ML15037A719
| ML15037A719 | |
| Person / Time | |
|---|---|
| Site: | Sequoyah  |
| Issue date: | 02/06/2015 |
| From: | Kent Howard Advisory Committee on Reactor Safeguards |
| To: | Advisory Committee on Reactor Safeguards |
| Howard K | |
| References | |
| NRC-1196 | |
| Download: ML15037A719 (129) | |
Text
UNITED STATES NUCLEAR REGULATORY COMMISSION ADVISORY COMMITTEE ON REACTOR SAFEGUARDS WASHINGTON, DC 20555 - 0001 February 6, 2015 MEMORANDUM TO: ACRS Members FROM:
Kent Howard, Senior Staff Engineer /RA/
Technical Support Branch, ACRS
SUBJECT:
CERTIFICATION OF THE MINUTES OF THE SEQUOYAH NUCLEAR PLANT, UNITS 1 AND 2 PLANT LICENSE RENEWAL SUBCOMMITTEE HELD ON NOVEMBER 5, 2014 The minutes for the subject meeting were certified on February 4, 2015. Along with the transcripts and presentation materials, this is the official record of the proceedings of that meeting. A copy of the certified minutes is attached.
Attachment:
As stated cc: E. Hackett M. Banks
UNITED STATES NUCLEAR REGULATORY COMMISSION ADVISORY COMMITTEE ON REACTOR SAFEGUARDS WASHINGTON, DC 20555 - 0001 MEMORANDUM TO:
Kent Howard, Senior Staff Engineer Technical Support Branch, ACRS FROM:
Gordon R. Skillman, Chairman Plant License Renewal Subcommittee
SUBJECT:
CERTIFICATION OF THE MINUTES OF THE SEQUOYAH NUCLEAR PLANT, UNITS 1 AND 2 PLANT LICENSE RENEWAL SUBCOMMITTEE HELD ON NOVEMBER 5, 2014 I hereby certify, to the best of my knowledge and belief, that the Minutes of the subject meeting held on November 5, 2014, are an accurate record of the proceedings for that meeting.
/RA/
02/04/15 Gordon R. Skillman, Chairman Date Plant License Renewal Subcommittee
ADVISORY COMMITTEE ON REACTOR SAFEGUARDS MINUTES OF SEQUOYAH NUCLEAR PLANT, UNITS 1 AND 2 NOVEMBER 5, 2014 The ACRS Plant License Renewal Subcommittee held a meeting on November 5, 2014 in Room T2B3, 11545 Rockville Pike, Rockville, Maryland. The meeting convened at1:30 p.m.
and adjourned at 3:13 p.m. The entire meeting was open to the public. Kent L. Howard, Sr.
was the Designated Federal Official for the meeting.
ATTENDEES ACRS MEMBERS/CONSULTANTS Gordon Skillman, Member Ronald Ballinger, Member Dana Powers, Member Harold B. Ray, Member Peter Riccardella, Member Michael T. Ryan, Member Stephen Schultz, Member John Stetkar, Member NRC Staff Emmanuel Sayoc, NRR/DLR Joel Rivera-Ortiz, NRC Region II (via Bridgeline)
Lindsay Robinson, NRR/DLR Daneira Melendez, NRR/DLR Roger Kalikian, NRR/DLR Andrew Pinaris, NRR/DLR Seung Min, NRR/DLR Mark Yoo, NRR/DLR Juan Lopez, NRR/DLR Michael Marshall, NRR/DLR William Holston, NRR/DLR Bill Rogers, NRR/DLR Giovanni Facco, NRR/DLR Allen Hiser, NRR/DLR John Daily, NRR/DLR Kimberly Green, NRR/DLR Mohammad A. Sadollah, NRR/DLR James Medoff, NRR/DLR Chris Miller, NRR/DLR Yoira Diaz, NRR/DLR Certified by: Gordon R. Skillman Certified on: February 4, 2015 1
OTHER ATTENDEES David M. Spears, Tennessee Valley Authority (TVA)
Joy Williams, TVA Kelli Yates, TVA Kylie Loomis, TVA Harold Williams, TVA Michael McBreasty, TVA Raymond Hicks, FirstEnergy Nuclear Operating Company (FENOC)
Cliff Custer, FENOC Lynn Goodman, DTE Electric Marc A. Brooks, DTE Electric Randy Breymaier, DTE Electric Bruce Cummings, DTE Electric Chris Wilson, Exelon
SUMMARY
The purpose of the meeting was to review the license renewal application (LRA) for the Sequoyah Nuclear Plant, Units 1 and 2 (Sequoyah)) and the draft Safety Evaluation Report (SER) with open items. The briefing was provided by representatives from the NRC staff and the applicant, Tennessee Valley Authority (TVA). The meeting transcripts are attached and contain an accurate description of each matter discussed during the meeting. The presentation slides and handouts used during the meeting are attached to these transcripts.
The following table lists the significant issues that were discussed during the meeting with the corresponding pages in the transcript.
SIGNIFICANT ISSUES Issue Reference Pages in Transcript Chairman Gordon Skillman opened the meeting.
4 Chairman Skillman inquired about the equipment reliability index between the two units. TVA responds 12 TVA discussed near term and future plant improvements 17 Chairman Skillman inquired about cathodic protection of buried piping.
TVA responds.
18 2
TVA stated that the LRA was developed using GALL Rev. 2.
23 TVA reviewed 4100 Aging Management Review (AMR) line items 23 TVA stated that 43 aging management programs are required to manage the effects of aging for the period of extended operation. There are 31 existing programs and 12 new. Twenty programs are consistent with GALL. Rev 2. Three programs were identified as not being consistent with GALL during the process and required enhancements. One of those programs required enhancements (Fire Water Systems).
23-24 TVA stated that there are Forty-three commitments associated with the aging management programs, and one associated with the operating experience program (44 commitments total).
24 Chairman Skillman inquired about scoping. TVA responds.
25-29 Member Schultz inquired about what is meant by an informal Operating Experience Report, and to put it in the context of what is meant by doing things in advance of fleet procedural guidance? TVA responds.
30-31 Chairman Skillman and Member Schultz inquired is anyone (TVA) considering Subsequent License Renewal. TVA responds.
31-36 TVA states that the Safety Evaluation Report contains one open item, two license conditions, and no confirmatory items.
36 TVA discusses the open item (Reactor Vessel Internals Program, specifically dealing with neutron fluence at the Upper Core Plate).
36-43 TVA concludes their portion of the meeting.
43-44 Chairman Skillman inquired about verification of CRD and nozzle thickness and nozzle wear. TVA responds 46-48 Member Ballinger inquires about VT3 inspections. TVA responds 51 ACRS Chairman Stetkar inquires about Underground Medium Voltage Cable failures and sump pump problems at Sequoyah. TVA responds 52-57 TVA responds to question concerning plan for inspection of the Upper Core Plate.
58 Manny Sayoc, Project Manager from Division of License Renewal (DLR) for Sequoyah begins DLR presentation.
59 During AMR audit, 35 reviewers examined TVA programs and documentation.
61-62 DLR staff completed initial review of Sequoyah LRA, and issued the SER with one open item on September 29, 2014 62 3
Member Schultz inquired about NRC staff participation in the Region II inspections. DLR responds.
62-63 Joel Rivera-Ortiz of Region II begins his presentation 63-67 Chairman Skillman inquired about the adequacy of inspecting the Essential Raw Cooling Water (ERCW) system as opposed to selecting other critical systems. Region II responds.
67-68 Member Schultz inquires about containment walkdowns. Region II responds.
68-70 ACRS Chairman Stetkar inquires about the ERCW piping condition and problems.
71-73 DLR reported that, on the basis of its review, 17 programs were consistent with GALL Rev. 2, Twenty-four programs are consistent with enhancements, one was consistent with enhancements and exceptions, one was plant specific.
74 DLR discusses open item.
74-77 DLR determined that TVA has provided an accurate list of Time Limited Aging Analyses as required by 10 CFR 54.21C1.
77 Member Riccardella inquires about the open item response received from TVA on estimated fluence for Upper Core Plate. DLR responds.
78-81 Chairman Skillman adjourned the meeting at 3:13 p.m.
83 Action Items Action Items Reference Pages in Transcript TVA and DLR final documentation have to agree on final count for AMPs 23-24 and 74 Documents Provided to the Subcommittee
- 1.
Sequoyah Nuclear Plant, Units 1 and 2, License Renewal Application (Package), dated January 7, 2013 (ML130240007).
- 2.
Safety Evaluation Report with Open Items Related to the License Renewal of Sequoyah Nuclear Plant Units 1 and 2, dated September 2014 (ML14266A033).
4
- 3.
NRC Aging Management Programs Audit Report Regarding the Sequoyah Nuclear Plant Units 1 and 2, dated June 13, 2013 (ML13141A320).
- 4.
NRC NUREG 1801, Revision 2, Generic Aging Lessons Learned (GALL) Report, dated December 2010 (ML103409041).
- 5.
NRC NUREG-1800, Revision 2, Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants (SRP-LR), dated December 2010 (ML103409036).
- 6.
Scoping and Screening Methodology Audit Report regarding the Sequoyah Nuclear Plant Units 1 and 2, dated May 16, 2013 (ML13119A135).
- 7.
NRC Regulatory Guide 1.188, Revision 1, Standard Format and Content for Application to Renew Nuclear Power Plant Operating Licenses, dated September 2005 (ML082950585).
- 8.
Sequoyah Nuclear Plant Units 1 and 2-NRC License Renewal Inspection, Inspection Report 05000327/2013012 AND 05000328/2013012, dated January 31, 2014 (ML14031A291).
5
Official Transcript of Proceedings NUCLEAR REGULATORY COMMISSION
Title:
Advisory Committee on Reactor Safeguards Plant License Renewal Subcommittee Docket Number:
(n/a)
Location:
Rockville, Maryland Date:
November 05, 2014 Work Order No.:
NRC-1196 Pages 1-84 NEAL R. GROSS AND CO., INC.
Court Reporters and Transcribers 1323 Rhode Island Avenue, N.W.
Washington, D.C. 20005 (202) 234-4433 6
1 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 UNITED STATES OF AMERICA 1
NUCLEAR REGULATORY COMMISSION 2
+ + + + +
3 ADVISORY COMMITTEE ON REACTOR SAFEGUARDS 4
(ACRS) 5
+ + + + +
6 PLANT LICENSE RENEWAL SUBCOMMITTEE 7
+ + + + +
8 WEDNESDAY 9
NOVEMBER 5, 2014 10
+ + + + +
11 ROCKVILLE, MARYLAND 12
+ + + + +
13 The Subcommittee met at the Nuclear 14 Regulatory Commission, Two White Flint North, Room 15 T2B3, 11545 Rockville Pike, at 1:30 p.m., Gordon 16 Skillman, Chairman, presiding.
17 COMMITTEE MEMBERS:
18 GORDON R. SKILLMAN, Chairman 19 RONALD BALLINGER, Member 20 PETER RICCARDELLA, Member 21 HAROLD B. RAY, MEMBER 22 MICHAEL T. RYAN, Member 23 STEPHEN SCHULTZ, Member 24 JOHN W. STETKAR, Member 25
2 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 DESIGNATED FEDERAL OFFICIAL:
1 KENT HOWARD 2
ALSO PRESENT:
3 JOHN CARLIN, TVA 4
DARREN BOEHM, TVA 5
DENNIS DIMOPOULOS, TVA 6
ERIN HENDERSON, TVA 7
MIKE HENDERSON, TVA 8
ADAM KEYSER, TVA 9
HENRY LEE, TVA 10 DENNIS LUNDY, TVA 11 WILLIAM PIERCE, TVA 12 PAUL SIMMONS, TVA 13 CHRIS WEBB, TVA 14 NRC STAFF:
15 ALLEN HISER, NRR/DLR 16 ROGER KALIKIAN 17 CHRIS MILLER, NRR/DLR 18 JOEL RIVERA-ORTIZ, RII (by teleconference) 19 EMMANUEL SAYOC, NRR/DLR 20 21 22 23 24 25
3 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 T-A-B-L-E O-F C-O-N-T-E-N-T-S 1
Welcome 2
by Gordon Skillman, Chairman.................4 3
Staff Introduction 4
by Chris Miller, Dir. DLR/NRR................6 5
Tennessee Valley Authority B Sequoyah Nuclear Plant, 6
Units 1 and 2 7
by John Carlin, TVA and team.................8 8
NRC Staff Presentation Opening Remarks 9
by Chris Miller, Dir. DLR/NRR...............60 10 NRC Staff Presentation SER Overview 11 by Emmanuel Sayoc, PM.......................60 12 13 14 15 16 17 18 19 20 21 22 23 24 25
4 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 P-R-O-C-E-E-D-I-N-G-S 1
(1:13 p.m.)
2 CHAIRMAN SKILLMAN:
Good afternoon.
3 Welcome. I'm Gordon Skillman, Chairman of the Plant 4
License Renewal Subcommittee. The subcommittee will 5
review the license renewal application for the Sequoyah 6
Nuclear Plant Units 1 and 2.
7 ACRS members in attendance are Harold Ray, 8
Ron Ballinger, Steve Schultz, Dana Powers, Mike Ryan.
9 We anticipate John Stetkar, the ACRS chairman. The 10 designated federal official is Kent Howard.
11 This afternoon we will hear presentations 12 from the Division of License Renewal from Region II.
13 And from Tennessee Valley Authority regarding this 14 matter, this subcommittee will gather information, 15 analyze relevant issues and facts and formulate 16 proposed positions and actions as appropriate for 17 deliberation by the committee.
18 The rules for participation in today's 19 meeting have been announced as part of the notice of 20 this meeting previously published in the Federal 21 Register.
22 We have not received written comments or 23 requests for time to make oral statements from members 24 of the public regarding today's meeting. The entire 25
5 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 meeting will be open to public attendance.
1 There will be a phone bridge line. To 2
preclude interruption of the meeting, the phone will 3
be placed in a listen in mode during the presentations 4
and the committee discussion.
5 A transcript of this meeting is being kept 6
and will be made available as stated in the Federal 7
Register notice.
8 Therefore, I request that participants in 9
this meeting use the microphones located throughout the 10 meeting room when addressing the subcommittee.
11 The participants are also requested to 12 please identity themselves and to please speak with 13 sufficient clarity and volume so that they can be 14 readily heard.
15 I also ask that all attendees silence their 16 electronic devices. We will now proceed with the 17 meeting, and I call upon Chris Miller to begin the 18 presentation.
19 (Simultaneous speaking) 20 MALE PARTICIPANT: I just had him a minute 21 ago. He's on his way over.
22 CHAIRMAN SKILLMAN: Okay. We'll wait. We 23 will wait.
24 (Whereupon, the above-entitled matter 25
6 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 went off the record at 1:16 p.m. and resumed at 1:19 1
p.m.)
2 CHAIRMAN SKILLMAN: Ladies and gentlemen, 3
we're back in session. I had gotten to the point of 4
the script where I was going to ask Chris Miller, 5
welcome Chris, to please proceed from here.
6 (Simultaneous speaking) 7 MR. MILLER: My calendar said 1:30, so --
8 CHAIRMAN SKILLMAN: I don't know where the 9
error came. We had been at 1300 for the last two 10 months, so I don't know where the 30 minute change came.
11 MR. MILLER: Yes, I'm not aware either, but 12 I think we can go ahead and get started.
13 (Simultaneous speaking) 14 MR. MILLER: Thank you. Whatever the 15 discrepancy was, I apologize.
16 CHAIRMAN SKILLMAN: Thank you everybody for 17 your patience. Thank you. Chris, go ahead.
18 MR. MILLER: Thank you, Mr. Chairman. I'm 19 Chris Miller, Director of Division of License Renewal.
20 With me here I have Yoira Diaz, and she's the Chief of 21 Projects, Branch 1.
22 We have a number of our members in the room, 23 and I won't introduce them all, but we'll introduce most 24 as they come up. I think we have Joel Rivera on the 25
7 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 phone. Can we just test that?
1 CHAIRMAN SKILLMAN: On the bridge line, 2
anyone that's there, please speak up.
3 MALE PARTICIPANT: I don't know that it's --
4 MR. MILLER: I'm told they're still trying 5
to get that, so we'll work to get him in.
6 CHAIRMAN SKILLMAN: Okay.
7 MR. MILLER: He's our lead inspector, and 8
he's in Region II. So hopefully we'll be able to make 9
that tie in. And our presentation will be done by Mr.
10 Emmanuel Sayoc, our Safety PM.
11 And also our Senior Technical Advisor, Dr.
12 Allen Hiser, he's right there. And as I mentioned, 13 after the presentation we'll introduce one by one.
14 Thank you.
15 This is our ACRS subcommittee meeting for the 16 license renewal application of the Sequoyah Nuclear 17 Power Units 1 and 2. The SER will, with open items was 18 issued on September 29, 2014 with one open item.
19 And its resolution will be documented in the 20 final SER. The one open items is regarding the reactor 21 vessel internals program related to the materials 22 reliability program, MRP 227, Action Item 1.
23 It is summarized in the SER reviewed by the 24 ACRS members. Since the issuance of the SER with open 25
8 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 items, the staff has been working diligently to try to 1
get resolution on this item.
2 The staff will summarize its completed 3
review in the final SER and present its findings in the 4
ACRS to the full committee.
5 At this time I'd like to turn the 6
presentation over the Tennessee Valley Authority and 7
the Site Vice President, John Carlin to introduce his 8
people and commence the presentation.
9 MR. CARLIN: Thanks, Chris. Mr. Chairman, 10 I'm John Carlin. I'm the Site Vice President at 11 Tennessee Valley Authority's Sequoyah Nuclear Plant.
12 We really appreciate the opportunity to be 13 here with you today to review the license application 14 for the Sequoyah Plan.
15 This has been a long four year journey, and 16 it's been a very, very important journey for the 17 station. And we look forward to discussing Sequoyah 18 with you.
19 To start mainly, the members of the team at 20 the table to introduce themselves.
21 MR. SIMMONS: Paul Simmons, I'm the station 22 plant manager.
23 MR. PIERCE: William Pierce, the site 24 engineer and director at the station.
25
9 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR. DIMOPOULOS: Dennis Dimopoulos from 1
engineering.
2 MR.
HENDERSON:
Michael Henderson, 3
engineering programs manager.
4 MS. HENDERSON: I'm Erin Henderson. I'm 5
the site licensing manager.
6 MR. LEE: Henry Lee, licensing.
7 MR. CARLIN: Today we also have brought with 8
us a team of subject matter experts. I'd like the 9
entire group to stand as a group.
10 CHAIRMAN SKILLMAN: The center of gravity in 11 the room tilts.
12 MR. CARLIN: If you feel the building tilt, 13 back up. Thank you very much. We really appreciate 14 the men and women who have joined us today and their 15 support.
16 We also have other people on the telephone 17 bridge listening in to provide additional technical 18 support to your discussions today.
19 Paul Simmons will briefly discuss Sequoyah's 20 plant history and background. Paul is a long tenured 21 person, previously a senior reactor operator at the 22 facility.
23 William Pierce will talk about the major 24 modifications. Dennis Dimopoulos and Erin Henderson 25
10 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 will talk about the license renewal application as well 1
as the safety evaluation.
2 And Michael Henderson will discuss our open 3
item. Again, we thank you for meeting with us today, 4
and that concludes my comments.
5 MR. SIMMONS: Thanks, John. Okay. We'll 6
go to Slide 7. The Sequoyah Unit 1, 2 units are located 7
on a 525 acre plot adjacent to the Chickamauga reservoir 8
on the Tennessee River, approximately 18 miles 9
northeast of Chattanooga, Tennessee.
10 Sequoyah supplies approximately 8 million 11 people through 158 distributors in the Tennessee Valley 12 area. Our plant is a two unit Westinghouse 4-loop 13 pressurized water reactor.
14 The generator output capability of each unit 15 at Sequoyah is 1199 megawatts of output rated core 16 power. The Sequoyah containment is a freestanding 17 steel vessel with an ice condenser and separate 18 reinforced concrete shield building.
19 We have two natural draft cooling towers used 20 in helper mode as required to maintained the Tennessee 21 River and environmental commitments that we've made for 22 operating the plant.
23 We have two switchyards on the facility that 24 you can see on the overhead view, 161-KV switchyard and 25
11 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 a 500-KV switchyard.
1 The Unit 1 output goes to the 500-KV 2
switchyard, and the Unit 2 output goes to the 161 3
And both those switchyard are 4
interconnected through transformers.
5 We'll go to Slide 9. Slide 9 slows where the 6
station is located relative to the city of Chattanooga, 7
8 In Slide 10, a little bit more of the 9
background. The construction permit for Sequoyah was 10 issued in May 1970. Our operating license for Unit 1 11 was issued September 17, 1980. For Unit 2, it was 12 issued September 15, 1981.
13 And commercial operation for Unit 1
14 commenced July 1, 1981 and for Unit 2, June 1, 1982.
15 We did do a power upgrade of approximately 44 megawatts 16 thermal on both units in 2002.
17 And we replaced steam generators on Unit 1 18 in 2003 and most recently on Unit 2 in 2013. And today 19 we've had very good operational performance out of 20 these steam generators on both units.
21 Our current status, Sequoyah Unit 1 and Unit 22 2 are operating at 100 percent power. Sequoyah Unit 23 1 is at 100 percent on our INPO Index, and Sequoyah Unit 24 2 is 100 percent on the INPO index.
25
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(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 It gets top quartile performance, 97.5. Our 1
equipment reliability index for Unit 1 is at 97 percent, 2
and at Unit 2 it's at 98 percent. And our next 3
refueling outage for Unit 1 is April 2015, and for Unit 4
2 it's November 2015.
5 CHAIRMAN SKILLMAN:
- Paul, those are 6
admirable numbers. What is the difference, if it's 7
worth talking about, the equipment reliability index 8
between the two units.
9 MR. SIMMONS: This is a slight difference in 10 the index, Mr. Chairman, of 1 percent. And typically 11 what that has been for us has been some unplanned LCOs 12 that we're working through over the last year that have 13 slightly differed between Unit 1 and Unit 2.
14 CHAIRMAN SKILLMAN: Thank you.
15 MR. SIMMONS: Mr. Chairman, that completes 16 my plant overview presentation pending any questions.
17 I'll turn it over to William Pierce.
18 MR. PIERCE: Good afternoon. My name is 19 William Pierce, and this afternoon I will be going over 20 major modifications and near-term improvements that 21 have been conducted at the station.
22 The first item that I'll be going over, which 23 is listed on Page, Slide 13 includes installing full 24 strength weld overlays on pressurizer locations on Unit 25
13 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 1 in 2007, and we installed four structure weld overlays 1
on pressurizer locations on Unit 2 in 2006.
2 There were two purposes for installing full 3
strength weld overlays on these locations. The first 4
purpose was for volumetric inspection purposes, and the 5
second purpose was for primary water stress corroding, 6
cracking resistance.
7 The second item that was listed there far as 8
major modifications that have been completed at 9
Sequoyah includes replacing portions of, balance the 10 plant side piping with flow accelerated corrosion 11 resistant piping.
12 The material of choice that we've chosen to 13 use at the station has been two and a quarter chrome, 14 1 percent moly, which is for accelerated corrosion 15 resistance.
16 As Paul mentioned earlier, we did replace 17 steam generators on Unit 1 in 2003 and then on Unit 2 18 in 2013. And the tubing material that we currently use 19 for our steam generators is alloy 69.
20 MEMBER BALLINGER: Is that thermally 21 treated?
22 MR. PIERCE: Yes, sir. That is correct, 23 thermally treated alloy 69. In addition, we have 24 replaced main condenser tube bundles with titanium 25
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(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 tubes. And we also have titanium clad tube sheets.
1 Also, we replaced portions of our carbon 2
steel sacrilated raw water piping. Currently we have 3
replaced piping this physical year in 2014.
4 We do have funding scheduled in the out years 5
for 2015, 2016 and 2017 for piping replacements. In 6
addition, we replaced fire protection pumps, tanks and 7
changed water source from raw water to potable water.
8 And to close out this slide, we replaced 9
containment spray heat exchanger 1B and component 10 cooling water heat exchangers.
11 CHAIRMAN SKILLMAN: Let me ask you a 12 question on that issue. I see in the SER the 13 description that you're now taking suction from, one 14 each, from your 300,000 gallon potable water tanks.
15 And those are fed by a municipal utility. To 16 what extent is this unit dependent upon other municipal 17 utilities for services such as that?
18 MR. DIMOPOULOS: With respect to the fire 19 water system, we do take, I'm sorry. I'm Dennis 20 Dimopoulos from engineering, Tennessee Valley 21 Authority.
22 The potable water system that we use to 23 supply our fire header system does come from a local 24 utility and has an additional back up onsite. We could 25
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(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 use raw water from the river associated with that.
1 CHAIRMAN SKILLMAN: Okay. That's half my 2
question. The other half is to what extent are you 3
depending on offsite municipal utilities for services 4
such as that. So water is coming in from an offsite 5
vendor --
6 MR. DIMOPOULOS: Right.
7 CHAIRMAN SKILLMAN: -- for instance. Are 8
there are dependencies like that associated with the 9
unit that are substantive, that we should talk about?
10 MR. DIMOPOULOS: Mr. Chairman, I cannot 11 think of any other outside sources but do note the 12 potable water, and we recognize that's a possibility 13 that we could lose that.
14 And we do design around it such that we have 15 onsite backup, so we do not depend on a municipality.
16 MR. SIMMONS: Mr. Chairman, the other piece 17 that we do have services from is for our sewage 18 treatment. We use that with the local municipality.
19 So that's the other interface that we have with the 20 local Soddy-Daisy city.
21 CHAIRMAN SKILLMAN: Okay. Does that, 22 should we interpret then you don't have a sewage plant 23 onsite, and you do not have sewage operators on site?
24 MR. SIMMONS: That's correct.
25
16 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 CHAIRMAN SKILLMAN:
- Yes, sir.
I 1
understand. Paul, thank you. Dennis, thank you.
2 MR. SCHULTZ: William, on the slide that 3
we're discussing here in the last three bullets here, 4
has there been equal treatment on both units in regard 5
to these modifications?
6 MR. PIERCE: Yes, that is correct, Mr.
7 Schultz.
8 MR. SCHULTZ: Thank you.
9 CHAIRMAN SKILLMAN: Let me ask one more 10 somewhat related, Paul, to your comment. One of the 11 portions of the SER communicates regarding station 12 drainage. And I'll read the text so you can understand 13 why I'm asking the question.
14 The license renewal application, Section 15 2.3.3.8 states the purpose of the station drainage and 16 sewage systems is to provide drainage for various 17 equipment and buildings and to collect and process 18 sewage from the plant facilities.
19 The station drainage system collects 20 building roof and floor drains, equipment drains, yard 21 drainage from the entire site, with the exception of 22 the reactor building and auxiliary building, which use 23 the waste disposal system for drainage collection.
24 The station drainage and sewage systems 25
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(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 together provide the sanitary water services for the 1
plant. I'm presuming that your roof drains and other 2
yard drains are separated from sewage.
3 And your sewage is dedicated to your offsite 4
vendor, whereas the yard drains and other find their 5
way back into the Chickamauga reservoir or whatever it 6
is. Is that accurate?
7 MR. SIMMONS: That's correct, Mr. Chairman.
8 CHAIRMAN SKILLMAN: Okay. Thank you.
9 Please proceed.
10 MR. PIERCE: Moving to Slide 14, on Slide 14 11 I'll be talking about the near term and future plant 12 improvements. The first item I'll be going over is 13 items that we have scheduling for our upcoming 14 refueling outage, which is in the spring, which is April 15 2015.
16 We have plans to replace approximately ten 17 thimble tubes. In addition, we plan on replacing the 18 containment spray heat exchanger in 1A.
19 For the fall refueling outage on Unit 2, we 20 will be replacing approximately ten thimble tubes on 21 that particular unit also.
22 As far as the outyears as far as plan 23 improvements, as mentioned earlier, we'll continue to 24 replace portions of carbon steel and safety-related raw 25
18 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 water piping.
1 And also, we have begun to design and began 2
installing cathodic protection. And as far as 3
cathodic protection, we're looking to start the design 4
in 2015 and complete design as far as implementation 5
in 2017.
6 MEMBER BALLINGER: Cathodic protection of 7
what?
8 MR. PIERCE: Cathodic protection of buried 9
piping.
10 MEMBER BALLINGER: Oh, buried pipe?
11 MR. PIERCE: Yes.
12 CHAIRMAN SKILLMAN: What is the status of 13 cathodic protection today?
14 MR. PIERCE: Mr. Chairman, the current 15 status of cathodic protection today, as I mentioned in 16 my slide, we have started the design which will start 17 in 2015.
18 We will have full implementation in 2017, and 19 we do have the high pressure fire protection tank that 20 has cathodic protection. And that is the current 21 status as of today, Mr. Chairman.
22 CHAIRMAN SKILLMAN: So one tank or two tanks 23 and that's it today?
24 MR. SIMMONS: Two tanks.
25
19 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 CHAIRMAN SKILLMAN: The two 300,000 gallon 1
tanks, and that is the extent of your --
2 MR. PIERCE: Yes, sir.
3 CHAIRMAN SKILLMAN: -- cathodic protection.
4 How then do you know that for all of those years, with 5
all of that buried piping, your buried piping is okay?
6 MR. PIERCE: Mr. Chairman, I'm going to ask 7
Mr. Kyle Loomis to speak to your question.
8 MR. LOOMIS: Kyle Loomis, engineering 9
programs. Mr. Chairman, we have implemented a buried 10 piping program at the site. It's based on the NEI 09-14 11 initiative and milestones.
12 During this time period we have done both 13 proactive and opportunistic inspections on the buried 14 piping at the plant.
15 CHAIRMAN SKILLMAN: Would that same program 16 be applied through your buried tanks also?
17 MR. LOOMIS: Not for our seven day tanks.
18 That's a separate program from what the UPTI program, 19 as we call it, under piping and tanks integrity 20 initiative.
21 MR. DIMOPOULOS: Mr. Chairman, if I may, 22 this is Dennis Dimopoulos. The only, we do not have 23 buried tanks for the Sequoyah Nuclear Plant with the 24 exception of the diesel generator seven day tanks.
25
20 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 CHAIRMAN SKILLMAN: Thank you.
1 MR. PIERCE: And to conclude, the last item 2
I will be discussing as far as multi year projects is 3
that we will continue to replace CRD and auxiliary HVAC 4
cooling coils.
5 And that ends my presentation, Mr. Chairman.
6 Now, I'll be turning over to Erin Henderson who will 7
go over our license renewal application preparation.
8 MS. HENDERSON: Thanks William. My name's 9
Erin Henderson. I'm the site licensing manager, and 10 I'm going to talk about how we developed our license 11 renewal application.
12 As John mentioned, this has been a few years 13 in the making here. We began the process of developing 14 our application and assembling our team in 2010.
15 At that time we put together a team of 16 experienced individuals that had been involved in 17 several other successful license renewal projects, and 18 they provided us the support in developing our 19 application.
20 They brought along with the their proven 21 processes and procedures. Most of the key players that 22 were involved in that application are here in the room 23 today and were previously introduced when John had 24 everybody stand up.
25
21 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 Our qualified site program owners and system 1
engineers were trained in the license renewal process.
2 Over the past few years they've provided the reviews 3
of aging management reports and the program evaluation 4
report.
5 And their knowledge and feedback is really 6
key to this process and is really especially evident 7
in the operating experience portion of the application.
8 CHAIRMAN SKILLMAN: Erin, may I ask you to 9
describe briefly the type of training, the content of 10 the training for those individuals, please?
11 MS. HENDERSON: I'm going to have Dennis 12 Lundy speak to that.
13 MR. LUNDY: My name is Dennis Lundy for the 14 license renewal project. The training we conducted is 15 a fairly standard page developed by Altran. It's 16 covering the capital systems, electrical systems, 17 civil structures.
18 It talks about aging effects, managing those 19 aging effects, how to detect aging effects when you're 20 walking through the plant. It's to help the team 21 develop that understanding.
22 CHAIRMAN SKILLMAN: Thank you.
23 MEMBER POWERS: Tell us what it does with 24 respect to coatings?
25
22 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR. LUNDY: I'm sorry.
1 MEMBER POWERS: Could you tell us what it 2
does with respect to coatings?
3 MEMBER POWERS: Did the training include 4
coatings? The training did not include coatings.
5 (Simultaneous speaking) 6 CHAIRMAN SKILLMAN: Erin, please continue.
7 MS. HENDERSON: Thanks. We've had a lot of 8
very experienced individuals review, provide reviews 9
and comments on the technical reports, and that 10 supported the application.
11 The project members have been engaged in NEI 12 working groups, and so the project has been represented 13 along with, in the civil, mechanical and electrical 14 working groups as well.
15 We did an industry peer review of the 16 application, and that resulted in over 300 comments 17 that we individually dispositioned.
Dennis 18 Dimopoulos is going to provide some more insights into 19 the outcome of the application.
20 MR. SCHULTZ: When was the industry peer 21 review conducted?
22 MS. HENDERSON: Dennis Lundy will --
23 MR. LUNDY: Would you repeat the question, 24 please?
25
23 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR. SCHULTZ: When was the industry peer 1
review conducted?
2 MR. LUNDY: In the summer of 2012.
3 MR. DIMOPOULOS: Okay. We're on Slide 18 4
right now, and I'll talk a little bit about the 5
application details. It was submitted in January 6
2013. It was developed using the latest provision of 7
the NUREG-1801 or the GALL report. That's Rev 2.
8 We used NEI 95-10 for the scope and guidance 9
and the aging management review details, and we did have 10 extensive peer reviews, over 15 peer reviews, as we went 11 through the process.
12 Additionally, along with this latest 13 revision of the GALL, we did address six interim staff 14 guidance documents and two more interim staff guidance 15 documents that came up during the REI process.
16 In all, there was 4100 aging management 17 reviewed line items. That's looking at component, 18 environment and developing those aging management 19 programs.
20 And all 43 aging management programs are 21 required to manage the effects for the period of 22 extended operation, 31 existing and 12 new.
23 If we move over to Slide 19, we'll look at 24 a breakdown that summarizes aging management program 25
24 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 reviews in relation to the GALL.
1 So for our application we identified 20 2
programs that we felt were consistent with the GALL and 3
following the SER issuance. We've got a very good, 4
rigorous region review and inspections and NR review 5
through our process.
6 And you'll notice the delta with the SER. We 7
had three programs that during that process were not 8
consistent with the GALL and required enhancements.
9 And one of those required exceptions. And that one was 10 associated with the fire water system.
11 So moving on to Slide 20, license renewal 12 commitments. It is included, that the commitments 13 will be included in FSAR supplement, which is Appendix 14 A of the license renewal application.
15 It will be tracked and managed through our 16 commitment tracking system and our corrective action 17 program. In all, 44 commitments associated with aging 18 management
- programs, 43 associated with aging 19 management programs and one associated with the 20 operating experience program, excuse me.
21 Slide 21 we'll talk about implementation.
22 So as we're moving through our issuance of the SER, and 23 we're focusing, shifting from application development 24 to implementation of commitments.
25
25 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 So we have Michael Henderson to my right. He 1
is participating in the NEI implementation working 2
group. Additionally, the site has selected a 3
permanent license renewal coordinator, and that is Joy 4
Williams who is here with us today.
5 And she is presently engaged in a review of 6
operating experience for aging management program 7
impacts and implementation efforts.
8 CHAIRMAN SKILLMAN: Before you change, this 9
is probably the best place to fit in my next question, 10 and it had to do with scoping.
11 In the status report that the staff provided 12 to the ACRS for the ACRS review for this meeting, the 13 wording is as follows.
14 The audit team determined that the 15 applicant's scoping methodology was generally 16 consistent with 10 CFR 54.
17 However, the audit team determined that 18 additional information was required in order for staff 19 to complete its review.
20 And the three bullets are the methods used 21 and the basis for any conclusions in which components 22 identified as safety-related in the plant equipment 23 database were not included in the scope for license 24 renewal.
25
26 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 The second bullet, methods used and basis for 1
conclusions in which Category 1 structures were not 2
included in the scope for license renewal.
3 And the third bullet, methods used and basis 4
for conclusions in which non safety-related structures 5
adjacent to Category 1 safety-related structures were 6
not included in the scope. Would you please speak to 7
that?
8 MR. DIMOPOULOS: Mr. Chairman, I'm going to 9
ask Mr. Lundy to provide some additional details.
10 MR. LUNDY: My name is Dennis Lundy with the 11 license renewal project. On the first category used, 12 there's, in our equipment database at Sequoyah in some 13 cases we have conservatively classified the components 14 of safety-related.
15 One example would be our fifth diesel 16 building. It was a, as part of the original plant 17 design along about the first or second year there's 18 going to be a new diesel building built.
19 And the components inside that building, 20 although they were never put in service, they were still 21 classified in the database as safety-related.
22 We never had, we wanted to maintain that 23 equipment in a safety-related status, but that 24 equipment has never been operational. It serves no 25
27 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 intended function for license renewal.
1 So that is an example. There are several of 2
those like that. The equipment database was 3
classified conservatively by a management decision and 4
left that way.
5 We went through each one of those. We 6
through the whole database with the staff, reviewed 7
each one of the items identified and developed the 8
understanding of why those were there. We made no 9
changes as a result of that.
10 The second two items, I think, if you would 11 repeat that question. Make sure I answer it --
12 (Simultaneous speaking) 13 CHAIRMAN SKILLMAN: The first category was 14 category where there were safety-related items in the 15 plant database that were not included in the scope of 16 license renewal.
17 MR. LUNDY: Okay. That's what I just did.
18 CHAIRMAN SKILLMAN: And I can understand 19 that. As long as none of those were credited for any 20 license or design basis issue.
21 MR. LUNDY: Yes, sir.
22 CHAIRMAN SKILLMAN: The second category is 23 Category 1 structures not included within the scope for 24 license renewal. Might that be the building in which 25
28 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 that engine was located or something such as that?
1 MR. LUNDY: Again, we have, one example is 2
our waste processing building. That particular 3
building in SAR is classified as a Category 1 structure.
4 However, there is no safety-related components inside 5
that building.
6 So we had classified that as basically an 7
alpha-2 structure, and assessment of the staff, and we, 8
they concurred with our classification that it was not, 9
even though it was a Category 1 structure, it didn't 10 need to be in the rule as a Category 1 structure.
11 CHAIRMAN SKILLMAN: I see.
12 MR. LUNDY: The last one dealt with our 13 service building. Our service building is adjacent to 14 our control building, auxiliary building.
15 With the initial scoping it was not in scope.
16 We did questioned on that by the staff. At one time 17 we had an analysis that said that building will not fall 18 on the control building, auxiliary building under a 19 seismic event.
20 After reviewing those, that documentation we 21 felt the station made the decision that is the right 22 thing to go ahead and bring that particular facility, 23 the service building into scope.
24 CHAIRMAN SKILLMAN: So it is now seismic so 25
29 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 that it can't fall on the adjacent building?
1 MR. LUNDY: It is not seismic, but we brought 2
that into, that building will now be monitored as part 3
of a structure monitoring program just like a Category 4
1 structure.
5 So we're given the confidence that it will 6
perform its function. It will not fall on that, the 7
adjacent building. Yes, sir.
8 CHAIRMAN SKILLMAN:
You've given 9
approximately four examples. Is that the totality of 10 this particular issue, or is there more that we need 11 to hear about?
12 MR. LUNDY: That's all that I can think of 13 right now, Mr. Chairman.
14 CHAIRMAN SKILLMAN: That's the whole story 15 as far as you can tell?
16 MR. LUNDY: Yes, sir.
17 CHAIRMAN SKILLMAN: Thank you. Please 18 proceed.
19 MR. DIMOPOULOS: Okay. We're still on 20 Slide 21, so basically our Sequoyah program owners, 21 many of whom you see here today, they are engaged in 22 the review of our license renewal implementation issues 23 and will guide implementation of the commitments in 24 regard to their specific programs as we move forward.
25
30 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR. SCHULTZ: Dennis, before you move on, 1
could you elaborate on the third bullet there?
2 Describe what is meant by an informal OE review and put 3
that in the context of what you mean by doing things 4
in advance of a fleet procedural guidance.
5 So is the fleet procedural guidance holding 6
anything up for Sequoyah?
7 MR. DIMOPOULOS: No, sir. Mr. Schultz, one 8
of the commitments that we made was to the operating 9
experience program.
10 And we're going to revise that program along 11 with some other station procedures to put the permanent 12 hooks and I say the culture into the station to address 13 things from a license renewal perspective.
14 So it goes further than the program owners 15 we see here today that we've trained, so it becomes 16 sustained long-term.
17 Until those procedures get implemented, we 18 have basically a gap measure that we've closed to 19 establish a person in the interim until all those 20 procedures and the commitments, some of them include 21 training for our initial and continuing training 22 programs, et cetera.
23 Until that gets closed, we have actions in 24 place where we're going to review the OE for those 25
31 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 triggers that may cause revisions to the aging 1
management programs.
2 MR. SCHULTZ: Okay. And you've identified 3
that individual in addition to the aging management 4
coordinator?
5 MR. DIMOPOULOS: That is the aging 6
management coordinator.
7 MR. SCHULTZ: That is the individual.
8 Okay. I appreciate that. Thank you.
9 CHAIRMAN SKILLMAN: Let me build on Dr.
10 Schultz's question just for a second. Here you are 11 asking for a future license extension of 20 years.
12 You're not going to use this for a couple of years.
13 It's going to take awhile to get it. Once 14 you have it you're not going to use it immediately.
15 You're only going to use it once your current license 16 expires on Unit 1 and then on Unit 2.
17 If I can be so bold, in the answer that you 18 gave to Dr. Schultz, what might you be thinking about, 19 preparations today, for a subsequent life renewal?
20 So you run this plant from 40 to 60. Is 21 anybody thinking 60 to 80 at this point in your 22 considerations?
23 MR. DIMOPOULOS: Mr. Chairman --
24 CHAIRMAN SKILLMAN: John --
25
32 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 (Simultaneous speaking) 1 CHAIRMAN SKILLMAN: We're interested in 2
that because steps that you take today, particularly 3
preservation steps that you take today, have some real 4
long implications.
5 MR. CARLIN: One of the things that, and I 6
appreciate that question for a number of different 7
levels. We've really been focused on making 8
improvements to Sequoyah that are long-term, 9
sustainable improvements.
10 We have made major modifications to our 11 switchyards, to our electrical systems. The 12 implementation of the Appendix R mods at Sequoyah was 13 much more extensive than most places.
14 We replaced miles of cable with the idea of 15 preparing for a long-term. Our focus on how we're 16 managing drainage and how we're managing our up cable 17 tunnels were all set up for long-term.
18 So while we have not embarked on the 60 year 19 plus initiative, our preparations have always focused 20 on that. Same thing goes with coatings.
21 Going in and looking with protective 22 coatings, long-term strategies in terms of digital 23 replacement, all of those things are focused on a 24 long-term traffic for rad monitors for other, equal 21, 25
33 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 other systems that we have in the plant, our rot control 1
systems.
2 All of those things are all focused with a 3
long-term view, with the long view. It isn't just to 4
get to the period of extended operation, but it is a 5
much longer view.
6 And I think the Tennessee Valley Authority 7
has made a commitment to nuclear. I mean it is a big 8
part of our, we've increased it. We have shut down a 9
number of our cold plants.
10 So strategically, the 60 year plus 11 initiative will really be brought to the floor sooner 12 than later. Our Unit 1 at Browns Ferry just entered 13 the period of extended operation.
14 And then obviously we'll be in that situation 15 right around 2020 time frame. So again, we have a 16 strong corporate commitment to nuclear, and we're going 17 to do that.
18 So concrete management, impact the fluence, 19 looking at temperature impacts, those sorts of things, 20 and we're closely monitoring what they're doing at 21 Ginna in terms of their evaluation of the concrete 22 structures, looking at some of the challenges.
23 We're looking forward to seeing what comes 24 out of that. So the answer, the long answer is we don't 25
34 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 have a formal program for beyond 60, but we're making 1
efforts. And our view is a long view of 40 years more 2
of operation.
3 CHAIRMAN SKILLMAN: Thank you. Okay.
4 MR. SCHULTZ: Let me back up to Dennis.
5 John, you made some good comments about the physical 6
improvements that you've made to the facility. And 7
then you mentioned 2020.
8 As the Chairman has indicated, that's in the 9
future, but it's not very far away. And my reaction 10 is somewhat affected by the choice of the word initiated 11 informal OE review.
12 And Dennis you brought up the issues 13 associated here about how we would move forward with 14 the overall aging management program, all of which is 15 very important.
16 So I think you're in the right place. But 17 when you make a major improvement to facility, one of 18 the cultural aspects of that is well, we've done it.
19 We've made these improvements. And now 20 we've got license renewal, and we're all set to go. We 21 don't have to worry about these things.
22 And the cultural aspect is very important to 23 make sure that the folks are all moving forward to 24 identify what needs to be done next in terms of aging 25
35 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 management. And it is a continuous process.
1 MR. CARLIN: I appreciate your challenge, 2
Dr. Schultz, about the cultural impact. It is.
3 Having led a plant through the period of, into the 4
period of extended operation, the first BWR to do it.
5 MR. SCHULTZ: At Browns Ferry.
6 MR. CARLIN: No, at the PWR was Ginna.
7 MR. SCHULTZ: Oh, Ginna.
8 MR. CARLIN: So I was the site vice president 9
of Ginna and setting up your programs, making sure 10 they're robust and long-term, also changing the mindset 11 of people because if you entered that period of extended 12 operation, the paradigm shifts.
13 There are new tests that have to be run.
14 There's a different way of viewing things from an aging 15 management perspective, and that is a big part of what 16 we'll be doing subsequent to this meeting, is 17 continuing down that path.
18 We started a journey in 2010. But we won't 19 finish it in 2020. It will go for the life of the plant, 20 and it really does require a different way of thinking 21 about the plant on the other side of that.
22 But you've got to set that table early 23 because it is a cultural shift. You can modify 24 behaviors, but you won't change the culture unless you 25
36 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 practice it before then.
1 MR. SCHULTZ: Thank you. I appreciate you 2
putting that on the record. Thank you.
3 CHAIRMAN SKILLMAN: Thank you, John.
4 Dennis, please proceed.
5 MR. DIMOPOULOS: Okay. We're on Slide 22 6
here. So the Safety Evaluation Report contains one 7
open item. Michael Henderson is going to talk about 8
that in the next slide.
9 It contains no confirmatory items and 10 contains two license conditions, and there are the 11 standard license conditions. One is to include the 12 FSAR supplement in the next update.
13 And the next one is to ensure implement our 14 new programs and enhancements six months prior to PEO.
15 So with that, I'd like to turn it over to Michael 16 Henderson who will talk about the SER open item.
17 MR. HENDERSON: Okay. Thanks, Dennis.
18 Good afternoon. I'm Michael Henderson, engineering 19 programs manager. As we've discussed, we do have one 20 open item in our safety evaluation report.
21 And that open item deals with the reactor 22 vessel internals program and specifically deals with 23 neutron fluence at the upper core plate.
24 So if we can jump to the next slide, we'll 25
37 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 kind of orient ourselves with the component we're 1
talking about.
2 The figure on the left is just the overall 3
schematic of our reactor vessel, and the upper core 4
plate is located just above the fuel region. It's 5
about a foot above the fuel.
6 And the figure on the right, it's just a 7
cutaway of the figure on the left. And the upper core 8
plate is in a red box there, so that's the component 9
we're talking about.
10 CHAIRMAN SKILLMAN: These are two different 11 reactor vessels, or those are not the same internal.
12 MR. HENDERSON: They're pictures taken from 13 two different locations. The one on the right is 14 supposed to be taking some of the objects out so you 15 can see the upper core plate.
16 But yes, all the components are not there.
17 They're not the same in the two figures, but the only 18 intent is to show location.
19 CHAIRMAN SKILLMAN: I understand the 20 cartoon, but I'm making the point what you have on the 21 left is an upper plenum. It's clamped by the head with 22 a lower bridge arrangement.
23 What you have on the right might be the same, 24 but that is a fundamentally different structural 25
38 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 member. I don't know if you can see it. I can see it.
1 MR. HENDERSON: Okay. The only intent was 2
to show --
3 CHAIRMAN SKILLMAN: Those are cartoons, 4
okay.
5 MR. HENDERSON: Yes, sir.
6 CHAIRMAN SKILLMAN: And the real point is 7
the upper core plate is that lower red member that 8
you're pointing to?
9 MR. HENDERSON: Correct.
10 CHAIRMAN SKILLMAN: Okay.
11 MR. HENDERSON: So going back to the 12 previous slide, we'll step through the open item 13 itself. So we received this RAI in September. We 14 responded on October 22nd, and that response is in 15 review.
16 The RAI really had two issues. The first was 17 to describe the fluence methodology that was used to 18 calculate the fluence at the upper core plate, and the 19 answer to that was pretty straightforward.
20 We used the same methodology that we've 21 always used. It's consistent with the reg guide, and 22 it's consistent with staff-approved methods that our 23 NSSS vendors use.
24 The second part of that RAI was really our 25
39 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 open item is the fact that the value we calculated for 1
the underside of the upper core plate is above a 2
threshold for a radiation embrittlement.
3 So the underside, obviously closer to the 4
fuel, more fluence. Now with that being said, being 5
above that threshold doesn't change the overall 6
categorization of the upper core plate.
7 It remains an expansion item with respect to 8
MRP guidance, and the reason for that is that it's still 9
not a leading indicator of any degradation within the 10 reactor vessel.
11 So with that being said, what Sequoyah has 12 done and what we are committing to doing is enhancing 13 our VT3 visual exam procedures so that when we do our 14 Section 11 inside the vessel visual exams, we'll take 15 a look at the underside of that upper core plate with 16 a VT3.
17 CHAIRMAN SKILLMAN: How do you do that?
18 MR. HENDERSON: Excuse me?
19 CHAIRMAN SKILLMAN: How do you do that?
20 That upper core plate is resting on the springs of the 21 fuel assemblers. It's clamped in place.
22 The head pushes it down, pushes the assembly 23 in place. The only way to see that is to pull that 24 plenum out and to view it from outside.
25
40 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR. HENDERSON: That would be the way to do 1
it, yes. It would only be when it's removed.
2 CHAIRMAN SKILLMAN: Okay.
3 MR. HENDERSON: It's not intended to be an 4
every outage type of commitment.
5 CHAIRMAN SKILLMAN: What does the program 6
require?
7 MR.
HENDERSON:
The ISI in-service 8
inspection program --
9 CHAIRMAN SKILLMAN: You're committing to a 10 visual for this particular open item. What is the 11 program that you are committing to?
12 MR. HENDERSON: As far as reactor vessel 13 internals, MRP 227. There are no requirements other 14 than an expansion item for this component. It would 15 only be examined if we found degradation elsewhere. So 16 this is more than what the MRP would require for this 17 item.
18 MR. SCHULTZ: What is the examination going 19 to look for?
20 MR. HENDERSON: The VT3 would be looking for 21 mechanical deformation, any sort of gross degradation 22 that may be present that could potentially serve as a 23 crack initiator. It will obviously not be looking for 24 cracking.
25
41 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MEMBER BALLINGER: That concerns me a little 1
bit because if you're concerned about IASCC, which is 2
what the issue is, you can get, you don't have to see 3
distortion and stuff like that to have cracks.
4 I mean if you're looking for distortion or 5
whatever as a precursor or an indicator that you may 6
have cracks, that's not going to be enough. I mean you 7
can get cracks long before you get anything like that.
8 MR. HENDERSON: I'd like Randy Lott from our 9
NSSS vendor.
10 MR. LOTT: Hi. I'm Randy Lott. I'm from 11 Westinghouse, and we helped put together both this 12 response and the response to that triple core plate.
13 The answer to your question is there are 14 actually no cracking mechanisms that were screened in.
15 The threshold for radiation embrittlement is somewhat 16 lower than the threshold for IASCC within our screening 17 process.
18 So there was no fatigue. There was no IASCC 19 or SCC concern identified in the upper core plant.
20 There was in radiation embrittlement requirement.
21 MEMBER BALLINGER: So it's a toughness 22 issue?
23 MR. LOTT: So it's really, yes. So it's 24 really more a matter of how large a crack can you 25
42 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 tolerate or when you get to the actual slot analysis.
1 But in terms of what to inspect for, I agree 2
with you. We're inspecting only in an abundance of 3
caution to make sure that we're able to withstand any 4
loss of toughness in the material.
5 MEMBER BALLINGER: So how does the 6
inspection verify that?
7 MR. LOTT: Well, the inspection is just 8
verifying that there's not a flaw that would challenge 9
the toughness of the material.
10 MR. SCHULTZ: So what type of inspection are 11 you going to do --
12 (Simultaneous speaking) 13 MR. LOTT: The recommendation for that was 14 a VT3S. The upper internals are pulled out. That's 15 basically, as you said, that's the unit face to the 16 fuel. So to get to the fuel, that's got to come out.
17 It's either got to be examined in transition 18 or as it's sitting on the stand during the rest of the 19 exam. It's just simply a visual examination.
20 We believe because barely, the evaluation 21 we've gone through says that the threshold, the bottom 22 surface of this component might exceed the threshold 23 for a irradiation embrittlement.
24 But the other surface would be pulled, would 25
43 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 not have enough radiation to be embrittled. We do a 1
scan, basically 1 DPA standard.
2 MEMBER BALLINGER: Yes, that's what I was 3
just going to say. It's the 1 DPA standard.
4 MR. LOTT: Yes, that's basically, in fact 5
it's 1.5 DPA for the things other than casting. But 6
it's below that. That's what the screening criteria 7
basically told us was it's below that 1 DPA level at 8
the top surface.
9 So we're not worried about the things above 10 it. That's a part of our concern.
11 CHAIRMAN SKILLMAN: So Dr. Ballinger, you 12 good?
13 MEMBER BALLINGER: Yes.
14 CHAIRMAN SKILLMAN: Okay, Dennis, you can 15 proceed. Excuse me, Mike.
16 MR. HENDERSON: I'll give it back to Dennis 17 for some concluding remarks.
18 MR. DIMOPOULOS: We're on Slide 26. So in 19 conclusion, the Sequoyah license renewal application 20 has followed the latest revision of the NUREG, the 21 latest revision of the GALL, with the only exception 22 such that it with the fire water system.
23 In all there are 44 commitments that we're 24 going to use to improve the aging management program 25
44 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 and the operating experience program that was 1
previously discussed.
2 During our application, the Sequoyah aging 3
management program owners and subject matter experts 4
have been involved with the development of the 5
application, the technical reports, the walk downs, 6
inspections, RAI responses and commitment development.
7 The programs and program enhancements are 8
defined for managing aging effects for Sequoyah for the 9
period of standard operation.
10 As John and Paul and William have discussed, 11 we made some significant investments to the plant 12 modifications over the years for the continuing safe, 13 reliable operation through the extended period of 14 operation.
15 So with that, we'll move on to questions and 16 comments.
17 MEMBER POWERS: It's always a curious 18 subject and interest to me. You made about a 40 percent 19 increase in the workload for aging management. How do 20 you do that? Go to the aging manager, and tell him 21 you're screwing up his weekends.
22 MR. SIMMONS: I would.
23 MEMBER POWERS: Me, too.
24 (Simultaneous speaking) 25
45 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR. SIMMONS: So as I understand your 1
question, Mr. Powers, is the workload associated with 2
the aging management, how are we prepared to deal with 3
that?
4 MEMBER POWERS: Yes.
5 MR. SIMMONS: So we have a very strong 6
management program at Sequoyah that integrates the 7
aging management process into those aspects of how 8
we're going about doing our preventative maintenance, 9
the other corrective actions, work activities that we 10 need to have.
11 One of the things that John and I do on a very 12 frequent basis is review our current stacking against 13 the work that we have, and we make adjustments as 14 required to accommodate for those needs based on the 15 workload that we have and we project that we'll have 16 over the next one to three years for that.
17 MEMBER POWERS: I've got to give you credit.
18 I ask this question pretty routinely of people, and 19 that's the best answer I've gotten.
20 I mean that's the right thing. You need more 21 people, you need more people. But that doesn't mean 22 that it's not proportional to the increase in workload 23 necessarily.
24 It may be more. It may be less. It depends 25
46 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 on what the nature of the job is.
1 CHAIRMAN SKILLMAN: I got a question, CRD 2
and nozzle wear. Got some interesting information in 3
the SER on this topic. Let me just read two sections 4
and then ask you to please respond.
5 In addition, the applicant stated that the 6
amount of wear, excuse me, this is from the status 7
report. No, it's the safety evaluation.
8 The applicant stated that with the amount of 9
wear, the remaining wall thickness of the CRD and 10 nozzles is sufficient to perform as designed function.
11 The applicant stated that all of the stress 12 intensity and fatigue usage factor limits used in the 13 design of the Unit 1, Unit 2 CRD and nozzles as specified 14 in the applicable ASME code editions remain satisfied 15 with the incorporation of the reduced CRD and nozzle 16 thickness.
17 The question is how has that thickness been 18 verified.
19 MR. PIERCE: Mr. Chairman, I'm going to ask 20 Mr. Adam Keyser to speak to your question.
21 CHAIRMAN SKILLMAN: Yes, sir. Thank you.
22 MR. KEYSER: Good afternoon. My name is 23 Adam Keyser. I'm the ASME Section 11 Program Manager.
24 This past outage on Unit 2 at Sequoyah back in the 25
47 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 spring, we were able to use our vendor and their NDE 1
techniques to take UT thickness measurements in those 2
locations.
3 CHAIRMAN SKILLMAN: Yes, sir. Thank you.
4 Let me ask one more, I think, if you want to stand by.
5 In response to thermal nozzles not located in the outer 6
two most concentric rows so on and so forth, the 7
applicant stated this inspection did not identify any 8
cracking with the thermal sleeves.
9 And Nozzles 20, 39, 40, 45, 47, 51, 53, 57 10 were noted as having the most wear. The applicant 11 further stated that the maximum wear was identified on 12 CRDM thermal sleeve Nozzle 20.
13 Here comes my question. In addition, the 14 applicant stated that its engineering evaluation 15 included a comparison of the observed wear of Unit 1 16 Nozzle 20 with the wear observed at another facility.
17 The applicant stated that the observed wear 18 of Nozzle 20 was less than the wear at the other 19 facility. And on this basis, the most significant 20 measured wear at the other facility was conservatively 21 used to evaluate the remaining service life of the 22 applicant's thermal sleeves.
23 I read that several times, and I said that 24 is an interesting way to do an evaluation. You find 25
48 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 somebody else who's worse than you, and you claim that 1
as the worst. And you march on. How is that 2
justified?
3 MR. KEYSER: The easy answer to that 4
question is since the time that examination was 5
performed, we have actually taken physical thickness 6
measurements.
7 The initial findings associated with the 8
technical bulletin were based on visual examination 9
results, and we didn't have a tool capable of physically 10 measuring the wear in this location.
11 So we utilized photographs taken during the 12 J-groove weld examinations performed at our plant and 13 compared them against photographs taken during the same 14 exam performed by the same vendor at the comparison 15 plant.
16 And at the time, that was the best data we 17 had to go on. Since then we have performed UT thickness 18 measurements.
19 CHAIRMAN SKILLMAN: Thank you.
20 MEMBER BALLINGER: I have another question.
21 Reading through the SER, the section on materials, 22 there were a number of cases where you thought one 23 material was there, but it was a different material when 24 you actually looked at it.
25
49 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 Are you sure that you have a direct 1
correlation? You know what materials you actually 2
have of the core structural materials, because that was 3
the issue between cast and rot materials in a number 4
of places. So you're sure now of the materials that 5
are present?
6 MR. SIMMONS: Mr. Ballinger, I'm going to 7
request that Mr. Chris Webb speak to your question.
8 MR. WEBB: Hi. I'm Chris Webb with 9
engineering programs. I understand you're asking 10 about the reactor vessel internals components --
11 MEMBER BALLINGER: Right.
12 MR. WEBB: -- that were originally 13 identified as rot --
14 (Simultaneous speaking) 15 MR. WEBB: Based on a review of CMTRs we 16 conservatively assume that they were cast also mixed 17 in with steel. We could not verify that they were one 18 or the other, so we conservatively assumed that they 19 were.
20 And that started with the CRGT byparts. And 21 we've since identified three other components and also 22 from that category, and that's the final number.
23 MEMBER BALLINGER: Okay. So when you make 24 the substance that's cast, that means you get earlier 25
50 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 embrittlement or aging.
1 MR. WEBB: Correct.
2 MEMBER BALLINGER: And so you factor that 3
in, okay. So where you couldn't determine, you've 4
assumed the worst case?
5 MR. WEBB: Correct.
6 CHAIRMAN SKILLMAN: Ron, thank you.
7 MR. SCHULTZ: I have a couple of questions.
8 CHAIRMAN SKILLMAN: Steve.
9 MR. SCHULTZ: First for you Mike, the 10 question I have is, and you may have covered this, and 11 I might have missed it, you talked about the inspection 12 program related to the open item.
13 But what is the earliest commitment date for 14 that inspection, and is it going to be a continuing 15 process? You said well, we don't have to do this all 16 the time. But is there a program plan that will 17 reevaluate, reinspect during the extension period?
18 MR. HENDERSON: You're referring to the VT3 19 exam --
20 MR. SCHULTZ: Yes.
21 MR. HENDERSON: -- that we will be doing.
22 MR. SCHULTZ: When is it going to be done?
23 MR. HENDERSON: It's going to be consistent 24 with the ten year ISI schedule.
25
51 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR. SCHULTZ: Okay.
1 MR. HENDERSON: So it'll be on that same 2
frequency.
3 MR. SCHULTZ: And when will that happen 4
first?
5 MR. HENDERSON: I don't have the exact date, 6
but I can get you the date when it'll happen first.
7 MR. SCHULTZ: Okay. Thank you. I 8
appreciate it.
9 MEMBER BALLINGER: I guess I have another 10 sort of companion question. That's a complicated 11 structure, a lot of holes and all kinds of things.
12 Are you sure that the VT3 would find what 13 you're looking for? It's not a flat plate that's easy 14 to get access to. It's a complex part, so have you done 15 anything to verify that the VT3 would actually work?
16 MR. HENDERSON: To this point, no. Again, 17 the VT3 would be above what's required by the MRP. It's 18 still an expansion item in the MRP document.
19 MR. SCHULTZ: And my other question is for 20 you, Erin. You mentioned in your presentation, and we 21 learned it was in 2012 that you had the industry peer 22 review done.
23 And it was also mentioned that there were 300 24 open items, 300 items that were identified, and I 25
52 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 presume they became open items in some list.
1 Were all of those elements, items closed 2
before the submittal, or how have those items been 3
tracked as you've gone forward with the application and 4
then with the subsequent interaction with the staff, 5
the industried items.
6 MS. HENDERSON: Dennis Lundy will talk a 7
little bit about that.
8 MR. LUNDY: My name is Dennis Lundy with the 9
license renewal project. Each one of those open items 10 were tracked in a database with an assigned owner.
11 Entergy, our primary contractor, put the 12 database together. Each individual question had a 13 defined answer that TVA reviewed and concurred with.
14 So they were tracked to closure. They were all closed 15 before it was submitted.
16 MR. SCHULTZ: Thank you.
17 MEMBER STETKAR: I apologize for coming in 18 late, so I hope, I don't think any of this was covered 19 beforehand. Somebody talk to me about underground 20 cables. So get your appropriate person ready.
21 Sequoyah's had a long history of problems 22 with water accumulation underground, buried in 23 underground, I'm going to need both of those because 24 I'm not quite sure what configurations you have, both 25
53 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 actual functional failures and cables and degraded 1
cables identified by testing.
2 As I read through the RAI responses and the 3
SER, first of all, because my last data comes from the 4
generic letter 2007 of one response. The last failure 5
I know about was in 2005.
6 What's your operating experience been from 7
2005 through 2014 in terms of underground cables? Have 8
you had any additional failures?
9 MR. DIMOPOULOS: Mr. Stetkar, I'm going to 10 ask Darren Boehm from our electrical design 11 organization answer that.
12 MR. BOEHM: Yes, my name is Darren Boehm from 13 site engineering. You were asking about failures post 14 the response to the generic letter 2007.
15 MEMBER STETKAR: That's the first question, 16 yes.
17 MR. BOEHM: We have had a test failure on a 18 diesel generator cable feed. I can get the exact date 19 on that.
20 MEMBER STETKAR: That date, I don't care.
21 MR. BOEHM: And we've also had one more 22 failure on a cooling tire lip pump cable. I think that 23 was approximately 2011.
24 MEMBER STETKAR: It was found by, how'd you 25
54 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 find it, water draining?
1 MR. BOEHM: That was a VLF test, very low 2
frequency.
3 MEMBER STETKAR: Water draining or the --
4 MR. BOEHM: We did not send that test away 5
for sampling, but we were seeing the indication of a 6
strong voltage dependence.
7 MEMBER STETKAR: Okay. In at least the SER 8
it notes that you'd had problems with, it identifies 9
Manhole 31, wherever that is.
10 And you were going to complete some regrading 11 of the surface to try to get, reduce the amount of water 12 intrusive of that manhole.
13 It was supposed to be completed by the end 14 of September of this year. Did you finish it?
15 MR. BOEHM: Yes, we have.
16 MEMBER STETKAR: Good, excellent. You've 17 also had problems, apparently, with sump pumps not 18 working and piping problems with the sump pumps. And 19 I guess you're on track for September of next year to 20 get those corrected. How are you doing there?
21 MR. BOEHM: I believe we have resolved that 22 commitment with preparing all of these acceptable sump 23 pumps and discharge pipe, safety-related manholes.
24 MEMBER STETKAR: When was your last 25
55 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 inspection to look for water accumulation?
1 MR. BOEHM: It's past on a four week PM. I 2
do not have the most recent, but as of September all 3
of our safety-related manholes were at acceptable 4
levels except for one, which is still documented in our 5
corrective action program.
6 We're still trying to resolve the issues with 7
that. That was in the scope of, we have gone into that 8
manhole, and apparently we didn't resolve the issue 9
fully. It's still in process to repair that one 10 remaining manhole.
11 MEMBER STETKAR: I came on the committee in 12 2007. We were talking about this issue in 2007. It's 13 seven years, not at Sequoyah but the industry in general 14 has been, it's just surprising that we're still talking 15 about it to this extent where you still have problems 16 in late 2014. I'll just make that as a comment.
17 MR. SIMMONS: Mr. Stetkar, I will comment on 18 that. Our standard at Sequoyah is we don't want any 19 water in our manholes, and that's what we're driving 20 to.
21 And we have put forth a lot of effort over 22 the last couple of years in regrading areas of our plant 23 to improve our drainage.
24 As Mr. Boehm spoke to, we have repaired, 25
56 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 replaced numerous sump pumps and addressed piping 1
issues. We do have one issue that he spoke to that 2
we're not satisfied with the current inspections that 3
we were seeing.
4 And we are taking action with our maintenance 5
organization to go and resolve that. And we're not 6
going to accept that for our plant.
7 MEMBER STETKAR: Yes, I understand the 8
commitments that you've made in terms of license 9
renewal. You're committing to all of the things in 10 GALL rev 2.
11 So I get that. I'm just trying to understand 12 where you are, where you've been in the past, where you 13 are now and develop some sort of confidence going 14 forward.
15 MR. CARLIN: Going back to Dr. Schultz's 16 comment, this is one of those, and the question was 17 posed by Mr. Skillman, we're committed to the long haul 18 on this.
19 And this isn't, so we need to fully resolve 20 this issue. We've had, we fully and readily admit that 21 we have not been good stewards at different times of 22 that.
23 We have invested millions of dollars to 24 ensure that degrading, that our drainage systems are 25
57 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 fully functional.
1 And we have made modifications to our cable 2
bolts to ensure that we can access them and quickly pump 3
any water that's discovered in them if we have sump pump 4
failures or something like that and also provide better 5
capability in terms of determining the level in those 6
at any time.
7 So we're continuing to invest, but it's set 8
up for the long haul. This is not just, you know, we're 9
just worrying about getting the sump pumps replaced and 10 saying okay, we've got a checkmark in a box. That 11 wasn't how we were going to approach this at all.
12 MEMBER STETKAR: And did I hear, you said 13 it's on a four week PM? You're --
14 (Simultaneous speaking) 15 MR. CARLIN: You're absolutely correct.
16 We're going to aggressive stewards going forward.
17 MEMBER STETKAR: Thank you.
18 CHAIRMAN SKILLMAN: Dr. Riccardella has 19 joined us. Pete, welcome. Colleagues, Dr. Ryan, any 20 questions for the TVA team?
21 MEMBER RAY: No.
22 CHAIRMAN SKILLMAN: Dr. Powers?
23 MEMBER POWERS: No.
24 CHAIRMAN SKILLMAN: Harold?
25
58 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MEMBER RAY: No.
1 CHAIRMAN SKILLMAN: John, any further 2
comments?
3 MEMBER STETKAR: No.
4 CHAIRMAN SKILLMAN: Steve?
5 MR. SCHULTZ: No.
6 CHAIRMAN SKILLMAN: TVA team, thank you very 7
much. What we're going to do is take a 15 minute break, 8
and then we're going to call the NRC staff to the table.
9 (Whereupon, the above-entitled matter 10 went off the record at 2:24 p.m. and resumed at 2:41 11 p.m.)
12 CHAIRMAN SKILLMAN: Ladies and gentlemen, 13 we are back in session, and before we begin the NRC 14 presentation, I'm going to call upon Allen Henderson, 15 I'm sorry, Michael Henderson to speak into the record 16 the issue of the plan for inspection for the upper core 17 plate, please.
18 MR. HENDERSON: The question was when is the 19 next ten year ISI for Sequoyah Unit 1 and Unit 2. That 20 next ten year ISI is in 2015, and we plan to do that 21 inspection at that time.
22 CHAIRMAN SKILLMAN: Thank you.
23 MR. HENDERSON: Thank you.
24 CHAIRMAN SKILLMAN: With that, I'm going to 25
59 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 call on Manny Sayoc of the NRC staff to take the meeting 1
from here, please. Manny, go ahead.
2 MR. SAYOC: Good afternoon, Chairman 3
skillman and members of the license renewal 4
subcommittee. My name is Emmanuel Sayoc, and I am --
5 MALE PARTICIPANT: Chris wants to make sure 6
7 MR. SAYOC: Chris, I'm sorry.
8 CHAIRMAN SKILLMAN: We are now calling upon 9
10 (Off record comments) 11 CHAIRMAN SKILLMAN: We're going to call upon 12 Chris Miller to make some opening comments.
13 MR. MILLER: Thank you, Chairman. We are 14 pleased to be presenting before you. A lot of work went 15 into this application review. What we hope to cover 16 this afternoon is the staff's review.
17 As I said earlier, the SER with open items 18 was issued September 20, 2014, transmitted via memo to 19 the ACRS on October 9th. I want to introduce Mr. Manny 20 Sayoc who's our technical lead PM for the safety side 21 of the review.
22 He is also joined by Lindsay Robinson who is 23 also our project manager on safety and Dr. Allen Hiser.
24 And behind me, if they would stand up, a lot of people 25
60 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 who worked on this and did a lot of work.
1 And they're supporting us today, so I just 2
want to let you know who's here. Thank you, and I'll 3
turn it over to Manny.
4 MR. SAYOC: Thank you, Chris. I didn't mean 5
to steal your thunder. Okay, so good afternoon 6
Chairman Skillman and members of the license renewal 7
subcommittee.
8 My name is Emmanuel Sayoc, and I'm the 9
license renewal project manager for the Sequoyah 10 Nuclear Power Plant Units 1 and 2, ISS renewal safety 11 review.
12 We are here today to discuss the review of 13 the Sequoyah license renewal application as documented 14 in the safety evaluation report with open items, which 15 we issued on September 29, 2014.
16 Joining me here at the table, as you said, 17 is Dr. Allen Hiser. He's a technical advisor for the 18 division of license renewal, and Ms. Lindsay Robinson, 19 visual license renewal safety project manager, who will 20 be running the slides.
21 Seated in the audience are members of the 22 technical staff who have participated in a review of 23 the license renewal application and/or worked parts of 24 the audits conducted at the point.
25
61 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 Mr.
Joel Rivera-Ortiz is our senior 1
inspector at Region II and is joining us via telephone.
2 Next slide.
3 Today we'll present a general overview of the 4
staff's review and then discuss the main sections and 5
issues presented in the staff safety evaluation report 6
as shown here.
7 Joel will present the results from the Region 8
II onsite inspection. Next slide. The staff 9
conducted several outside audits and inspections for 10 the application as shown on this slide.
11 During the scoping and screening methodology 12
- audit, the audit team reviewed applicant's 13 administrative controls governing the scoping and 14 screening methodology and the technical basis for 15 selected scoping and screening results.
16 The staff also reviewed selected examples of 17 component material environmental combinations, 18 information contained in applicant's corrective action 19 relevant to the plant-specific age related degradation 20 and reviewed quality practices applied during 21 development of the LRA and the training of personnel 22 who participated in the review of the LRA.
23 During the aging management program audit, 24 a team of over 35 reviewers examined Tennessee Valley 25
62 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 Authority or TVA's aging management programs and 1
related documentation to verify applicant's claims of 2
consistency with the corresponding AMPs in the GALL 3
report.
4 The staff will use AMPs and documented the 5
results in the report dated June 12, 2014. Next slide.
6 Region II conducted its regional inspection 7
as shown a slide Joel will be presenting. We'll 8
present the inspection results shortly.
9 In addition to the audits and inspections 10 already mentioned, the staff conducted in depth 11 technical reviews and issued requests for additional 12 information or RAIs.
13 The staff completed its initial review of the 14 safety Sequoyah license renewal application with the 15 exception of one open item and issued in a safety 16 evaluation report with open items on September 29, 17 2014.
18 The staff will continue to review the open 19 item and associated outstanding RAI. Our plan is to 20 issue Sequoyah's final SER in January 2015. Now I'll 21 turn the presentation over to Joel of Region II.
22 MR. SCHULTZ: Manny, before you leave that, 23 I wanted to make sure. It looks like you had the Region 24 II inspection, and I just wanted to understand in those 25
63 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 inspections what was the participation?
1 That is, you have the Unit 1 containment 2
walkdown. That was just Unit 2, excuse me, Region II 3
personnel that participated in that? You have a team 4
inspection listed after that.
5 Any headquarters' staff participate in 6
either of those?
7 MR. SAYOC: Yes, sir. Mr. Schultz, thank 8
you for the question. For Region II, that was 9
primarily region personnel. Headquarters' staff 10 participated in any scoping and screening audit and the 11 aging management program audit.
12 MR. SCHULTZ: Okay. So that team 13 inspection was handled by Region II?
14 MR. SAYOC: Yes, sir.
15 MR. SCHULTZ: Thank you.
16 MR. SAYOC: Okay. I think we were about to 17 call Joel on the line here to go over the Region II 18 inspections. Joel.
19 MR. RIVERA-ORTIZ: Thank you, Manny. Good 20 afternoon, Chairman Skillman and members of the 21 subcommittee. We are on Slide Number 5 of the 22 presentation.
23 My name is Joel Rivera. I'm a senior reactor 24 inspector in Region II and a team leader for the license 25
64 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 general inspection of Sequoyah. This inspection was 1
conducted last year in accordance with NRC inspection 2
procedure 710002.
3 We completed an inspection in two places, and 4
to clarify the previous question asked about the 5
composition of the teams.
6 We conducted a walkdown of the Unit 1 7
containment performed by Region II inspection staff 8
including the October 2013 refueling outage because 9
that was the only opportunity available around that 10 time to inspect the containment because they were on 11 refueling outage.
12 And after the outage was completed, we 13 conducted a team inspection in November of 2013. The 14 team consisted of five inspectors from Region II and 15 one materials engineer from NRR.
16 So to answer the previous question, there was 17 one member from NRR participating in the inspection.
18 The team conducting inspection activities in the three 19 specific areas shown on the slides as directed by the 20 inspection procedure.
21 For the inspection of scoping and screening 22 methodology, the teams selected the essential raw 23 cooling water system to verify on a sampling basis that 24 the system was scoped and the applicable aging 25
65 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 management reviews were performed in accordance with 1
Part 54.
2 The team also interviewed plant personnel 3
and conducted walkdowns on portions of the system to 4
verify that scoping and screening results were 5
consistent with the application.
6 For the inspection of aging management 7
programs, the teams selected all programs described in 8
the application. The team interviewed plant 9
personnel, reviewed program implementing procedures 10 and samples of inspection, testing and surveillance 11 results to assess the implementation of existing 12 programs.
13 Additionally, the team conducted walkdowns 14 of plant areas to assess of existing programs, based 15 on the current material conditions and verify that 16 applicable aging effects had been accurately 17 identified in the application.
18 The team discussed with the applicant their 19 planned activities to enhance and develop new programs 20 and the evaluation of industry operating experience 21 used to prepare the application.
22 And last, for the review of updates to the 23 application and open items, the team discussed with the 24 applicant any potential material changes to the 25
66 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 application, such as planned modifications or changes 1
to the current licensing basis, verify that the 2
applicant was planning to revise the application in 3
accordance with Part 51.
4 Prior to a team inspection, the team 5
consulted with NRR to identify any items of interest 6
that require further inspection. And last, the team 7
verified that official administrative controls were in 8
place to ensure that commitment tasks were being 9
tracked to completion prior to the period of extended 10 operation. Next slide, please.
11 Part of the conclusions of the inspection, 12 on the basis of the sample selected for review, the team 13 concluded that the applicant performed aging 14 management reviews in accordance with Part 54.
15 Based on the sample of plant areas visually 16 inspected and the review of program documents, the team 17 concluded that the existing programs were being 18 effective in managing aging effects for plant 19 structures and equipment within the scope of license 20 renewal.
21 The plant walkdowns show that structures, 22 systems and components were being maintained in good 23 condition and aging effects were being identified, 24 monitored and corrected to maintain the system 25
67 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 functions.
1 The team confirmed that the applicant had 2
plans to implement the enhancements described in the 3
applications and develop new aging management programs 4
in accordance with the applications and the 5
commitments.
6 Additionally, the team confirmed that the 7
information used to prepare the application was 8
retrievable, auditable and consistent with Part 54.
9 The team finally determined that the 10 proposed aging management programs, when implemented 11 in accordance with the application, the regulatory 12 commitment and applicable quality assurance measures 13 will provide regional assurance that the aging facts 14 will be managed to maintain the function of applicable 15 structures, system and components. That concludes my 16 part of the presentation.
17 CHAIRMAN SKILLMAN: Joel, this is Dick 18 Skillman. I have one question I would like to ask, 19 please. Can you hear me?
20 MR. RIVERA-ORTIZ: Yes, I can hear you 21 clearly.
22 CHAIRMAN SKILLMAN: I would like to know the 23 basis upon which you would conclude that inspecting 24 just the essential raw cooling water system is 25
68 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 sufficient.
1 I'm going to guess that Sequoyah's got 200 2
and some systems of those. There are probably 35 or 3
40 that are critical systems. You've chosen just one 4
of the critical systems, and I'm curious why one is 5
sufficient, please.
6 MR. RIVERA-ORTIZ: Okay. Well, we selected 7
the, when we are putting inspection plans together we 8
wanted to select a comprehensive, a large system that 9
covers multiple areas of the plant and interfaces with 10 multiple components.
11 And that's why we selected the essential raw 12 cooling water system. In addition to that, we wanted 13 to use risk insights to select a system that was 14 significant in risk for plant safety.
15 And we used that. We believe that the 16 essential raw cooling water was a good sample, 17 representative of the methodology that the licensee 18 used for similar systems for system insight.
19 CHAIRMAN SKILLMAN: Thank you, Joel. I 20 appreciate the answer. Thank you.
21 MR. SCHULTZ: Joel, this is Steve Schultz.
22 Thank you for your presentation. Two questions, both 23 related. You did the walkdown of the containment for 24 Unit 1 during the refueling outage in 2013 and then had 25
69 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 a subsequent inspection of November.
1 I presume that the team inspection looked at 2
both units.
3 MR. RIVERA-ORTIZ: Yes, that's correct.
4 The scope of inspection, the team inspection in 5
November was a programmatic, was a review of the 6
programs. And we look at both units.
7 MR. SCHULTZ: Okay. And was there anything 8
identified in the containment walkdown for Unit 1 that 9
would suggest that you would like to perform a similar 10 walkdown for Unit 2 in the upcoming outage?
11 MR. RIVERA-ORTIZ: At the time of that 12 walkdown, I don't recollect of any significant issues 13 that require a walkdown in the other unit.
14 In addition to that, we routinely walkdown 15 the containment during the baseline inspection program 16 that we implement.
17 MR. SCHULTZ: Right.
18 MR. RIVERA-ORTIZ: So at that time we didn't 19 identify any significant in regions that required a 20 similar walkdown in the Unit 2.
21 MR. SCHULTZ: And you had the ability 22 matched up with the traditional walkdowns that you do 23 during outages.
24 MR. RIVERA-ORTIZ: Yes.
25
70 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR. SCHULTZ: Thank you.
1 CHAIRMAN SKILLMAN: Joel, Dick Skillman, I 2
have one more question, please. You mentioned that as 3
you were preparing for this inspection, you asked 4
headquarters if there were any areas that headquarters 5
would like you to inspect.
6 MR. RIVERA-ORTIZ: That's correct.
7 CHAIRMAN SKILLMAN: What were those areas, 8
please?
9 MR. RIVERA-ORTIZ: It was one particular 10 item that the NRR asked us to take a second look at.
11 And there was an indication on a concrete wall in the 12 turbine building that the technical reviewers wanted 13 the region's opinion on the licensee's actions to 14 manage aging of that turbine building wall.
15 CHAIRMAN SKILLMAN: And what did you find in 16 that inspection, please?
17 MR. RIVERA-ORTIZ: The assessment of one of 18 the civil engineers in the group was that the condition 19 had been identified and been monitored and it did not 20 impact the structural integrity of the wall in the 21 turbine building.
22 And licensee had been monitoring the 23 condition, and in addition to that, had been well 24 capturing the request for additional information from 25
71 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 the staff.
1 And my understanding is that the licensee has 2
a specific commitment to take additional actions prior 3
to pure start up operation to address that condition.
4 CHAIRMAN SKILLMAN: Thank you, Joel. Thank 5
you.
6 MR. RIVERA-ORTIZ: You're welcome.
7 MEMBER STETKAR: Joel, this is John Stetkar.
8 I had to keep you on the hook here, but it's the price 9
you pay. You guys walked down the ERCW system, right?
10 MR. RIVERA-ORTIZ: That's correct.
11 MEMBER STETKAR: And I noticed the buried 12 and underground piping and tanks inspection program is 13 characterized as a new program for Sequoyah.
14 And as is sometimes the case on these new 15 program, when they look at operating experience they 16 say well, this is a new program. We don't have the 17 operating experience that's relevant to a new program.
18 Well, okay, but the plant has been operating 19 now for quite some number of years. What was the 20 condition, and I don't know the configuration? Could 21 you actually look at, is there ERCW piping, is it 22 underground, or is buried?
23 MR. RIVERA-ORTIZ: For this, the --
24 MEMBER STETKAR: Both?
25
72 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR. RIVERA-ORTIZ: -- good expand of the 1
piping is buried.
2 MEMBER STETKAR: Is buried, below? Do you 3
know if they had any, did you come across when you were 4
there at the site any experience of leakage of problems 5
with that piping?
6 MR. RIVERA-ORTIZ: No, the result of the 7
walkdown identified that at least the accessible 8
conditions were well maintained. There was no 9
observable leakage from the components.
10 We did a walkdown from ERCW, essential raw 11 cooling water pumping station, all the way to a number 12 of heat exchangers and components. And we didn't 13 identify any active leaks in those components.
14 In our walkdown we talked to system 15 engineers. They discussed with us, he was very 16 knowledgeable, history of the system.
17 And that operating experience had been 18 captured in the operating experience review for the 19 system and the program. So to answer your question, 20 we did not see any active leakage in our walkdown of 21 the areas that we sampled.
22 MEMBER STETKAR: Good, and no evidence of 23 significant adverse operating experience when you 24 talked to the systems engineer?
25
73 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR.
RIVERA-ORTIZ:
No, that's our 1
understanding.
2 MEMBER STETKAR: Yes, great. Thank you.
3 CHAIRMAN SKILLMAN: Joel, I would be remiss 4
if I didn't convey a compliment to you and your 5
inspection team. Several of the members used your 6
inspection report as significant basis for their review 7
and found your report to be very well done, very 8
thorough and extremely helpful in preparation for this 9
engagement with the licensee. So, thank you.
10 MR. RIVERA-ORTIZ: I appreciate that 11 comment. Thank you.
12 MR. SAYOC: Okay, Emmanuel Sayoc, I'll 13 continue the presentation. Thank you, Joel. Now 14 let's move to Section 3: The Aging Management Review 15 Results.
16 Section 3.0 covers the staff's review of the 17 applicant's aging management programs. Section 3.1 to 18 3.6 covers aging management review items in each of the 19 general system areas within the scope of license 20 renewal.
21 For a given aging management review, the 22 staff reviewed the items to determine whether it was 23 consistent with the GALL report. If an aging 24 management review was not consistent with the GALL 25
74 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 report, the staff conducted a technical review to 1
ensure accuracy.
2 The one open item in the SER is related to 3
an aging management program in Section 3.0 and will be 4
discussed shortly. Next slide.
5 The applicant submitted 43 aging management 6
programs in the application, 31 of which are existing 7
and 12 of which are new. One plant-specific AMP was 8
provided.
9 All within the exception of the 10 plant-specific AMP were evaluated by the staff for 11 consistency with the GALL report.
12 On the basis of its review, the AMPs 13 evaluated against the GALL report, the staff concluded 14 that 17 were consistent, 24 were consistent with the 15 enhancements, one was consistent with enhancements and 16 exceptions and one was plant-specific.
17 Let's now cover the open item related to the 18 aging management programs. Next slide. The 19 applicant's PWR vessel internals program implements 20 the guidance provided by EPRI's material reliability 21 program, MRP 227A, entitled PWR Reactor Internal 22 Inspection and Evaluation Guideline, which is dated 23 January 9, 2012.
24 And it includes a plant's specific responses 25
75 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 to action items, conditions and limitations which were 1
identified in the staff's safety evaluation report or 2
3 Staff safety evaluation identified a number 4
of applicant/action items that each applicant's team 5
was responsible to address related to its 6
plant-specific design and operating history.
7 MRP issued EPRI letter number MRP 2013-25 8
dated October 2013 in order to provide an applicant with 9
the basis for responding to applicant's RAIs on Action 10 Item 1 and a method that could be used to determine 11 whether the technical assumptions in MRP 227 would be 12 bound for the design operations for the reactor vessel 13 internal for components at the facilities.
14 The EPRI letter MRP 2013-25 stated that if 15 an applicant's units did not maintain a minimum 16 distance of 12.2 inches between the top of the active 17 fuel and the bottom of the surface of the upper core 18 plate for a period extending two effective full power 19 years, then applicants will be required to provide 20 additional evaluations to assure applicability of MRP 21 227A to its design and operating history.
22 In its response to Action Item 1, the 23 applicant stated that neither of its units meet the MRP 24 screening criteria.
25
76 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 That applicant stated that the maximum fast 1
neutron fluence for components above the upper core 2
plate is projected to be below the screening criteria 3
for irradiation embrittlement.
4 The staff noted that MRP 227A identifies an 5
irradiation assisted stress corrosing cracking or 6
IASCC and irradiation embrittlement, or IE, as aging 7
mechanisms that could employ Westinghouse designed 8
upper core plates.
9 The staff also noted the applicant's 10 response to RAI B.1.34-9 did not provide sufficient 11 information for the staff to review the applicant's 12 plant-specific evaluation.
13 Therefore, the staff issued follow up RAI 14 B.1.34-9A requesting the applicant to provide 15 additional information. Number 1, they were requested 16 to provide a brief description of the analysis and 17 methodology used to determine that projected fluence 18 after 60 years of operation will be below the threshold 19 limit.
20 Number 2, the neutron fluence values that are 21 used as the lower bound neutron fluence threshold for 22 IE at the core plate, and Number 3, the projected 23 neutron fluence values for the upper core plates 24 through 60 years of licensed operation for both units.
25
77 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 The applicant provided the response to 1
staff's RAI following issuance of the SER with open 2
items. The staff is currently reviewing the 3
information provided and applicant's response and 4
expects to complete its review and document its 5
findings in the final SER.
6 We will present these findings in the final, 7
I'm sorry, in the ACRS full committee. Okay, next 8
slide.
9 Now moving to SER Section 4, which covers 10 time limited aging analysis or TLAA, Section 4.1 11 documents the staff's evaluation of the applicant's 12 identification of applicable TLAAs.
13 The staff evaluated applicant's basis for 14 identifying those plant-specific or generic analysis 15 that needed to be identified as TLAAs and determine that 16 TVA has provided an accurate list of TLAAs as required 17 by 10 CFR 54.21C1.
18 Section 4.2 to 4.7 documented the staff's 19 review of the applicable Sequoyah TLAAs as shown.
20 Based on its review and the information provided by the 21 applicant, the staff concluded that the TLAAs will 22 Number 1, remain valid for the period of standard 23 operation to the TLAAs have been projected to the end 24 of the period of extended operation, or Number 3, the 25
78 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 effects of aging on those intended functions will be 1
adequately managed for the period of extended operation 2
as provided by 10 CFR 54.21 CI, II and III.
3 Next slide. The staff's conclusion will be 4
provided in a final safety evaluation report at the 5
conclusion of the staff's evaluations.
6 Pending satisfactory resolution of the open 7
item, the staff will be able to determine whether the 8
requirements of 10 CFR 54.29(a) will have been met for 9
the renewal of Sequoyah's Nuclear Power Plant's Units 10 1 and 2.
11 This concludes the staff presentation, and 12 now we'll be available to answer any further questions 13 from the subcommittee.
14 CHAIRMAN SKILLMAN: Thank you, Manny.
15 Colleagues, do any of you have a question for the NRC 16 staff? Pete.
17 MEMBER RICCARDELLA: On the open item, 18 you've received their response?
19 MR. SAYOC: Yes, sir. We received a 20 response in late October. I believe it was the last 21 week of October. The staff is currently reviewing 22 those responses.
23 MEMBER RICCARDELLA: And what are the --
24 (Simultaneous speaking) 25
79 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 MR. SAYOC: I'm sorry, the question was?
1 MEMBER RICCARDELLA: The responses that 2
they submitted.
3 MR. SAYOC: I'll call on our staff member to 4
supply that information. Roger Kalikian.
5 MR. KALIKIAN: This is Roger Kalikian from 6
the NRC staff. The fluence they estimated for the 7
upper core plate, so part of the upper core plate is 8
going to have, Slide 3 about the embrittlement special 9
which was, trying to figure out --
10 MR. HISER: Page 3, Roger.
11 MR. KALIKIAN: Oh, Page 3? Yes, I'm on Page 12
- 3. I'm just, it was going to be 1.87 times 10 to the 13 21 for Unit 1 and 1.82 times 10 to the 21 for Unit 2.
14 And that would've been above.
15 MEMBER BALLINGER: It's roughly 1 DPA.
16 MR. KALIKIAN: I'm sorry, yes.
17 MEMBER BALLINGER: Roughly 1 DPA, and the 18 limit is what? I thought I heard somebody say 0.5.
19 MR. KALIKIAN: I'm sorry.
20 MEMBER BALLINGER: I thought it was one, but 21 I thought I heard somebody saying it was 0.5 DPA was 22 the threshold.
23 MR. KALIKIAN: No, 0.5 wasn't part of the 24 answer. Maybe, I have to think that it wasn't, but I 25
80 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 think for that area that was the fluence threshold.
1 MEMBER BALLINGER: Is it 1.5 DPA?
2 (Simultaneous speaking) 3 MR. LOTT: The screening criteria --
4 CHAIRMAN SKILLMAN:
Please identify 5
yourself.
6 MR. LOTT: Randy Lott, Westinghouse, the 7
screening criteria that was used in MRP 227A as far as 8
radiation embrittlement of rocks and steel was 1.5 DPA.
9 The values, I think, the question about the values of 10 what was used for casting is where the other values came 11 in.
12 MEMBER BALLINGER: I can do this. Once you 13 get a mental conversion between fluence and DPA, which 14 to me is 1 DPA, but the threshold is 1.5. So why are 15 we, it's not above the threshold.
16 MR. HISER: Actually, the 1.87 is equivalent 17 to about 1.2 or so DPA. I'm sorry, 2.5 DPA.
18 MEMBER BALLINGER: Oh, okay. So I'm off by 19 one digit. My conversion factor was not good enough.
20 MR. HISER: It's a little bit higher.
21 MEMBER BALLINGER: Okay.
22 MR. HISER: And also that was on the lower 23 surface of the upper core plate. At the top surface 24 it's a bit lower, 6.39 times 10 to the 20th, which is 25
81 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 just below 1 DPA, and then 6.22 for Unit 2.
1 MEMBER BALLINGER: Okay.
2 MEMBER RICCARDELLA: So is there an 3
evaluation that's going to be performed?
4 MR. HISER: Yes, the staff, as Manny said, 5
the staff will evaluate the response, and if we find 6
it acceptable we'll write it up in the final SER.
7 Otherwise, if we have any additional questions, we'll 8
go back to the applicant with RAIs.
9 MR. MILLER: Mr. Chairman, just as far as the 10 record goes, I'm not sure if any of that information 11 is proprietary, its fluence.
12 MALE PARTICIPANT: No, none of it is 13 proprietary.
14 MR. LOTT: Those numbers were in the 15 non-proprietary version.
16 MR. MILLER: Thank you.
17 CHAIRMAN SKILLMAN: Staff, thank you.
18 Pete, thank you. Any other questions? Again, around 19 the table. Any of the members, Thomas, Harold?
20 MEMBER RAY: No.
21 CHAIRMAN SKILLMAN: Ron?
22 MEMBER BALLINGER: No.
23 CHAIRMAN SKILLMAN: John?
24 MEMBER STETKAR: No.
25
82 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 CHAIRMAN SKILLMAN: Dr. Powers?
1 MEMBER POWERS: No.
2 CHAIRMAN SKILLMAN: Michael?
3 MEMBER RYAN: No.
4 CHAIRMAN SKILLMAN: On the bridge line, and 5
while we're waiting for the bridge line, does anyone 6
in the room have comments, please?
7 Everybody stand by. Let's make sure our 8
phone line is open, and we'll find out if there's 9
anybody out on the phone line that has comments or 10 questions.
11 OPERATOR: The line is open.
12 MEMBER STETKAR: For those of you who don't 13 participate, we'll square you away. This is one of the 14 highest technology we're ever doing.
15 CHAIRMAN SKILLMAN: If there's anyone out 16 there, could you please say something so we can confirm 17 that the line is open?
18 OPERATOR: The line is open.
19 CHAIRMAN SKILLMAN: Thank you. For those 20 who would be online, are there any questions or any 21 comments, please? I'll ask one more time. Any 22 questions or comments?
23 Hearing none, closing comments colleagues?
24 Any comments that you would have? Any questions you 25
83 NEAL R. GROSS COURT REPORTERS AND TRANSCRIBERS 1323 RHODE ISLAND AVE., N.W.
(202) 234-4433 WASHINGTON, D.C. 20005-3701 (202) 234-4433 would have? Let me first say thank you very much to 1
the NRC staff for your work, your presentation, for 2
getting us to this point.
3 Let me also thank the TVA team for all the 4
work that they have done to bring this presentation to 5
us and to give us a good briefing today. If there are 6
no more comments or questions, this meeting is 7
adjourned.
8 (Whereupon, the above-entitled matter 9
went off the record at 3:13 p.m.)
10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25
Sequoyah Nuclear Plant ACRS Subcommittee Meeting November05,2014
Agenda
- Introductions JohnCarlin
- PlantHistoryandBackground PaulSimmons
- MajorModificationsandNearTermPlantImprovements WilliamPierce
- LicenseRenewalApplicationProject ErinHenderson
- LicenseRenewalApplication Results DennisDimopoulos
- SafetyEvaluationReportOpenItem MikeHenderson
- ConcludingRemarks DennisDimopoulos SequoyahACRSSubcommittee 2
John Carlin Site Vice President
Introductions
SequoyahACRSSubcommittee 3
Representing Sequoyah Nuclear Plant
- PaulSimmons-PlantManager
- WilliamPierce-Director,SiteEngineering
- DennisDimopoulos-Manager,Engineering
- MichaelHenderson-Manager,EngineeringPrograms
- ErinHenderson-Manager,SequoyahLicensing SequoyahACRSSubcommittee 4
Personnel In Attendance ISI Programs AdamKeyser/JasonBarrick ChemistryPrograms BruceVogel ReactorVessel Programs Chris Webb/DaveLafever Fire Protection/Appendix R DavidSanders/RobertEgli EdTurner/JoyWilliams/JimGrant InaccessibleElectricalCable DarrenBoehm SteamGenerators JeremyMayo StructuresMonitoring TylerHaraway FlowAccelerated Corrosion DavidSpears Buried Piping KyleLoomis Coatings Kelli Yates Fuels Fuels/Neutron Monitoring DavidBrown InstrumentationPrograms GaryTiner Chemical Monitoring HaroldWilliams ServiceWaterProgram EdCraig OverheadHandling Brookes Bacon FatigueManagement DennisLundy LR ProjectContractor AlanCox/RezaAhrabli DavidWootten/RogerRucker WestinghouseRVI RandyLott SequoyahACRSSubcommittee 5
Paul Simmons Plant Manager PlantHistoryandBackground SequoyahACRSSubcommittee 6
Sequoyah Nuclear Plant Site SequoyahACRSSubcommittee 7
Plant Overview
- SequoyahUnits1and2arelocatedon525acresbesidethe ChickamaugaReservoirontheTennesseeRiver,approximately18 milesnortheastofthecitycenterofChattanooga,Tennessee
- Sequoyahsupplieselectricitytoapproximately8.3millionpeople through158distributorsintheTVAservicearea
- SequoyahisatwounitWestinghouse4loopPWR
- GeneratoroutputforeachSequoyahunitis1199MWeforrated corepower
- EachSequoyahcontainmentisafreestandingsteelvesselwithanice condenserandseparatereinforcedconcreteshieldbuilding
- Twonaturaldraftcoolingtowersusedinhelpermodeasrequired forNPDESlimits
- 161KVand500KVswitchyards SequoyahACRSSubcommittee 8
Site Location SequoyahACRSSubcommittee 9
History and Background
- ConstructionPermit-May1970
- OperatingLicense
- Unit1 September17,1980
- Unit2 September15,1981
- CommercialOperation
- Unit1 July1,1981
- Unit2 June1,1982
- 1.3%MeasurementUncertaintyRecaptureUprate(44MWt)
- Unit1and2 2002
- SteamGeneratorReplacement
- Unit1-2003/Unit2 2013 SequoyahACRSSubcommittee 10
Current Status
- CurrentPlantStatus-November5,2014
- INPOIndexof100%onbothunits(TopQuartile97.5%)
- Unit1 97%EquipmentReliabilityIndex
- Unit2 98%EquipmentReliabilityIndex
- NextRefuelingOutage
- Unit1-Refueling Outage20- April2015
- Unit2-Refueling Outage20- November2015 SequoyahACRSSubcommittee 11
William Pierce Engineering Director MajorModificationsandNearTermImprovements SequoyahACRSSubcommittee 12
Major Modifications Completed or In Progress
- InstalledpressurizerPWSCCresistantfullstrengthweldoverlays (U12007,U22006)
- ReplacedportionsofsecondarysidepipingwithFACresistantmaterial (beganin1990sandongoing)
- Replacedsteamgenerators(U12003;U2 2013)
- Replacedmaincondensertubebundles(titaniumtubes;titaniumclad tubesheets)- U21996,U11997
- Replacedportionsofcarbonsteelservice/rawwaterpiping(2014)
- Replacedfireprotectionpumps/tanksandchangedwatersourcefrom rawwatertopotablewater(1998)
- Replacedcontainmentspray HX1B (1998)andcomponentcoolingwater HXs(1993)
SequoyahACRSSubcommittee 13
Near Term/Future Plant Improvements RefuelingU1Outage20(April2015)
- Replacing~10thimbletubes
- Replacingcontainmentsprayheatexchanger1A RefuelingU2Outage20(November2015)
- Replacing~10thimbletubes 2015and2016
- Replacingportionsofcarbonsteelservice/rawwaterpiping
- Designingandbegininstallingcathodicprotection(complete2017)
- ReplacingCRDandAuxiliaryBuildingHVACcoolingcoils SequoyahACRSSubcommittee 14
Erin Henderson Licensing Manager LicenseRenewalApplicationPreparation SequoyahACRSSubcommittee 15
License Renewal Application - Project
- ApplicationDevelopment
- LRProjectTeamassembled-2010
- ExperiencedTeamselected
- SequoyahProgramOwnersandSystemEngineers-earlyand continuousinvolvement
- TechnicalDocuments(Reports/RAIs)review/concurrencebySMEs andProgramOwners
- Utilizedreviewsbyindustryexperiencedpersonnel
- IndustryInteraction
- NEIWorkingGroupinvolvement(Contractor/TVA)
- Industrypeerreview
- IndustryOEutilizedinLRAdevelopment SequoyahACRSSubcommittee 16
Dennis Dimopoulos Engineering Manager LicenseRenewalApplicationResults SequoyahACRSSubcommittee 17
License Renewal Application Details
- ApplicationDetails
- SubmittedapplicationJanuary7,2013
- DevelopedusingNUREG1801(GALL)Rev2
- FollowedscopingguidanceofNEI9510IndustryGuideline forImplementingtheRequirementsof10CFR54TheLicense RenewalRuleRev6
- ConductedAgingManagementReview(AMR)perNEI9510 andindustryguidancedocuments
- AddressedsixLicenseRenewal(LR)ISGdocumentsinthe LRAandtwoLRISGdocumentsinRAIresponses
- Completed~4100AMRlineitems
- 43AMPs(31existingand12new)requiredtomanageaging effectsforthePEO SequoyahACRSSubcommittee 18
Aging Management Program (AMP) Summary 43AMPsCredited SequoyahACRSSubcommittee 19 Consistent withGALL Consistent with Enhancement Consistentwith Enhancements andExceptions PlantSpecific Total LRA 20 22 0
1 43 SER with OpenItem 17 24 1
1 43
License Renewal Application (LRA)
Commitments
- LicenseRenewalCommitments
- IncludedinFSARSupplement(AppendixAofLRA)
- ManagedbySequoyahCommitmentTrackingSystemand CorrectiveActionProgram(CAP)
- Totalof44commitments
- 43associatedwithAMPs
- 1associatedwiththeOperatingExperience(OE)program SequoyahACRSSubcommittee 20
Implementation
- ParticipatinginNEILRImplementationWorkingGroup
- SelectedpermanentAgingManagementCoordinator
- InitiatedinformalOEreviewforimpactstoAMPsinadvance ofrevisiontofleetproceduralguidance
- Initiatedworktoaddresscommitments
- SequoyahAMPOwnerswillguidetheimplementationeffort assistedbyexperiencedimplementationcontractor SequoyahACRSSubcommittee 21
Safety Evaluation Report (SER) with Open Item
- SequoyahSERcontainsoneOpenItem
- SequoyahSERcontainsnoconfirmatoryitems
- SequoyahSERcontainstwoLicenseConditions
- LicenseCondition1 Include10CFR54.21(d)UFSARsupplementinthenextUFSARupdate EvaluatechangestoUFSARsupplementper10CFR50.59
- LicenseCondition2 ImplementnewprogramsandenhancementssixmonthspriortothePEO PerforminspectionsandtestingbeforetheendofthelastRFOpriortothePEOor sixmonthspriortothePEO,whicheveroccurslater SequoyahACRSSubcommittee 22
Michael Henderson Engineering Programs Manager SEROpenItem SequoyahACRSSubcommittee 23
SER - Open Item B.1.349c RAIRequest
- Providedescriptionofthemethodologyusedtoprojectthe60year fluenceattheReactorVesselInternal(RVI)uppercoreplate(UCP)
- Providetheprojected60yearfluenceattheUCPcomparedtothe screeningthresholdfluenceforIrradiationEmbrittlement(IE)
Resolution
- Providedthemethodologyusedforthefluenceprojectionsaswell asthe60yearprojectedfluenceatthebottomoftheUCP
- NeutrontransportmethodmeetsRG1.190
- MethodologydescribedinNRCapprovedWCAPs14040Aand 16083NPA
- ProvidedthebasisfortheconclusionthatMRP227Ainspection protocolsforRVIsremainvalidforSequoyahU1andU2
- ResponsespreparedbythePWROG andapprovedbyTVASQN Status
- Responsesubmitted SequoyahACRSSubcommittee 24
Reactor Vessel Internals Upper Core Plate SequoyahACRSSubcommittee 25
Concluding Remarks
- SequoyahLRAbasedonNUREG1801,Rev.2withexceptionsonly intheFireWaterProgramforLRISG201202
- 44CommitmentstoimproveexistingAMPs,toimplementnew AMPsandtoenhancetheOEProgram
- SequoyahAMPOwnersandSMEsinvolvedin:
- Developmentoftheapplication,technicalreports,audit&inspection interviews,RAIresponsesandcommitmentdevelopment
- Programsandprogramenhancementsdefinedformanaging agingeffectsatSequoyahforthePEO
- Investedinplantmodificationsforcontinuingsafe,reliable extendedoperation SequoyahACRSSubcommittee 26
Comments and Questions?
SequoyahACRSSubcommittee 27
Safety Evaluation Report (SER) with Open Items November 5, 2014 Emmanuel Sayoc, Project Manager Office of Nuclear Reactor Regulation Advisory Committee on Reactor Safeguards License Renewal Subcommittee Sequoyah Nuclear Plant, Units 1 and 2 1
Presentation Outline
- Overview of Sequoyah license renewal review
- Region II License Renewal Onsite Inspection
- SER Section 2, Scoping and Screening Review
- SER Section 3, Aging Management Review
Audits and Inspections Scoping and Screening Methodology Audit
- March 11-14, 2013 Aging Management Program (AMP) Audit, weeks of
- March 18, 2013, and March 25, 2013 Environmental Audit
- April 8-12, 2013 Region II Inspection (Scoping and Screening & AMPs), weeks of
- October 21, 2013 - Unit 1 Containment Walk-down
- November 18, 2013 and December 2, 2013 - Team Inspection 3
Overview (SER)
- Safety Evaluation Report (SER) with Open Items issued September 29, 2014
- OI B.1.34-1: Reactor Vessel Internals Program
- The final SER is scheduled for publication January 5, 2015 4
Inspection Overview:
- Inspection Procedure IP71002 completed in 2013 o Oct. 2013 - Containment walk-down during Unit 1 refueling outage o Nov. 2013 - Team Inspection (5 inspectors and 1 NRR materials engineer) on-site for 2 weeks
- Inspection Scope:
o Scoping and Screening Methodology of SSCs o Aging Management Programs for In-scope SSCs o Updates to the License Renewal Application and Open Items Inspection 5
Region 2 Inspections
6
==
Conclusions:==
Scoping and screening performed in accordance with 10 CFR 54 Existing programs were effective in managing aging effects Plans existed to implement enhancements and new programs Information used to prepare the license renewal application was retrievable, auditable, and consistent with 10 CFR 54 Reasonable assurance that aging effects will be managed and intended functions maintained Region 2 Inspections
Section 3: Aging Management Review
- Section 3.0 - Aging Management Programs
- Section 3.1 - Reactor Vessel & Internals, Reactor Coolant System
- Section 3.2 - Engineered Safety Features
- Section 3.3 - Auxiliary Systems
- Section 3.4 - Steam and Power Conversion System
- Section 3.5 - Containments, Structures and Component Supports
- Section 3.6 - Electrical and Instrumentation and Controls System 7
SER Section 3 3.0.3 - Aging Management Programs
- 43 Aging Management Programs presented by applicant and evaluated in the SER
- 31 Existing and 12 new
- Consistent - 17
- Consistent with Enhancements - 24
- Consistent with Enhancements and Exceptions - 1
- Plant Specific - 1 8
9 SER Section 3 Open Item OI B.1.34-1: Reactor Vessel Internals Program
- Issue: The applicants response to A/LAI No. lacked information on projected fluence values for upper internals and upper core plate.
- Staff issued RAI B.1.34-9a, requesting the applicant demonstrate 60-year fluence below embrittlement threshold
- Resolution of OI B.1.34-1 is pending staffs review of the applicants response
4.1 Identification of TLAAs 4.2 Reactor Vessel Neutron Embrittlement Analysis 4.3 Metal Fatigue 4.4 Environmental Qualification of Electric Equipment 4.5 Concrete Containment Tendon Prestress Analyses 4.6 Containment Liner Plate, Metal Containments, and Penetration Fatigue Analyses 4.7 Other Plant-Specific TLAAs SER Section 4: TLAA 10
Pending satisfactory resolution of the open item, the staff will render its decision in the final SER on meeting the requirements of 10 CFR 54.29(a) for the license renewal of Sequoyah Plant, Units 1 and 2 Conclusion 11