results of their review of the Waterford renewal 5
application to the ACRS Subcommittee, the License 6
Renewal Subcommittee on September 20 of this year.
7 There were no follow ups from the meeting on 8
Waterford.
9 The license renewal presentations today 10 will be led by the following staff, Phyllis Clark, and 11 at the table will be Dr. Allen Hiser, our Senior 12 Technical Advisor. With me is Eric Oesterle. He's a 13 Chief of the Projects Branch in our Division, and in 14 the audience are other staff who conducted the review, 15 and management as well.
16 We look forward to a productive discussion 17 today with the full Committee, and as always, we will 18 address any questions on our reviews that you may 19 have.
We look forward to receiving your 20 recommendation letter on our review.
21 At this time, I'd like to turn the 22 presentation over to the Entergy team and their Site 23 Vice President, Mr. John Dinelli, to introduce his 24 team and commence their presentation.
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8 MR. DINELLI: Thank you. Good morning.
1 My name is John Dinelli and I'm the Site Vice 2
President at the Waterford 3 Steam Electric Station 3
responsible for the safe and reliable operation of the 4
facility.
5 This is an important day for Waterford.
6 We at Entergy have been working for several years to 7
get ready for the period of extended operation at 8
Waterford.
9 In today's presentation, you will hear 10 about major equipment upgrades as well as the 11 establishment of fleet aging management programs in 12 support of that effort.
13 We have with us today from Waterford, 14 Brian Lanka, the Director of Engineering, John 15 Jarrell, the Senior Manager of Operations, and Garry 16 Young, Director of License Renewal. We also have 17 other project and technical personnel in attendance 18 should their input be necessary.
19 And today's agenda for this presentation 20 it to describe the Waterford Station, plant status, 21 and our licensing history. We will also address major 22 equipment upgrades, both completed and planned, that 23 will help us prepare for the extended period of 24 operation. In addition, we will discuss the license 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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9 renewal project itself.
1 We want to thank you for the opportunity 2
today. This is a very important day and a major 3
milestone for Waterford 3 and for Entergy. Now I'll 4
turn it over to John Jarrell.
5 MEMBER SKILLMAN: Before you do that, 6
please, John, let me ask you a question. In the 7
spirit of shadow of the leader, what shadow do you 8
cast at your site regarding Appendix B to 10 CFR 50, 9
your QA program and programs?
10 MR. DINELLI: Mr. Skillman, the QA program 11 is a vital component to the safe operation of the 12 facility, so the way I cast my shadow for the 13 organization is to fully support the QA organization 14 and all of the functions that they serve.
15 I'll come through my experience that if 16 you have a healthy adherence to that program and all 17 aspects of that program, that it will ultimately drive 18 station performance.
19 So by showing my employees, my directors, 20 managers, and station employees that adherence to that 21 and following through with that program is important, 22 it makes it important to them, and overall makes us a 23 better operating facility.
24 MEMBER SKILLMAN: Thank you, sir. Thank 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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10 you.
1 MR. JARRELL: Okay, good morning. Again, 2
I want to thank the members of the ACRS for meeting 3
with us today. My name is John Jarrell. I'm the 4
Senior Manager of Operations at Waterford 3. I want 5
to give a little description of the site.
6 First of all, Waterford 3 is located about 7
25 miles upriver from New Orleans in St. Charles 8
Parish. We are a combustion engineering design and 9
EBASCO was our contractor and constructor. We do have 10 a dry containment.
11 I would like to apologize. We are having 12 some technical difficulties as you can see.
13 All right, our turbine generator is a 14 Westinghouse turbine generator. Our ultimate heat 15 sink is a combination of dry and wet cooling tower 16 fans which are independent from the Mississippi River.
17 It is a relatively unique design.
18 Our licensed thermal power limit is 3,716 19 megawatts thermal and the staff complement is 20 currently approximately 751 employees.
21 As of this morning, the plant was at 100 22 percent power. We are in our 18-month refueling 23 cycle. We are in the rack or oversight process action 24 matrix column one. Our last refueling outage was 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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11 spring of 2017 and we are preparing for an outage 1
refuel 22 which will occur early 2019.
2 MEMBER SKILLMAN: For the last several 3
fuel cycles, what has been your approximate capacity 4
factor?
5 MR. JARRELL: Our capacity factor has been 6
over 90 percent, so we've had a good operating history 7
and 90 percent was our capacity factor as of August of 8
this year.
9 MEMBER SKILLMAN: Thank you.
10 MR. JARRELL: Our licensing history is our 11 construction permit.
We were permitted for 12 construction in 1974. We received our operating 13 license on March 16 of 1985 and we went commercial in 14 September of 1985 as well.
15 We had an eight percent power upgrade in 16 April of 2005, and we submitted our license renewal 17 application on March 16 of 2016, and our current 18 license is set to expire December 18 of 2024.
19 So with that, I'd like to turn it over to 20 our Engineering Director, Brian Lanka. He'll go over 21 some major equipment upgrades at the site.
22 MR. LANKA: I'm Brian Lanka. I'm the site 23 Engineering Director. First, I want to start by 24 saying Entergy and Waterford are committed through our 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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12 nuclear strategy plan to make Waterford 3 reliable for 1
extended operation. To that means, we have a long 2
range plan focused on improving plant safety and 3
equipment performance.
4 The station has completed replacement of 5
our four active coolant pump motors. We have 6
proactively added design margin by increasing our 7
diesel generator fuel capacity. We've increased that 8
capacity by approximately 35 percent.
9 We have also addressed reliability by 10 replacing our safety-related static uninterruptible 11 power supplies, and in January, we'll complete a 12 modification that will put a swing system in to 13 further increase reliability.
14 In 2013, the station has replaced both the 15 reactor head and the steam generator. Both use more 16 resilient materials. The reactor head eliminated all 17 LI600 material on the head.
18 The station has also replaced the 19 traveling screen system to further reduce debris from 20 entering the condenser and protecting our new steam 21 generator.
22 This is a picture of our new traveling 23 screens. These are Geiger screens. They are zero 24 carryover screens. They actually rotate in a circular 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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13 motion versus carryover. These are pictures of our 1
new steam generators going in in 2013. We replaced 2
the LI600 tubes with LI690, and this is a picture of 3
the reactor heads going in. We replaced all of the 4
top, the coils, and everything on top of the head as 5
well.
6 Going forward, we had the following -
7 CHAIRMAN CORRADINI: Can I ask a quickie?
8 MR. LANKA: Sure, go ahead.
9 CHAIRMAN CORRADINI: On your, you had gone 10 through this list, and now I've lost it. You said you 11 added more capacity for your fuel storage tanks. What 12 does that change your capacity for running the diesel 13 generators from and to?
14 MR. LANKA: We added approximately 10,000 15 gallons, so we had an additional margin -- we're 16 required to have a seven-day supply because this is 17 additional margin so we can run more surveillance 18 without having to go back and fill it up.
19 CHAIRMAN CORRADINI: So seven becomes 14 20 or seven becomes 10?
21 MR. LANKA: We still use seven. We just 22 lowered the capacity, but if you look at it the way 23 you're explaining it, we probably gained a couple of 24 days.
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14 CHAIRMAN CORRADINI: Okay, thank you.
1 MR. LANKA: Okay, going forward, in 2
January, we will be retubing our condenser with SEA-3 CURE, which is a more resilient material. We'll also 4
be upgrading our cathodic protection system based on 5
the new SEA-CORE material.
6 CHAIRMAN CORRADINI: I wasn't at the 7
meeting, so I apologize if I'm stopping you and this 8
is old news. What is the material for the condenser?
9 MR. LANKA: SEA-CURE.
10 CHAIRMAN CORRADINI: What is that?
11 MR. LANKA: It's a high-end stainless 12 steel.
13 CHAIRMAN CORRADINI: High end.
14 MR. LANKA: It's very resilient.
15 CHAIRMAN CORRADINI: Okay, thank you. Is 16 there any more interesting technology? Is there any 17 surface treatment to the tubes or is this alloy steel 18 untreated on the surface?
19 MR. LANKA: It's untreated.
20 CHAIRMAN CORRADINI: Untreated, thank you.
21 MR. LANKA: We are also working to replace 22 our core protection calculators. This system is part 23 of our reactor coolant protection system which 24 actually monitors the core. We have plans to replace 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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15 our turbine control system and our safety-related 1
- chillers, and
- lastly, to improve safety and 2
reliability, we have several ongoing upgrades of our 3
motors, fans, and associated motor control centers for 4
our ultimate heat sink.
5 I'm going to turn it over now to Garry 6
Young who will go over the license.
7 MR. YOUNG: Okay, thank you. I'm Garry 8
Young, the Director of License Renewal for the Entergy 9
nuclear fleet, and I'd like to give you some 10 background on our license renewal process, including 11 the approach for the integrated plan assessment and 12 for preparing the license renewal application.
13 We have a dedicated corporate team working 14 on license renewal for all of the Entergy nuclear 15 plants. This team, with almost two decades of 16 experience with all aspects of aging management and 17 license renewal, has prepared more than a dozen 18 license renewal applications over the past several 19 years.
20 In addition to the corporate team, a plant 21 team of Waterford experts in
- design, systems 22 engineering, and plant programs was established for 23 this license renewal project. The plant team provided 24 the needed input, review, and oversight of all the 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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16 engineering and environmental reports that were 1
created.
2 Entergy used the NRC-approved guidance in 3
NEI 95.10 to prepare the project specific procedures 4
and guidelines. These procedures have been used on 5
our previous license renewal projects and are 6
routinely updated based on lessons learned, industry 7
operating experience, and changes to NRC guidance.
8 The site specific aging management review 9
results for Waterford were compared to the GALL 10 Report, which is NUREG-1801, Revision 2, as part of 11 the license renewal application development, and I'll 12 talk more about the comparison of the programs with 13 the GALL Report on a later slide. The LRA was 14 submitted to the NRC in March of 2016.
15 The NRC review process culminated in the 16 Waterford safety evaluation report which was issued in 17 August of 2018 with no open items and no confirmatory 18 items. We appreciate the extensive and thorough work 19 of the NRC staff in reaching this important milestone 20 in the license renewal application review process.
21 Next slide.
22 This slide summarizes the aging management 23 programs credited for license renewal. We have 41 24 aging management programs that include 12 new programs 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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17 and 29 existing programs, most of which are or will be 1
consistent with the GALL Report with a handful of 2
exceptions as shown on this slide.
3 Some examples of the 12 new programs are 4
the buried and underground piping and tanks inspection 5
program, the non-EQ cables and connections, aging 6
management programs, and one-time inspection programs.
7 Some aspects of these new programs have 8
been implemented, but they are considered new programs 9
because a significant number of changes must be made 10 or have only recently been made to make them 11 consistent with the program descriptions in the GALL 12 Report.
13 For example, the Waterford buried piping 14 program was initiated in response to the 2009 NEI 15 initiative, but significant changes are necessary to 16 incorporate the latest NRC guidance which includes the 17 interim staff guidance issued in 2015.
18 For clarity in describing the program, 19 Entergy classified it as a new program that would be 20 consistent with the program description in the most 21 recent NRC guidance.
22 In addition, most of these new programs 23 have already been implemented at other Entergy nuclear 24 units. This allows us to ensure that implementation 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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18 of the Waterford aging management programs reaps the 1
benefits of lessons learned, from the Entergy 2
operating experience review
- program, and the 3
corrective action program.
4 28 of the existing programs have been 5
compared to the GALL programs, and only a few 6
exceptions have been taken. These exceptions include 7
such things as revised inspection intervals based on 8
the Waterford refueling outage schedules and 9
referencing NRC regulatory guides and industry 10 standards that are later revisions than those 11 referenced in the GALL Report which was published in 12 2010.
13 And finally, we have one existing plant 14 specific program which is the period surveillance and 15 preventive maintenance program. This program includes 16 a variety of aging management activities that could 17 not readily fit within the scope of the GALL Report 18 programs. Next slide.
19 On the topic of commitment management and 20 controlling the commitments that we've made for 21 license renewal, Entergy has a fleet program that 22 covers management of commitments for all our nuclear 23 plants.
24 We have successfully used this commitment 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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19 management program for our previous license renewal 1
projects, including projects for plants that have 2
implemented license renewal commitments and are 3
successfully operating in the period of extended 4
operation.
5 For each Waterford license renewal 6
commitment, the commitment management program 7
identifies the actions needed to implement the 8
commitments and identifies the owner responsible for 9
implementation.
10 Assignments will include actions such as 11 creation of implementing procedures for new aging 12 management programs and incorporating enhancements to 13 existing aging management programs. So this completes 14 my portion of the presentation. Thank you.
15 MEMBER MARCH-LEUBA: Can I ask you a 16 question? You may not be the right person. Are you, 17 any of you familiar with the term alkali-silica 18 reaction, concrete aging mechanism? Does it affect 19 your plant?
20 MR. YOUNG: No, we did look into that 21 because that is an industry issue of importance, but 22 we found that there was no indication of ASR at 23 Waterford.
24 MEMBER MARCH-LEUBA: Thank you.
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20 MR. DINELLI: Thank you. So I just want 1
to thank the Committee once again and assure the 2
Committee that Entergy is committed to the long term 3
operation and continuous improvement of our facility.
4 We will manage the effects of our aging, 5
evaluate time limited aging analysis under the 6
evaluations governed by 10 CFR 54, and we meet the 7
provisions for issuance of a license renewal.
8 So once again, I want to thank you for 9
this opportunity on this important day, and I look 10 forward to any further discussions.
11 MEMBER SKILLMAN: John, thank you.
12 Colleagues, any questions for the Entergy Waterford 3 13 team? Okay, team change out? Joe, back to you.
14 MR. DONOGHUE: Thank you, Chairman 15 Corradini. In my opening remarks, I introduced 16 Phyllis Clark as the project manager, and Allen Hiser 17 is our senior technical advisor involved in license 18 renewal, and Lois James who is the project manager 19 assisting in this project. Go ahead.
20 MS. CLARK: Good morning, Chairman 21 Corradini and the members of the ACRS.
22 MEMBER SKILLMAN: You may have to get 23 closer to the mic.
24 MS. CLARK: Okay, thanks, okay. My name 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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21 is Phyllis Clark and I'm the project manager for the 1
license renewal safety review for the Waterford Steam 2
Electric Station Unit 3, or I'll refer to it as 3
Waterford.
4 We are here today to discuss the staff's 5
review of the Waterford license renewal application as 6
documented in the safety evaluation report, SER, which 7
was issued August 17, 2018.
8 Joining me here at the table is Allen 9
Hiser, Senior Technical Advisor for License Renewal, 10 aging management, and Ms. Lois James, Senior Safety 11 Project Manager from the Division of Material and 12 License Renewal, DMLR.
13 Seated in the audience and joining by 14 phone are members of the technical staff who 15 participated in the review of the license renewal 16 application and conducted onsite audits and 17 inspection. Next slide.
18 I will begin the presentation with a 19 general overview of the staff's review and then 20 present the staff's conclusions. Next slide.
21 On March 23, 2016, Entergy Operations, 22 Inc. submitted a license renewal application or LRA 23 for Waterford which has a combustion engineering 24 pressurized water reactor, PWR, nuclear steam electric 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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22 steam supply system with licensed thermal power of 1
3,716 megawatts thermal. The staff conducted two 2
onsite audits and one inspection at the site.
3 During the scoping and screening 4
methodology audit, the audit team reviewed the 5
applicant's scoping and screening methodology, 6
selected examples of component material and 7
environmental combinations, the corrective action 8
program, administrative and confirmatory action 9
process as described in the LRA, and the training of 10 personnel who participated in the development of the 11 LRA. The results of the audit are documented in the 12 report dated November 10, 2016.
13 During the aging management program 14 audits, the audit team examined the applicant's aging 15 management program of AMPs, related documentation, and 16 operating experience to verify the applicant's claim 17 of consistency with corresponding AMPs in the generic 18 aging lessons learned report or GALL Report. The 19 staff reviewed the initial 41 AMPs and documented the 20 results in the report dated May 9, 2017.
21 Region IV conducted a 71.02 inspection in 22 January and February of 2017 and documented the 23 results in a report dated March 31, 2017.
24 Based on the inspection results, the 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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23 Region IV team had reasonable assurance that Entergy's 1
program in place or planned as described in their 2
commitment table will manage the aging effects and 3
ensure the intended safety functions of safety, 4
structure, and components within the scope of the 5
rule. Next slide.
6 The Waterford final SER was issued on 7
August 17, 2018. During the staff's in-depth 8
technical review of the LRA, 119 RAIs were issued, 25 9
of which were follow-up RAIs. The final SER will be 10 published as a NUREG report following the issuance of 11 the renewed license.
12 The ACRS Subcommittee was held on 13 September 20, 2018 and there were no follow-up items 14 for the staff. Next slide.
15 MEMBER REMPE: I have a question. I did 16 not participate in the Subcommittee either, but I'm 17 just curious about the number of RAIs. Is this 18 typical? Is it going down as we go through more of 19 these plants and license renewal or how does this 20 compare to other -
21 MS. JAMES: Hello, my name is Lois James.
22 If I may, this is a low number. I worked on two other 23 plants that we had over 300, 360, 380, so the 119 is 24 relatively low for my recollection of history.
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24 MEMBER REMPE: In your opinion, is that 1
because this is a great licensee or is that because 2
everyone's understanding the process and the 3
expectations of the process?
4 MS. JAMES: I think at this point, it 5
would be understanding the process. We only have 6
about three or four left, I think, maybe five, and so 7
one of the things our management has been stressing is 8
that they need to look at old RAIs or previously 9
issued RAIs and make sure those get addressed, and I 10 think in general for license renewal, we're finding 11 that.
12 MEMBER REMPE: Great, thank you.
13 MR. OESTERLE: This is Eric Oesterle, 14 Chief of the License Renewal Projects Branch. So to 15 add to what Lois had mentioned, yes, the understanding 16 of the process is getting better, and one of the 17 things that the staff has been doing is communicating 18 expectations to applicants ahead of time that they 19 should be looking at RAIs that staff has issued on 20 previous applications.
21 And applicants have done that, and so 22 they've already answered questions then ahead of time 23 that we asked before, and so the number of questions 24 that we end up having to ask, you know, has 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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25 continuously trended downwards. And also as you'll 1
see in the next presentation on River Bend, we came in 2
around the same level of RAIs as on Waterford.
3 MEMBER SKILLMAN: I would like to make a 4
comment here. I've been looking at these for seven 5
years. I believe that the individuals who have been 6
preparing the license renewal applications have worked 7
hard to make sure that the initial submittal is 8
strong, accurate, and thorough.
9 And as Garry Young said when he introduced 10 himself, he's done about 12 of these, so I think 11 there's some credit to be given to Garry and the crew 12 that did this. They're getting better at this 13 process.
14 But it also may point to the degree to 15 which the plant owners have protected the material 16 condition of the plant, and from my experience, that's 17 critical. This plant is not falling down around 18 peoples' heads and shoulders.
19 This is a plant that's in good condition 20 because people have been taking care of it, but those 21 two need to go side by side in order to get to a very 22 low number of RAIs, and credit to the staff for having 23 a thick magnifying glass and being able to say, "This 24 is a low number." That's not by accident. It took an 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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26 awful lot of effort.
1 MR. OESTERLE: Yeah, we definitely agree 2
with your remarks, and we'll add that what we heard at 3
the Subcommittee meeting on September 20 was from the 4
regional inspector that the plant was in good material 5
condition.
6 MS. CLARK: In the next few slides, I'll 7
present the results of the staff's review as described 8
in the SER. SER Section 2 describes the scoping of 9
the system structures and components or SSCs and 10 screening of structures and components to identify 11 those subject to an aging management review of AMR.
12 The staff reviewed the applicant's scoping 13 and screening methodology, procedures, quality control 14 applicable to the LAR development, and training of its 15 personnel.
16 The staff also reviewed the various 17 summaries of the safety-related SSCs, non-safety SSCs 18 affecting safety functions, and the SSCs relied upon 19 to perform functions applicable to Waterford in 20 compliance with the Commission regulation for fire 21 protection, environmental qualifications, station 22 blackout, pressurized thermal shock, and anticipated 23 transience without a scram.
24 Based on the review of the results from 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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27 the scoping and screening audit and additional 1
information provided by the applicant, the staff 2
concludes that the applicant's scoping and screening 3
methodology and implementation were consistent with 4
the standard review plan and the requirements of 10 5
CFR Part 54.
6 SER Section 3 and its subsections cover 7
the staff's review of the applicant's programs 8
managing aging in accordance with 10 CFR 54.21A3.
9 Sections 3.1 through 3.6 include the AMR items in each 10 of the general system areas within the scope of 11 license renewal. For a given AMR item, the staff 12 reviewed the item to determine whether it is 13 consistent with the GALL Report.
14 For AMR items not consistent with the GALL 15 Report, the staff reviewed the applicant's evaluation 16 to determine whether the applicant has demonstrated 17 that there is reasonable assurance that the effects of 18 aging will be adequately managed so that the intended 19 functions will be maintained consistent with the 20 current licensing basis for the period of extended 21 operation. Next slide.
22 The LAR described a total of 41 AMPs, 12 23 new, 29 existing, and one plant specific. This slide 24 identifies the applicant's disposition of these AMPs 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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28 in the left column and the staff's disposition in the 1
right column. The AMPs were evaluated by the staff's 2
consistency with the GALL Report.
3 During the staff's review, the applicant 4
changed the disposition of three AMPs based on NRC 5
requests for additional information. These AMPs are 6
in-service inspection changed from consistent in the 7
original LRA to consistent with enhancements.
8 Reactor vessel surveillance changed from 9
consistent in the original LRA to consistent with 10 enhancements and exceptions.
Steam generator 11 integrity changed from consistent in the original LRA 12 to consistent with enhancements.
13 SER Section 4 identifies time limiting 14 aging analysis to TLAAs. Section 4.1 documents the 15 staff's evaluation of the applicant's identification 16 of applicable TLAAs.
17 The staff evaluated the applicant's basis 18 for identifying those plant specific or generic 19 analyses that need to be identified as TLAAs and 20 determined that the applicant has provided an adequate 21 list of TLAAs as required by 10 CFR 54.21C1.
22 Sections 4.2 through 4.7 document the 23 staff's review of the applicable Waterford TLAAs for 24 the areas shown on this slide. Based on its review 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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29 and the information provided by the applicant, the 1
staff concludes that either one, the analysis is valid 2
for the period of extended operation, two, the 3
analysis has been projected to the end of the period 4
of extended operation, or three, the effects of aging 5
on the intended functions will be adequately managed 6
for the period of extended operation as required by 10 7
CFR 21.C1 Subparagraphs I, ii, and iii respectively.
8 The staff finds that the requirements of 9
10 CFR 54.29A have been met for the license renewal of 10 Waterford. This concludes the staff's presentation.
11 We're available for any further questions from the 12 full Committee.
13 MEMBER SKILLMAN: Phyllis, thank you.
14 MS. CLARK: Thanks.
15 MEMBER SKILLMAN:
Colleagues, any 16 questions for the staff in the matter of Waterford 3, 17 please?
18 MEMBER BALLINGER: Well, I have a 19 question, but it's for Entergy. We had an 20 unanticipated transient over here and the question is 21 does Entergy have other experience with SEA-CURE 22 tubing for condensers? Yeah, what experience does 23 Entergy have with SEA-CURE for tubing material for 24 condensers?
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30 MR. LANKA: This is Brian Lanka. Entergy, 1
to my knowledge, has not installed SEA-CURE yet. We 2
have installed titanium Fitzpatrick when we did own 3
them, but we have reached out to the industry, and 4
other utilities are using SEA-CURE.
5 MEMBER BALLINGER: Thank you.
6 MEMBER SKILLMAN: Colleagues, any other 7
question or questions for the staff in the matter of 8
Waterford 3?
9 MEMBER MARCH-LEUBA: Well, since nobody is 10 asking the question, do you evaluate ASR for Waterford 11 or ask any questions about it?
12 DR. HISER: I would expect that we looked 13 through the operating experience at Waterford, and we 14 did walk downs during the AMPs audit, and obviously 15 there were no indications of ASR identified.
16 MEMBER MARCH-LEUBA: Thank you.
17 MEMBER SKILLMAN: So with that, Allen, and 18 Phyllis, and Lois, thank you very much. And Mr.
19 Chairman, we're back to you.
20 CHAIRMAN CORRADINI: Okay, so here's what 21 we're going to do. We have the challenges of the 22 room, so we have to stick with the published schedule, 23 which means we cannot take up River Bend until 10:30 24 when it is scheduled. We're going to essentially go 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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31 off the record and we're going to look at the draft 1
letter report for Waterford now.
2 (Whereupon, the above-entitled matter went 3
off the record at 9:03 a.m. and resumed at 10:44 a.m.)
4 CHAIRMAN CORRADINI: Okay, why don't we 5
come back into session? We're going to now take on 6
our second subject which is the River Bend Station 7
license renewal, so I'll turn it back over to Member 8
Skillman. Dick, do you want to take it over?
9 MEMBER SKILLMAN:
- Yes, ladies and 10 gentlemen, thank you. We are picking up the second 11 license renewal application discussion. In this 12 discussion, we will hear from leaders from the River 13 Bend Station owned and operated by Entergy South. And 14 without further ado, I'm going to turn the microphone 15 over to Joe Donoghue from the NRC staff for the 16 remainder of this session, Joe?
17 MR. DONOGHUE: Thank you, Member Skillman, 18 and thank you, Chairman Corradini, and members of the 19 ACRS full Committee.
20 I'm Joe Donoghue. I'm the Deputy Director 21 of the Division of Materials and License Renewal in 22 the Office of Nuclear Reaction Regulations. We 23 sincerely appreciate the opportunity to brief the ACRS 24 full Committee on the River Bend license renewal 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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32 review that we've done.
1 As you know, the staff presented the 2
results of their review on the River Bend application 3
to the ACRS License Renewal Subcommittee on September 4
20 of this year. There were two follow-up items from 5
that meeting and the staff is prepared to discuss them 6
today.
7 The license renewal presentation today 8
from the staff will be led by Emmanuel Sayoc, and we 9
have other staff who will be participating in that 10 participation, Dr. Allen Hiser, our Senior Technical 11 Advisor for License Renewal.
12 Also here is Eric Oesterle, Chief of the 13 Project Branch in our Division, and in the audience 14 and on the phone, we have other technical staff and 15 management to support the presentation.
16 We look forward to a productive discussion 17 today with the full Committee, and as always, we'll 18 address any questions on our review that you may have, 19 and we look forward to receiving your recommendation 20 letter to support issuing the renewed license.
21 I'd like to turn the presentation over to 22 the Entergy team and their Site Vice President, Bill 23 Maguire, to introduce his team and commence their 24 presentation.
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33 MR. MAGUIRE: Thank you, Mr. Donoghue.
1 Good morning, Mr. Chairman and members of the ACRS.
2 My name is Bill Maguire. I'm the Site Vice President 3
at River Bend Station. We very much appreciate the 4
opportunity to present -
5 PARTICIPANT: I just think you got to get 6
close to it.
7 MR. MAGUIRE: Okay, I'll move the 8
microphone up. Is this better? Great, thank you.
9 Good morning. My name is Bill Maguire. I am the Site 10 Vice President at River Bend Station. We very much 11 appreciate the opportunity to review our license 12 renewal application with the Committee.
13 We have dedicated significant resources at 14 Entergy in the application presentation and 15 preparation, and we believe it got a very thorough 16 review by the staff, a very rigorous and detailed 17 review.
18 For this morning's discussion, we have 19 with us Mr. James Henderson. He's our Engineering 20 Director. He'll be talking about some of the plant 21 upgrades that we've done to ensure long-term reliable 22 operation of the station, Mr. Tim Schenk, our 23 Regulatory Assurance Manager, he'll go over the 24 background of the station, and Mr. Garry Young, our 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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34 Fleet Director for License Renewal.
1 Again, we thank you for this opportunity 2
today, and we welcome your questions and look forward 3
to discussion, and I'll turn over the presentation to 4
Mr. Tim Schenk.
5 MEMBER SKILLMAN: Before you do, Bill, 6
thank you for being here. Please speak to us on the 7
same topic that I asked the VP from Waterford 3, and 8
that is you are the exec at this site. You do cast a 9
shadow as the leader, and what is your vision of the 10 shadow that you cast relative to Appendix B to 10 CFR 11 10, your QA program?
12 MR. MAGUIRE: Well, thank you, Mr.
13 Skillman. I have a strong passion for our nuclear 14 independent oversight organization. That's how we 15 meet the Appendix B regulation, as well as our 16 commitment to a robust corrective action program.
17 Our nuclear oversight manager is a strong 18 leader with multi-site, multi-discipline experience.
19 He has reporting to him a robust organization that 20 represents all of the disciplines at the station, 21 engineering, operations, maintenance, technical team.
22 I have a responsibility to provide to him 23 a few members of the teams that are rotate 24 assignments, so we pick high quality personnel. For 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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35 example, we currently have a current senior reactor 1
operator license holder to rotate to the team to 2
ensure we get a good technical, rigorous review of our 3
control room operations, our field operations.
4 We also have a robust corrective action 5
program as I mentioned. As of this morning, we've 6
generated over 5,830 condition reports here to date, 7
so we have a very low threshold for problem 8
identification.
9 We also have in our Entergy management 10 model an articulated value for safety, and the tool 11 that we use to implement safety is what we call the 12 PDC model or prevention, detection, correction model, 13 and certainly we correct a number of issues at the 14 station through the corrective action program, but the 15 model is biased toward prevention and detection 16 activity.
17 So our operators are performing rounds, 18 our engineers are doing system health reports, all 19 intended to be out in the detection and prevention 20 mode so that our plant runs safely and reliably.
21 MEMBER SKILLMAN: Thank you, please 22 proceed.
23 MR. SCHENK: Thank you, Bill. This is Tim 24 Schenk. I'm the Regulatory Assurance Manager at River 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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36 Bend Station. River Bend is located in Louisiana, 1
West Feliciana Parish, approximately 24 miles north, 2
northwest of Baton Rouge.
3 It's a General Electric and Triple S 4
design. Stone and Webster was the constructor. We're 5
boiling water reactors six type. We have a General 6
Electric mark three containment and a GE turbine 7
generator.
8 Our ultimate heat sink is an independent 9
wet cooling tower. We have a closed circulating water 10 system with mechanical draft cooling towers, and we're 11 licensed to 3,091 megawatts thermal and our 12 approximate staff is 820 at this time.
13 Currently, our plant status is actually 75 14 percent power as of 0600 this morning. We had a 15 planned control rod pattern adjustment overnight and 16 we'll be ascending in power throughout the day today.
17 We're on a 24-month operating cycle in our 18 reactor oversight process. We're a column one plant.
19 Our last refueling outage was in the spring of 2017.
20 That was refueling outage number 19. Our next 21 refueling outage is scheduled for the spring of 2019 22 and that will be refueling outage number 20.
23 MEMBER SKILLMAN: Tim, what is your 24 capacity factor, please?
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37 MR. SCHENK: Our capacity factor for this 1
cycle is 84.5 percent.
2 MEMBER SKILLMAN: Are you experiencing 3
some equipment problems that are pushing you back from 4
90, 92, 94 percent?
5 MR. SCHENK: The biggest impact in our 6
capacity factor this cycle was a planned outage that 7
we took in January of 2018 to address fuel leaks.
8 MEMBER SKILLMAN: Yes, sir, thank you.
9 MEMBER MARCH-LEUBA: I was going to ask 10 about that. What fuel do you use? Who is your fuel 11 vendor, GE?
13 MEMBER MARCH-LEUBA: GNF, you use GNF too?
14 MR. SCHENK: Yes.
15 MEMBER MARCH-LEUBA: And you were having 16 leakage problems?
17 MR. SCHENK: Yes, sir, we have experienced 18 fuel leaks through this cycle.
19 MEMBER MARCH-LEUBA: Okay, thank you.
20 MEMBER SKILLMAN: Thank you. Please 21 continue.
22 MR. SCHENK: Some of the River Bend 23 licensing history, we received our construction permit 24 in 1977 and our operating license was in 1985, and we 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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38 commenced commercial operation in 1986. We were 1
operating initially at 2,894 megawatts thermal.
2 We received our first power up rate in the 3
year 2000 and went to 3,039 megawatts thermal, and 4
then we did another power up rate in 2003 for thermal 5
power optimization and that's where we're currently 6
at, 3,091 megawatts thermal.
7 Our license renewal application was 8
submitted in May of 2017 and our current operating 9
license will expire in August of 2025.
10 MEMBER REMPE: Do you have any plans for 11 other upgrades or MELLA+ separation or anything like 12 that?
13 MR. SCHENK: No, ma'am.
14 MEMBER REMPE: Why not?
15 MR. MAGUIRE: I can answer that. So while 16 the plant has the reactor capacity to add additional 17 megawatts from the plant, we would have to provide 18 additional balance of plant support to give that 19 margin, and right now, the economics would support us 20 using other forms of generation rather than adding 21 capacity to our existing plant.
22 MEMBER REMPE: Thank you.
23 MR. SCHENK: All right, with that, I'd 24 like to turn it over to our Engineering Director, 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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39 James Henderson.
1 MR. HENDERSON: Good morning. My name is 2
James Henderson. I am the Engineering Director at 3
River Bend Station. I want to go over a couple of 4
items. The first will be our major equipment upgrades 5
for the facility, and then we'll go over our planned 6
upgrades going forward.
7 The first thing that Entergy has done is 8
done a very good job of making sure we have major 9
investments looking at the long-term health and 10 reliability of the station, not just from an equipment 11 liability perspective, but also a safe and reliable 12 operation of the facility.
13 The first item is an upgrade to our 14 digital electro hydraulic control system. We'll have 15 a picture further on in the slide presentation and 16 we'll discuss further that upgrade that was performed.
17 We also have an upgrade for our control building 18 chilled water controls.
19 Those digital controls help with our 20 operators interface as well as diagnostics for 21 understanding and ability to troubleshoot and really 22 get in front of one of our safety-related chilled 23 water systems.
24 We've also done recoat for underground 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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40 circulating water piping. That coupled with quality 1
soil as well as our cathodic protection system really 2
helped improve the overall health for our circ water 3
system, and also the further bullets look at our 4
modernization of the plant, so -
5 MEMBER SKILLMAN: Excuse me, sir. Let me 6
ask this question and I'm curious from a personal 7
perspective. Is the mud or the dirt in which that 8
circ water piping prehistoric Mississippi mud that 9
attacks the piping?
10 And I ask that because I spent many years 11 in the Susquehanna River basin fighting this very 12 issue, so I'm wondering if it's the nature of the 13 water, or the nature of the dirt, or the combination.
14 Could you speak a little bit to it, please?
15 MR. HENDERSON: Yes, I could. Actually 16 it's the quality of the soil itself that's actually 17 helpful for our protection of that underground piping.
18 Unlike the Susquehanna plant that you mentioned, the 19 soil is actually one of our key barriers to maintain 20 the quality and structural integrity of the 21 underground piping.
22 So we've seen from that soil, in not only 23 the coating that we've done, vast improvements as far 24 as our corrosion programs.
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41 MEMBER SKILLMAN: Did you add different 1
soil to protect the pipe?
2 MR. HENDERSON: No, we did not. It's the 3
same soil.
4 MEMBER SKILLMAN: Okay, thank you.
5 MEMBER RICCARDELLA: Have you had leakage 6
issues?
7 MR. HENDERSON: We have not, and we do 8
underground inspections whenever we have any 9
opportunity to go in, not only just with our normal 10 requirements as a part of our program, and all of 11 those inspections have been satisfactory.
12 MEMBER SKILLMAN: Please proceed. Thank 13 you.
14 MR. HENDERSON: The next slide in our 15 presentation shows a representation of our digital 16 electro hydraulic control system. Those upgrades 17 eliminated on the order of 90 single point 18 vulnerabilities from the facility.
19 It also gave the interface for the 20 operations team to be able to not only perform 21 testing, but better diagnostic for the generation of 22 the plant and ensure that we don't have challenges 23 there.
24 The next slide shows our four e-volt load 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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42 center breakers. This is just another example of 1
modernization to the plant. This dealt with a lot of 2
obsolescence that we had with some of our breakers in 3
the facility. Those have been changed and this has 4
improved overall reliability as well as our safety-5 related power performance.
6 The next slide is carbon steel piping 7
replacement. The system that's depicted here is our 8
reactor water cleanup system. We've gone in and 9
replaced carbon piping with new carbon piping as well 10 as chromoly.
11 That's helped improve the overall 12 reliability of our reactor water cleanup system as 13 well as a fact perspective, really helping the 14 reliability of the system.
15 The next slide goes through our major 16 equipment upgrades that are planned, the first being 17 our turbine building chiller replacements. Those will 18 complete in 2019. This is really to help with 19 generation as well as reliability for the station.
20 Our turbine chillers not only supply our turbine 21 building, but they also supply our main steam tunnel 22 associated with our reactor vessel.
23 MEMBER SKILLMAN: Jim, would you go back 24 a slide, please? For the reactor water cleanup piping 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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43 that was replaced, was this piping degradation 1
identified in your flow accelerated corrosion program?
2 MR. HENDERSON: Yes, it was.
3 MEMBER SKILLMAN: Oh, it was?
4 MR. HENDERSON: Yes, it was.
5 MEMBER SKILLMAN: And is this a 40-year 6
replacement that you are providing?
7 MR. HENDERSON: The replacement time 8
frame, I do not have that.
9 MEMBER SKILLMAN: No, no, how long is this 10 new piping going to be good for?
11 MR. HENDERSON: It will last for the 40 12 years.
13 MEMBER SKILLMAN: And does this pipe and 14 its attachments remain in your FAC program?
15 MR. HENDERSON: Yes, they do.
16 MEMBER SKILLMAN: Okay, thank you.
17 MEMBER BROWN: Could you go back another 18 slide? Right there, are those -- excuse me, I've got 19 to learn to do this too. Are those breakers digital 20 controls?
21 MR. HENDERSON: They are not. They have 22 indications as far as diagnostics for breaker amperage 23 and those things, but they are specifically at the 24 bucket of the breaker. They do not communicate with 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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44 the main control room or any other areas.
1 MEMBER BROWN:
- Okay, no internet 2
connections or anything like that?
3 MR. HENDERSON: That's correct.
4 MEMBER BROWN: Okay, that's fine. I might 5
have asked that earlier, but I forgot.
6 MR. HENDERSON: No worries.
7 MEMBER BROWN: Thank you.
8 MR. HENDERSON: The next item we'll talk 9
about is the spent fuel pool neutron absorber upgrade.
10 There's a slide going forward for a picture of that.
11 We also have condenser upgrades that will be taking 12 place in 2021. Similar to Waterford 3, we'll be going 13 with the secure piping for our retube.
14 We also have service water cooling heat 15 exchanger
- refurbs, our Fancy Point switchgear 16 upgrades. That's our offsite power source that comes 17 to the facility really making sure we have the 18 reliability and redundancy of offsite power coming to 19 the facility. That's an upgrade scheduled.
20 We also will be discussing the feedwater 21 strainer. I have a picture in the slide show for it 22 and that's related to the fuel failures that we've 23 seen that have been predominantly caused by foreign 24 material, and also our feedwater level control system 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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45 upgrades to a digital system which will eliminate 1
several of the single point vulnerabilities and 2
obsolescence concerns with our feedwater level control 3
system.
4 The next slide depicts our neutron 5
absorber prototype inserts. Currently we have 60 of 6
these inserts installed. They will help improve 7
neutron absorption in our spent fuel pool.
8 We've done the analysis for both seismic 9
as well as thermal impacts of having those inserts 10 into the core. Our plan is to in 2020, have an 11 engineering change that allows to take credit for 12 those as a part of our licensing basis.
13 MEMBER SKILLMAN: Jim, you said into the 14 core. I think what you meant is in the spent fuel 15 pool.
16 MR. HENDERSON: Spent fuel pool, that's 17 correct.
18 MEMBER SKILLMAN: Okay, thank you.
19 MEMBER REMPE: What material is that?
20 MR. HENDERSON: It's boron aluminum.
21 MEMBER RICCARDELLA: And is that going to 22 allow you to load more fuel in the condenser packing?
23 MR. HENDERSON: It will, and the intent 24 will be with the installation that we begin now, when 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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46 we get to 2020 with all of the analysis, we'll be able 1
to see what kind of additional capacity we'll have 2
based upon the inserts that we have in the spent fuel 3
pool.
4 MEMBER BALLINGER: You had boraflex before 5
that?
6 MR. HENDERSON: Yes, we did. We have the 7
boraflex inserts.
8 All
- right, our next slide depicts 9
strainers that will be installed in our feedwater 10 system. This is one of two strainers that will go in 11 the last point in our feedwater injection into the 12 vessel. We've had foreign material intrusion impacts 13 to our fuel. We have addressed the sources of those 14 foreign material.
15 This will be a preventive measure to allow 16 another means of collecting foreign material prior to 17 it getting into the vessel so that we don't have, 18 going forward, fuel failures at our facility. This 19 depiction is actually not the one that we're 20 installing, but this is just a representation of what 21 we'll have.
22 MEMBER MARCH-LEUBA: And you're planning 23 to install this during the next outage?
24 MR. HENDERSON: Yes.
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47 MEMBER MARCH-LEUBA: This was not part of 1
these reviews operating, I mean, on the scheduled 2
outages you had last cycle, right?
3 MR. HENDERSON: That's correct. This will 4
be in our next refueling outage in the spring of 2019.
5 And the final upgrade that I will discuss 6
is our feedwater level control. This will be a 7
digital upgrade. We have taken actions to bridge and 8
alleviate some of the concerns with our analog system 9
that we've had for feedwater level control. This will 10 improve with the SPV elimination as well as operator 11 interface, the ability to control reactor water level.
12 Some of the things that we're doing at the 13 station one is looking at OE from the industry as far 14 as impacts not only from a cyber security perspective 15 for installation of the system, but also the 16 effectiveness of the level control going forward, so 17 this is an item that we have on target for the station 18 as well.
19 With that, I'll turn over the presentation 20 to Garry Young.
21 MR. YOUNG: Okay, thank you. I'm Garry 22 Young, Director of License Renewal for the Entergy 23 nuclear fleet and I'd like to give you some background 24 on our license renewal process, including the approach 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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48 for the integrated plan assessment and for preparing 1
the license renewal application.
2 We have a dedicated corporate team working 3
on license renewal for all of the Entergy nuclear 4
plants, and this team with almost two decades of 5
experience with all aspects of aging management and 6
license renewal has prepared more than a dozen license 7
renewal applications over the past several years.
8 In addition to the corporate team, a plant 9
team of River Bend experts in design, systems 10 engineering, and plant programs was established for 11 this license renewal project. The plant team provided 12 needed input, review, and oversight of all the 13 engineering and environmental reports that were 14 created.
15 Entergy used the NRC-approved guidance in 16 NEI 95.10 to prepare the project specific procedures 17 and guidelines. These procedures have been used on 18 our previous license renewal projects and are 19 routinely updated based on lessons learned, industry 20 operating experience, and changes to NRC guidance.
21 The site specific aging management review 22 results for River Bend were compared to the GALL 23 Report, NUREG-1801, Revision 2, as part of the 24 application development, and I'll talk more about the 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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49 comparison of aging management programs with the GALL 1
Report on a later slide.
2 The license renewal application was 3
submitted to the NRC in May of 2017 and the NRC used 4
a new review process for the River Bend application 5
that included some efficiency improvements based on 6
lessons learned from previous NRC reviews.
7 This has proven to be a successful effort 8
by the NRC staff and has resulted in a planned 18-9 month review schedule rather than the typical 22-month 10 review schedule. Okay, next slide.
11 The NRC review process culminated in the 12 River Bend safety evaluation report which was issued 13 in August of 2018 with no open items and no 14 confirmatory items. We appreciate the extensive and 15 thorough work of the NRC staff in reaching this 16 important milestone in the license renewal application 17 review process. Okay, next slide.
18 This slide summarizes the aging management 19 programs credited for license renewal. We have 43 20 aging management programs that include 12 new programs 21 and 30 existing programs that are or will be 22 consistent with the GALL Report programs with a 23 handful of exceptions that are shown on this slide.
24 Some examples of the 12 new programs are 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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50 the buried and underground piping and tanks inspection 1
program, the non-EQ cables and connections aging 2
management programs, and one-time inspection programs.
3 Some aspects of these new programs have 4
been implemented, but they are considered new programs 5
because a significant number of changes must be made 6
or have only recently been made to make them 7
consistent with the program descriptions in the GALL 8
Report.
9 For example, the River Bend buried piping 10 program was initiated in response to a 2009 NEI 11 initiative, but significant changes are necessary to 12 incorporate the latest NRC guidance which includes 13 interim staff guidance issued in 2015.
14 For clarity in describing the program, 15 Entergy classified it as a new program that would be 16 consistent with the program description in the most 17 recent NRC guidance.
18 MEMBER MARCH-LEUBA: What is the plant 19 specific program, the last bullet?
20 MR. YOUNG: That's the period surveillance 21 and preventive maintenance program.
22 MEMBER MARCH-LEUBA: That's not in other 23 plants?
24 MR. YOUNG: Entergy has that in all of our 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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51 plants. It's an existing program and we use it when 1
we have some, for example, some preventive maintenance 2
activities that we can credit for aging management 3
such as inspections during some period frequency for 4
maintenance.
5 MEMBER MARCH-LEUBA: Yeah, but there's 6
nothing special about River Bend. All Entergy plants 7
have that?
8 MR. YOUNG: All of the Entergy plants have 9
it, yes.
10 MEMBER MARCH-LEUBA: Okay, I just was 11 reading something wrong in that bullet.
12 MR. YOUNG: Okay, the 30 existing programs 13 have been compared to the GALL programs, and only a 14 few exceptions have been taken. These exceptions 15 include such things as revised inspection intervals 16 based on the River Bend refueling outage schedules and 17 referencing NRC regulatory guides and industry 18 standards that are later revisions than those 19 referenced in the GALL Report which was published in 20 2010.
21 And then the last one is the plant 22 specific program which is the period surveillance and 23 preventive maintenance program. Okay, next slide.
24 On the topic of commitment management and 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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52 controlling the commitments that we've made for 1
license renewal, Entergy has a fleet program that 2
covers management of commitments for all our nuclear 3
plants.
4 We have successfully used this commitment 5
management program for our previous license renewal 6
projects, including projects for plants that have 7
implemented license renewal commitments and are 8
successfully operating in the period of extended 9
operation.
10 For each River Bend license renewal 11 commitment, the commitment management program 12 identifies the actions needed to implement the 13 commitments and identifies the owner responsible for 14 implementation.
15 Assignments will include actions such as 16 creation of implementing procedures for new aging 17 management programs and incorporating enhancements to 18 existing aging management programs, and this completes 19 my portion of the presentation and I'll turn it back 20 over to Bill.
21 MR. MAGUIRE: Thank you, Garry. In 22 summary, Entergy is committed to the long-term safe 23 and reliable operation of the River Bend facility.
24 Entergy will manage the effects of aging in accordance 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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53 with 10 CFR 54. Entergy has evaluated time limited 1
aging analysis that require evaluation under 10 CFR 54 2
and we have met the provisions of 10 CFR 54 for 3
issuance of a renewed license. That concludes our 4
remarks pending your questions.
5 MEMBER SKILLMAN: Bill, thank you.
6 Colleagues, any questions, please, for the River Bend 7
management team?
8 MEMBER KIRCHNER: Could you go back to, 9
you mentioned issues with fuel leakage and then you 10 showed us a picture of a strainer, feedwater strainer.
11 What was the program or analysis that you did? Did 12 you see debris or crud on the fuel that was the cause 13 of the leakage and that led you to this planned step 14 to install a feedwater strainer or can you give us 15 some more detail on that issue, please?
16 MR. HENDERSON: Yes, so we've done 17 analysis for the fuel that has been removed from the 18 core with indications of fuel failure, and all of the 19 indications show or are indicative of foreign material 20 and debris.
21 The actions that I discussed earlier about 22 pinpointing the specific causes of those were very 23 foreign material potential systems that got into the 24 vessel, including our feedwater system and our 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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54 feedwater sparger probe, so those all have direct feed 1
into the vessel to cause a foreign material concern, 2
so that's where we narrowed down and pinpoints to go 3
address and correct.
4 The whole purpose of the strainer itself 5
was more of a prevention perspective to give us an 6
additional robust barrier between getting items 7
through our feedwater system into the vessel and cause 8
a potential fuel failure.
9 MEMBER BALLINGER: Was this foreign 10 material from the system or from maintenance which 11 introduced the foreign material into the system?
12 MR. HENDERSON: It was -- the first of it 13 was due to a failure of one of our feedwater 14 regulating valves.
15 MEMBER BALLINGER: Okay.
16 MR. HENDERSON: There was a Variseal 17 within that that failed and went in. The other item 18 was because of a conductivity probe that had broken 19 off and their operating experience about conductivity 20 probes breaking. That conductivity probe made its way 21 into our feedwater sparger and made a hole into the 22 sparger.
23 MEMBER BALLINGER: So these are from 24 systems? They're not from like a wire brush or 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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55 something?
1 MR. HENDERSON: No, that's correct. It is 2
not from maintenance practices.
3 MR. MAGUIRE: And this measure would not 4
have prevented the feed reg valve from failing or the 5
probe from failing, but it would have prevented those 6
components from getting into the reactor vessel and 7
causing fuel defects.
8 MEMBER KIRCHNER: So if I could follow up, 9
so the fuel failure was induced by this debris getting 10 caught in the fuel at a grid spacer or some place?
11 MR. MAGUIRE: Yes, sir.
12 MEMBER KIRCHNER: Or was it blocking the 13 channel, the flow into the bundle?
14 MR. MAGUIRE: It's at the grid spacer.
15 It's debris induced threading of the cladding of the 16 fuel that's causing the defects.
17 MEMBER KIRCHNER: So it wasn't a dry out 18 problem per se. It was more of an inter-middle 19 interaction kind of problem?
20 MR. MAGUIRE: You are correct.
21 MEMBER KIRCHNER: Did the first grid 22 spacer pick up the debris?
23 MR. MAGUIRE: We have -
24 MEMBER KIRCHNER: Was it in the bottom of 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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56 the cooler?
1 MR. MAGUIRE: The GNF comes with a fuel 2
defender, and the fuel defender provides a tortuous 3
path at the bottom of the fuel bundle so that if you 4
did have some debris entering the reactor core, the 5
probability of it getting inside the channel is low.
6 If it were to get past the defender, it 7
could get stuck at any number of the spacers along the 8
longitudinal length of the fuel bundle, and we have 9
seen defects at different heights in the fuel bundle, 10 typically at a spacer grid.
11 MEMBER KIRCHNER: Thank you.
12 MEMBER RICCARDELLA:
You mentioned 13 feedwater sparger damage.
Did this require 14 replacement of the sparger or just repair?
15 MR. HENDERSON: During our next refueling 16 outage, we have a clam shell, for lack of better 17 terms, that we're going to put over the sparger itself 18 which will repair the sparger and the hole that we 19 have indications of an issue with.
20 MEMBER MARCH-LEUBA: Just curious because 21 we have time, how do you know it was broken? I mean, 22 you saw it on the last refueling outage?
23 MR. HENDERSON: We actually were doing in 24 core inspections and had a camera that was panning 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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57 over the area, and we identified the -
1 MEMBER MARCH-LEUBA: During refueling, it 2
was visual?
3 MR. HENDERSON: That's correct.
4 MEMBER RICCARDELLA: Was it the little 5
sparger nozzle, the little elbows, one of those or the 6
main pipe, sparger piping?
7 MR. HENDERSON: Yeah, if you can imagine 8
the actual sparger elbow, right on the side of the 9
elbow was where the hole had -
10 MEMBER REMPE: Okay, thank you.
11 MEMBER SKILLMAN: Colleagues, any further 12 questions for the River Bend executive team? Hearing 13 none, Joe, change out time. Entergy team, thank you.
14 MR. DONOGHUE: Chairman Corradini and 15 Committee, we're just about ready with our staff 16 presentation. As I said before, Emmanuel Sayoc, the 17 project manager who led this, will lead the 18 presentation. Allen Hiser, who you saw earlier today, 19 he's our senior technical advisor for license renewal, 20 and Angela Wu is a project manager that helped with 21 this review. Take it away.
22 MEMBER SKILLMAN: So, Angela, Emmanuel, 23 Allen, let's go. Thank you very much for being here 24 and let's go.
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58 MR. SAYOC: Good morning, Chairman 1
Corradini and members of the ACRS. My name is 2
Emmanuel Sayoc and I am the license renewal project 3
manager for the River Bend Station Unit 1 safety 4
review.
5 We are here today to discuss the staff's 6
review of the River Bend license renewal application 7
or LRA as discussed in the safety evaluation report 8
issued on August 16, 2018. Joining me here at the 9
table are Dr. Allen Hiser, senior technical advisor, 10 and Ms. Angela Wu, project manager from the Division 11 of Materials and License Renewal.
12 Seated in the audience are members of the 13 technical staff who participated in the review of the 14 license renewal application and conducted the onsite 15 audits and inspections. Next slide.
16 I will begin the presentation with a 17 general overview of the staff's review. Next, I will 18 touch upon follow-up items from the ACRS Subcommittee 19 meeting of September 20, 2018. As there were no open 20 items or confirmatory items in the SER, I will proceed 21 to the staff's
- review, follow-up
- items, and 22 conclusions. Next slide.
23 On May 25, 2017, Entergy Louisiana, LLC 24 and Entergy Operations, Inc., collectively referred to 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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59 as Entergy or the applicant, submitted an application 1
for renewal of River Bend operating license for an 2
additional 20 years.
3 Consistent with prior license renewal 4
reviews, the staff conducted the three standard audits 5
as shown in the slide, the operating experience audit, 6
the scoping and screening methodology audit, and the 7
aging management audit.
8 These audits were performed from NRC 9
headquarters, and the regional 71.02 inspection as 10 well as portions of the AMP audit were performed 11 onsite at River Bend.
12 During the operating experience audit, the 13 team conducted an independent search of plant 14 operating experience information to determine whether 15 the applicant's LRA aging management program can 16 adequately manage the associated aging effects. The 17 operating experience audits were documented in a 18 report dated January 18, 2018.
19 During the scoping and screening 20 methodology audit, the team reviewed the applicant's 21 administrative controls governing the scoping and 22 screening methodology and the technical basis for 23 selecting scoping and screening results. The scoping 24 and screening methodology audits were documented in a 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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60 report dated January 8, 2018.
1 During the AMP audits, the team examined 2
applicant's aging management programs and related 3
documentation to verify that the applicant's programs 4
are consistent with those described in the GALL Report 5
and with plant conditions and operating experience.
6 The staff documented the results in a report dated 7
January 29, 2018.
8 Region IV conducted a 71.02 inspection in 9
February and March 2018 and documented their results 10 in a report dated May 7, 2018.
11 Based on the inspection results, the 12 Region IV team had reasonable assurance that the 13 Entergy programs in place or planned as described in 14 their commitment table will manage the aging effects 15 and ensure the intended safety function of systems, 16 structures, and components within the scope of the 17 rule. Next slide, please.
18 The River Bend final SER was issued on 19 August 16, 2018. With the staff's in-depth technical 20 review of the LRA, a total of 119 RAIs were issued, 15 21 of which were follow-up RAIs. The final SER will be 22 issued with the renewed license and published as a 23 NUREG report.
24 The ACRS License Renewal Subcommittee 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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61 meeting was held on September 20, 2018. There were 1
two follow-up items from that meeting which I will 2
discuss later in the presentation. Next slide, 3
please.
4 In the next few slides, I will present the 5
results of the staff's review of the LAR as described 6
in the SER. SER Section 2 described the scoping of 7
SSCs and the screening of structures and components to 8
identify those subject to AMR.
9 The staff reviewed the applicant's scoping 10 and screening methodology, procedures, quality 11 controls applicable to the LAR development, and 12 training of its project personnel.
13 The staff also reviewed the various 14 summaries of safety-related systems, structures, and 15 components or SSCs, non-safety SSCs affecting safety 16 functions, and SSCs relied upon to perform functions 17 applicable to River Bend in compliance with the 18 Commission's regulations for fire protection, 19 environmental qualification, station blackout, and 20 anticipated transience without scram.
21 Based on the review results from the 22 scoping and screening audit and additional information 23 provided by the applicant, the staff concludes that 24 the applicant's scoping and screening methodology and 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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62 implementation were consistent with the standard 1
review plan and the requirements of 10 CFR Part 54.
2 Next slide, please.
3 SER Chapter 3 and its subsections cover 4
the staff's review of the applicant's programs for 5
managing aging in accordance with 10 CFR 54.21A3.
6 Sections 3.1 through 3.6 include AMR items 7
in each of the general system areas within the scope 8
of license renewal. For a given AMR item, the staff 9
reviewed the item to determine whether it is 10 consistent with the GALL Report.
11 For the AMR items not consistent with the 12 GALL Report, the staff reviewed the applicant's 13 evaluation to determine whether the applicant has 14 demonstrated reasonable assurance that the effects of 15 aging will be adequately managed so that the intended 16 functions will be maintained consistent with the 17 current licensing basis for the period of extended 18 operation. Next slide, please.
19 The LRA described a total of 43 aging 20 management programs, 11 new, 31 existing, and one 21 plant specific. This slide identifies the applicant's 22 disposition of AMPs in the left column and the staff's 23 disposition of AMPs on the right column.
24 One plant specific AMP was provided. All 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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63 with the exception of the plant specific AMP were 1
evaluated by the staff for consistency with the GALL 2
Report Rev 2.
3 Overall, the staff concluded that 22 AMPs 4
were consistent with the GALL Report. These included 5
12 new programs, 10 existing programs. In addition, 6
13 programs were consistent with enhancements, two 7
consistent with exceptions, and five were consistent 8
with enhancements and exceptions. Next slide, please.
9 SER Section 4 identifies time-limited 10 aging analysis or TLAAs. Section 4.1 documents the 11 staff's evaluation of the applicant's identification 12 of applicable TLAAs.
13 The staff evaluated the applicant's basis 14 for identifying those plant specific or generic 15 analyses that need to be identified as TLAAs and 16 determined that the applicant has provided an accurate 17 list of TLAAs as required by 10 CFR 54.21C1.
18 Sections 4.2 through 4.7 document the 19 staff's review of applicable TLAAs as shown. Based on 20 its review and the information provided by the 21 applicant, the staff concludes that either one, the 22 analysis remain valid for the period of extended 23 operation, two, the analysis has been projected to the 24 end of the period of extended operation, or three, the 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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64 effects of aging on the intended functions will be 1
adequately managed for the period of extended 2
operation as required by 10 CFR 54.21C1 Subparagraphs 3
I, ii, and iii respectively. Next slide.
4 I will now discuss the two follow-up items 5
from the Subcommittee meeting. With regards to the 6
ACRS request for clarification on SER Section 7
2.1.4.2.1, the staff verified that the plant drain 8
system was the only non-safety SSC providing support 9
for safety functions under 10 CFR 54.4A1.
10 LRA Section 2.1.1.2.1, function failures 11 for non-safety related SSCs states that the systems 12 and structures required to support a safety function 13 are classified as safety related and have been 14 included in the scope of license renewal in accordance 15 with 10 CFR 54.4A1.
16 As a result, only one safety-related SSC 17 supporting a safety function was identified. That is 18 the plant drain system which supports maintaining 19 suppression pool inventory for use following a loss of 20 coolant accident and was therefore included within the 21 scope of license renewal in accordance with 10 CFR 22 54.4A2.
23 As verified by the staff, the plant drain 24 system is the only non-safety system credited in the 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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65 LRA for supporting a safety function and it's not just 1
an example. Next slide, please.
2 The second follow-up item was related to 3
the EDG crankcase vent lines. At the September 20 4
ACRS Subcommittee meeting, a concern was raised 5
regarding applicant's response to RAI 2.3.3.16-1.
6 The staff agreed that further 7
clarification of the applicant's RAI response was 8
warranted and the applicant agreed to supplement their 9
original RAI response to provide that clarification.
10 A supplemental response has been submitted 11 and the staff has completed its review and found it 12 acceptable. The staff has also updated the relevant 13 section of its SER and provided that to the ACRS.
14 In its supplemental RAI response, the 15 applicant clarified that with respect to the 16 application of the scoping criteria of 10 CFR 54.4A1, 17 the purpose of the vent pipe for Division I and II 18 emergency diesel engine is to vent the gases from the 19 diesel generator to the outdoors.
20 Upon loss of the vent pipe pressure 21 boundary, the gases would exhaust into the room, but 22 the diesel would continue to perform its function.
23 When the diesel is in operation, the room ventilation 24 system is in service venting the room.
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66 Therefore, the loss of pressure boundary 1
of this vent pipe has no impact on the diesel or 2
personnel and it has no safety function. The function 3
of venting the crankcase to the outdoors is not 4
necessary for the diesel to operate under emergency 5
conditions.
6 The applicant also clarified that the 7
Division III diesel engine removes the crankcase gases 8
via the engine and its exhaust line. In addition, 9
periodic surveillance testing confirms adequate 10 control of crankcase gases for Division I, II, and III 11 diesel engines.
12 With respect to the application of scoping 13 criteria of 10 CFR 54.4A2, non-safety related SSCs 14 whose failure could impact SSCs proving safety 15 function, the applicant clarified that for the 16 Division I and II emergency diesel engines, the non-17 safety related engine vent lines are not subject to 18 aging management review under 54.4A2 because the vent 19 lines contain no liquids that would impact other 20 components in the room from leakage or spray.
21 The vent lines are installed with seismic 22 supports that are subject to aging management review 23 and included in the structures monitoring program.
24 Therefore, the vent lines cannot fall or impose an 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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67 unanalyzed load on the connection to the safety-1 related diesel engine that would render it unable to 2
perform its intended safety function under both normal 3
and seismic conditions.
4 The staff found these clarifications to 5
provide sufficient justification as to why the 6
Division I and II emergency diesel engine vent lines 7
are not within the scope of license renewal per the 8
criteria of 10 CFR 54.4A.
9 The staff updated the relaxant section of 10 the SER to include this clarification, has provided 11 that update to the ACRS, and considers this issue 12 fully resolved. Next slide, please.
13 In conclusion, on the basis of its safety 14 review, the staff finds that the requirements of 10 15 CFR 54.29A are met for the license renewal of River 16 Bend Station Unit 1. This concludes my presentation.
17 Now, if there are any questions, the staff would like 18 to take them at this time.
19 MEMBER SKILLMAN: Thank you, Manny.
20 Colleagues, any questions for the staff that conducted 21 the review here for River Bend?
22 MEMBER MARCH-LEUBA: I should have asked 23 the applicant the same question. Any concrete aging, 24 ASR concrete aging issues identified?
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68 MR. SAYOC: Yes, I have Brian Wittick 1
here, the Chief of the Structural Branch to further 2
elaborate.
3 MR. WITTICK: Yes, my name is Brian 4
Wittick. I'm the Branch Chief of the Structural 5
Engineering Branch that did the review. Similar to 6
Waterford, in reviewing their application, given the 7
amount of work we were doing on ASR at the time, we 8
were particularly sensitive to that particular effect, 9
and so we did a careful review of the operating 10 experience and corrective action program to verify 11 whether or not there was any indications of ASR for 12 River Bend. There were none.
13 And while we were onsite for other audit 14 activities, Angie Buford, who briefed you yesterday, 15 did walk downs in the plant and specifically did look 16 for any indications of ASR and found none.
17 MEMBER MARCH-LEUBA: Yeah, that's what I 18 was going to say, that just looking at the licensee 19 reports, maybe you wouldn't find anything. What you 20 need is a walk down through all the concrete 21 structures with somebody with a trained eye, and it 22 doesn't need to be the staff. It has to be the 23 licensee, the one that's looking for those clear 24 indications.
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69 MR. WITTICK: Correct.
1 MEMBER MARCH-LEUBA: And it doesn't cost 2
that much money. You just need to have a trained eye.
3 MEMBER REMPE: So when you looked for 4
indications, you not only looked for cracks, but you 5
also looked for any unexplained building movement, 6
right?
7 MR. WITTICK: Well, I'm not the structural 8
expert, but when she did her sampling inspections, she 9
said she specifically looked for any indications of 10 ASR and found none.
11 MEMBER REMPE: Thank you.
12 MEMBER KIRCHNER: Emmanuel, I wanted to go 13 back to the fuel question that I raised. So how does 14 this fit into your review? Obviously there was an 15 issue that the applicant has taken what appear to be 16 some appropriate corrective actions to address it.
17 How does that impact -- How does this fit into your 18 review, an issue like that where you have an operating 19 plant and they're seeking an extension or a renewal?
20 We were corrected earlier that plant 21 equipment upgrades aren't the same as committed 22 upgrades, but it seems like the applicant has 23 identified the strainer as one means to prevent 24 foreign objects from getting into the fuel, into the 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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70 core. So how does this -- how do you address that 1
issue as part of this license renewal process?
2 MR. SAYOC: I appreciate the question. As 3
far as the fuel issue and the strainers, that's not 4
within the scope of license renewal. That's a Part 50 5
operating within their scope. Does anybody else want 6
to elaborate from the staff?
7 DR. HISER: Yeah, so really this is not a 8
part of our review. We are focused on passive, long-9 lived systems, structures, and components, and the 10 fuel does not fit within that.
11 MEMBER KIRCHNER: I understand that. So 12 it's under the existing license under 10 CFR 50, but 13 when an issue -- maybe this is a more generic 14 question, not specific just to this plant, but when 15 you have an issue like that that's of concern, how 16 does that factor into your LRA review?
17 DR. HISER: If it's a, if it's operating 18 experience related to an item that's within the scope 19 of license renewal, then we would consider whether 20 that operating experience is consistent with the 21 boundaries of the appropriate GALL aging management 22 program, and if it exceeds the boundaries, then the 23 plant normally would implement some enhancement to 24 their program to adequately manage that aging effect 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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71 in the future.
1 For example, they may do more extensive 2
inspections. Instead of visual examination, they may 3
do ultrasonic. They may do inspections more 4
frequently than the GALL AMP would indicate.
5 MEMBER KIRCHNER: My concern is that this 6
falls kind of betwixt and between. It appears that 7
the applicant has a plan in place to address it, but 8
it is an aging effect if indeed parts or pieces get 9
into the primary system and then find their way into 10 the core.
11 Those parts are displaced because of 12 aging, or corrosion, or migration, whatever. How do 13 you -- you know, I understand you have these AMPs and 14 all of the GALL Report, but, I mean, this is a real 15 issue obviously for the existing license, but it also 16 suggests that there may be aging effects that impact 17 the license -
18 MEMBER SKILLMAN: I'd like to weigh in on 19 this. Well, let me chime in. I loaded eight lead 20 test assemblies one time. We thought we had found the 21 magic path through the swamp of fuel. All eight of 22 them fell apart. We had parts and pieces all over 23 TMI-1.
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72 design issue, the fuel, and we worked our way through 1
that very painfully as a team, worked our way through 2
that. So when a probe fails or a device fails, it's 3
not necessarily an aging issue. It can be simply a 4
mechanical failure.
5 So I think to try to couple the events 6
that triggered the installation of the feedwater 7
filter with AMP probably isn't cricket. From time to 8
time, the plants get older, things happen, or you 9
install a new device and the device doesn't function 10 the way it was advertised and you deal with it.
11 So I'm adverse to connecting what has 12 happened to the fuel at River Bend, if you will, to 13 either a failed AMP or lack of clairvoyance on the 14 plant staff. That fires some emotion in me that -
15 MEMBER KIRCHNER: That's not where I was 16 going with this. I'm just interested in exploring 17 this interface. You have something that has happened 18 due to aging of the plant. Either a component wears 19 out prematurely -- I mean, it wasn't an expected 20 failure, I don't think.
21 MEMBER SKILLMAN: Okay.
22 MEMBER KIRCHNER: So the plant is 23 operating. It's aging. Things will break. I 24 understand that. I was just concerned that this kind 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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73 of falls in a gap, an interesting gap. The fuel did 1
not fail because of the defect in the fuel design. It 2
was caused by something in the plant that had aged or 3
failed, and it's just an interesting -- I'm just 4
checking to see how this gets factored into the 5
6 MR. DONOGHUE: So Member Kirchner, this is 7
Joe Donoghue. I'm going to use a different example to 8
tell you our thought process, but before I get there, 9
what our expectation is is something like this gets 10 factored into the plant's programs to evaluate and 11 determine the cause. I can let them speak to that in 12 any detail, but leading to another example, the 13 Anchor/Darling valve problem.
14 When that occurred, one of the things that 15 we did working with the Division of Engineering was to 16 try to fully understand the cause of that to see if it 17 was an aging-related mechanism, to see if it needed to 18 be part of our license renewal, a normal, regular 19 license renewal protocol, and we determined not.
20 And I'll tell you that, you know, this is 21 an -- you're right. It's worth -- we have to look at 22 these and think about them, and pull the string on 23 what the cause is and see if it's an aging-related 24 one.
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74 And there's a list of other issues, and 1
I'll be as -- I'll illustrate it this way. In 2
George's office, the Director who is here, when there 3
are material-related issues that occur, he's got them 4
listed on his white board in his office, and for this 5
reason, we evaluate them.
6 We work closely with the Division of 7
Engineering. And if we determine, if it's determined 8
that it's an aging-related mechanism for a passive 9
component, we then have to consider how it's going to 10 be dealt with in a normal review protocol. Allen, do 11 you have more?
12 DR. HISER: The only other thing I would 13 say is passive long-lived, it's within the scope of 14 license renewal, and if it's not within the scope of 15 license renewal, it is not a part of our review, but 16 that does not obviate the plant needing to make 17 effective corrective actions to remediate a situation, 18 identify root cause, and things like that. That is 19 still -- that's a Part 50 process that is incumbent on 20 the plant.
21 MEMBER KIRCHNER: I know it's under the 22 existing license. I appreciate that, but let me ask 23 you, does the aging management program for reactor 24 vessels, internals, and coolant system, would that 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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75 pick this up going forward?
1 MR. MEDOFF: Hello, this is Jim Medoff of 2
the staff. I was the staff reviewer for the 3
applicant's reactor vessel internals program. We did 4
come across one example of a situation exactly what 5
you're talking about which was mentioned earlier in 6
the presentation, which was the hole in the feedwater 7
sparger.
8 As we've said, that is a Part 50 issue, 9
but we did assess whether it could potentially impact 10 the aging management programs. We did do our 11 appropriate due diligence. We turned it over to the 12 Division of Operating Reactor Licensing and with the 13 Region. We had several calls with the applicants on 14 the operating experience to determine whether there 15 would be any impacts on aging.
16 For instance, if you had a part that was 17 generated as a loose part, could it vibrate against 18 the reactor vessel or any of the internals and cause 19 them to wear away, which would be an aging effect, so 20 we did evaluate that. So it's not like we ignored 21 this.
22 We do evaluate specifically those effects 23 and our conclusion is after talking with the licensee, 24 hearing what the licensee had to say with us over the 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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76 phone, and in phone calls with counterparts that were 1
involved from the Division of Engineering and with the 2
regional office, we concluded there were no impacts, 3
that even though it was Part 50 driven event, that 4
could cause like an aging effect later on in one of 5
the components that was scoped in for renewal and 6
screening in for an aging management review.
7 In regards to the fuel assemblies, those 8
are never scoped for renewal. Those are -- they may 9
be scoped in for renewal, but they're never subject to 10 an aging management review because they're passive and 11 long lived. So operating experience involved with 12 those types of things would never come away. We 13 always leave it as a Part 50 issue.
14 MEMBER BALLINGER: So what you're saying 15 is this is a River Bend specific issue, not a BWR 16 generic issue? There's no other experience out in the 17 fleet where similar debris production has occurred?
18 MR. MEDOFF: No, I'm not saying that. I'm 19 saying because the fuel assemblies, they may be scoped 20 in for renewal, and they're not subject to AMR because 21 they're replaced on a specified time frame set by 22 their core offload, so experience like that would 23 never been considered for its impacts on aging because 24 they're not subject to AMR.
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77 MEMBER BALLINGER: Yeah, I'm not talking 1
about the fuel. I'm talking about the structure. So 2
have there been other similar cases where these 3
components have produced debris which ended up in the 4
vessel?
5 DR. HISER: I'm not aware of any. There 6
may be, but they have not -
7 MEMBER BALLINGER: But that would -
8 DR. HISER: They would be on a plant 9
specific basis. If the plant had a history of doing 10 that, then again, through the Part 50 original 11 operating license context, then they would take 12 appropriate measures to ensure that that doesn't 13 happen, that -
14 MEMBER BALLINGER: Okay, but I'm talking 15 about other plants as well. In other words, in other 16 BWRs, you're saying that this is a unique -- these 17 debris production devices were unique to this plant 18 and not to some other, and not likely to occur in 19 other similar plants?
20 DR. HISER: I don't know that I would say 21 either one of those. I'm not aware of other plants 22 that had these kinds of filters, and maybe River Bend 23 could comment on that, and there may be other plants 24 that have had issues with this.
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78 MEMBER BALLINGER: Okay.
1 MEMBER MARCH-LEUBA: All BWRs have leakage 2
at one time in their lives. I mean, this is a common 3
thing. It's not specific to River Bend.
4 MR. HENDERSON: This is James Henderson, 5
Engineering Director for River Bend. When we did look 6
at the conductivity probe failure that had the hole in 7
the sparger that caused some of the debris to get into 8
the vessel, there was Dresden that had a similar OE 9
where a conductivity probe had broken and caused an 10 issue in their feedwater spargers as well, so there is 11 industry operating experience for that.
12 MEMBER MARCH-LEUBA: Yeah, but you did 13 take positive steps by buying the GNF fuel with the 14 filter at the bottom because you know that fuels pass 15 in your system, and we found out there were not 16 sufficient enough, but you put in the additional 17 filter which is even better?
18 MR. HENDERSON: That's correct.
19 MEMBER MARCH-LEUBA: And the only thing I 20 can blame you for is during the license renewal, 21 you're trying to take credit for that filter when it 22 doesn't really belong there. That filter wasn't 23 really used for operating concerns. It has nothing to 24 do with the license renewal. You were just so proud 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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79 of it that you wanted to show us the picture, but it 1
didn't belong in this presentation.
2 MR. HENDERSON: The intent of the 3
inclusion in the presentation was just to show the 4
upgrades that we have planned for the station.
5 MEMBER MARCH-LEUBA: Yeah, so we're 6
confused because you put it in there when it really 7
doesn't belong.
8 MR. HENDERSON: I understand.
9 MEMBER KIRCHNER: Okay, thank you.
10 MEMBER SKILLMAN: Colleagues, any other 11 questions for the NRC staff, please?
12 MEMBER DIMITRIJEVIC: I have a question on 13 this follow up on the vent for the diesel generator 14 room. Is there any other electrical equipment there 15 like, you know, intermediate basks or controls? Is 16 there any, other than the diesel generator, is there 17 any other electrical equipment in that room, and if 18 yes, was then the room heat up calculation performed 19 to show that that can operate without the vent?
20 MR. SAYOC: Yes, I appreciate the 21 question. This is regarding the second follow up, 22 right, the emergency diesel generator grid lines?
23 MEMBER DIMITRIJEVIC: Right, right.
24 MR. SAYOC: Okay, I'd like to call upon 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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80 Mr. Dave Nold to elaborate on the follow-up item.
1 Thank you, David.
2 MR. NOLD: This is David Nold with the 3
Containment and Ventilation Systems Branch. With 4
respect to other equipment, safety-related equipment 5
in the area of the vent lines, is that what you're 6
talking about?
7 According, well, all I had to do was rely 8
on the answer of the supplemental response, was the 9
fact that these pipes do not leak. They do not 10 contain fluid. There's no potential impact there.
11 MEMBER DIMITRIJEVIC: My concern was about 12 other electrical equipment in this diesel generator 13 room, like a bask which the diesel generator connects 14 to and goes to the emergency switch or the controls 15 for the diesel generator. Is there any other 16 electrical equipment which can be sensitive to 17 temperature? That's my concern.
18 MR. NOLD: Temperature.
19 MEMBER DIMITRIJEVIC: Yes.
20 MR. HENDERSON: This is James Henderson 21 with River Bend Station, Engineering Director. For 22 the emergency diesel generator room, there are no 23 other switch gears that are in the room. It is only 24 the diesel generator. There's a control room that is 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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81 next to the room. It's separated by a fire-rated 1
door, but that room only has auxiliaries that support 2
the diesel generator function.
3 MEMBER DIMITRIJEVIC:
And which 4
auxiliaries are in that room?
5 MR. HENDERSON: It's related to -- there's 6
an equipment room, the air compressors associated with 7
the diesel, some of the jacket water pumps. Those 8
power supplies come within that diesel generator room.
9 It's not a cross-divisional, other power supplies or 10 electrical buses there.
11 MEMBER DIMITRIJEVIC: And none of this 12 equipment is sensitive to the temperature heat up in 13 the room?
14 MR. HENDERSON: That's correct.
15 MEMBER DIMITRIJEVIC: All right, so is 16 this the case in other applications? Did you always 17 see the venting to the diesel generator room is out of 18 the scope? We just had Waterford this morning, so, I 19 mean, I was just wondering. Did they also exclude it?
20 MR. NOLD: When I first got feedback on 21 this issue, I did do a search of other license 22 renewal, the SEs. I couldn't find anything that this 23 ever has been surfaced before this question, so it is 24 unique as far as I know.
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82 MEMBER DIMITRIJEVIC: All right.
1 MEMBER SKILLMAN: Colleagues, any other 2
questions for the staff? Hearing none, Manny, thank 3
you, and Mike, back to you.
4 CHAIRMAN CORRADINI: Okay, what we're 5
going to do is take a break for lunch and come back at 6
1:00. We're off the record after this discussion 7
because we'll be going through our draft slides to 8
report to the Commission for our December meeting. So 9
we'll be back here, the Committee will be back here at 10 1:00.
11 For those on River Bend that want to see 12 and be present for the letter making session, that 13 will probably be something around 2:00 to 2:15.
14 You're more than welcome to stay and listen to us 15 prepare slides for the Commission, but I sense that 16 you might have other profitable things to do.
17 MEMBER REMPE: Mike, just to make sure 18 that we're in compliance -
19 CHAIRMAN CORRADINI: We're in compliance.
20 I checked.
21 MEMBER REMPE: Did you adjust -
22 CHAIRMAN CORRADINI: Yes.
23 MEMBER REMPE: Okay.
24 MEMBER MARCH-LEUBA: And we're off the 25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
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83 record for the rest of the week, so he can go home?
1 CHAIRMAN CORRADINI: I just said that.
2 Yeah, he's off. We're off the record.
3 (Whereupon, the above-entitled matter went 4
off the record at 11:49 a.m.)
5 6
7 8
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Waterford 3 License Renewal
Name Title John Dinelli Site Vice President, Waterford 3 Brian Lanka Director, Engineering John Jarrell Sr. Manager, Operations Garry Young Director, License Renewal 1
Entergy Presenters
- Background
- Site Description
- Plant Status
- Licensing History
- Major Equipment Upgrades
- License Renewal Project
- Aging Management Programs and Commitments
- Conclusion 2
Agenda
- 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 Site Description
- 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 Plant Status
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
Waterford 3 Licensing History
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
Major Equipment Upgrades
8 Photos - New Traveling Screens
9 Photos - New Steam Generators
10 Photos - New Reactor Head
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 Major Equipment 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 reviews
- LRA format and content
- Used Revision 2 of NUREG-1801 12 Waterford 3 License Renewal Project
SER issued August 17, 2018
- No open items
- No confirmatory items 13 Safety Evaluation Report
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 Aging Management Programs
- 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
- Similar new AMPs and AMP enhancements have been successfully implemented at other Entergy plants 15 Program Commitment Implementation
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 Conclusion
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 3
Audit / Inspection Dates Location Scoping & Screening Methodology Audit June 13 - 16, 2016 Onsite Aging Management Program (AMP) Audits July 11 - July 29, 2016 Onsite Region IV 71002 Inspection: Scoping and Screening and AMPs January 30 - February 16, 2017 Onsite
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
- 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
Applicants Original Disposition of AMPs 12 new programs 10 consistent 2 consistent with exceptions 29 existing programs 9 consistent 17 consistent with enhancements 2 consistent with enhancements and exceptions 1 plant specific Final Disposition of AMPs in SER 12 new programs 10 consistent 2 consistent with exceptions 29 existing programs 6 consistent 19 consistent with enhancements 3 consistent with enhancements and exceptions 1 plant specific 7
3.0.3 - Aging Management Programs (AMPs)
SER Section 3
- 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
SER Section 4
- 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 Conclusion
River Bend Station License Renewal
1 Entergy Presenters Name Title Bill Maguire Site Vice President James Henderson Director, Engineering Tim Schenk Manager, Regulatory Assurance Garry Young Director, Fleet License Renewal
2 Agenda
Background
- Site Description
- Plant Status
- Licensing History
- Major Equipment Upgrades License Renewal Project
- License Renewal Application (LRA)
- Aging Management Programs and Commitments Conclusion
3 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
4 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
5 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)
Construction Permit March 25, 1977 Operating License November 20, 1985 Commercial Operation June 16, 1986 5% Power Uprate November 2000 Power Uprate License Amendment (1.7% Thermal Power Optimization)
January 31, 2003 LRA Submitted May 25, 2017 Operating License Expiration August 29, 2025 6
RBS Licensing History
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
Major Equipment Upgrades
8 Photos - Digital EHC Human Machine Interface for EHC on the H13-P680 Panel
9 Photos - 480 V Loadcenter Breakers
10 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
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 Major Equipment Upgrades
12 Photos - Neutron Absorber Prototype Inserts Start of absorber insertion Full insertion. Ready to retract tool
13 Photos - Feedwater Strainer
14 Photos - Feedwater Level Controls
15 Major Equipment Upgrades RBS 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 review LRA format and content
- Used Revision 2 of NUREG-1801
- 18-month NRC review schedule
16 Safety Evaluation Report SER issued August 2018
- No open items
- No confirmatory items
17 Major Equipment Upgrades
- 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 Aging Management Programs and Regulatory Commitments
18 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 Similar new AMPs and AMP enhancements have been successfully implemented at other Entergy plants
19 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.
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 3
Audit / Inspection Dates Location Operating Experience Audit October 2 - 13, 2017 Rockville Scoping & Screening Methodology Audit October 24 - 26, 2017 Onsite Aging Management Program (AMP) Audits October 16 - November 8, 2017 November 6 - 10, 2017 NRC HQ Onsite Region IV 71002 Inspection: Scoping, Screening, and AMPs February 26 - March 2, 2018 March 19 - 23, 2018 Onsite
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 5
- 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
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 Applicants Disposition of AMPs 11 new programs
All consistent 31 existing programs
12 consistent
13 consistent with enhancements
2 consistent with exceptions
4 consistent with enhancements and exceptions 1 plant-specific existing program Final Disposition of AMPs in SER 12 new programs
All consistent 30 existing programs
10 consistent
13 consistent with enhancements
2 consistent with exceptions
5 consistent with enhancements and exceptions 1 plant-specific existing program 7
3.0.3 - Aging Management Programs (AMPs)
- 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 SER Section 4 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
10 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.
11 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.
Conclusion