ML111020379
| ML111020379 | |
| Person / Time | |
|---|---|
| Site: | Diablo Canyon  |
| Issue date: | 03/31/2011 |
| From: | Division of Operating Reactor Licensing |
| To: | |
| Wang, A B, NRR/DORL/LPLIV, 415-1445 | |
| References | |
| TAC ME5033, TAC ME5034 | |
| Download: ML111020379 (87) | |
Text
UNITED STATES OF AMERICA U.S. NUCLEAR REGULATORY COMMISSION FORTHCOMING PRE-LICENSING MEETING WITH REPRESENTATIVES OF PACIFIC GAS AND ELECTRIC COMPANY March 31, 2011 1:00 P.M. to 4:00 P.M.
TRANSCRIPT OF PROCEEDINGS Public Meeting Rockville, Maryland
2 APPEARANCES Pacific Gas & Electric Company:
Loren Sharp Senior Director Engineering Services at Pacific Gas and Electric Nathan Barber PRA Engineer, Pacific Gas & Electric Company Norm Abrahamson Engineering Seismologist, Pacific Gas & Electric Company Bill Horstman DCPP Senior Civil Engineer, Pacific Gas & Electric Company Philippe Soenen Project Manager, Strategic Projects Organization Diablo Canyon Power Plant Rich Klimczak Design Engineering Manager, Pacific Gas & Electric Company Jennifer Post Attorney, Pacific Gas & Electric David Repka Winston & Strawn, LLP, Counsel for Pacific Gas & Electric Kimberly Keithline Senior Project Manager, Nuclear Energy Institute NRC Staff:
Alan Wang Project Manager, Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Annie Kammerer Senior Seismologist and Earthquake Engineer Office of Nuclear Regulatory Research
3 James Polickoski Project Manager Office of Nuclear Reactor Regulation Maxwell Smith Counsel for NRC Staff US Nuclear Regulatory Commission Office of the General Counsel Michael Markley Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Kamal Manoly Senior Technical Advisor, NRR, Division of Engineering Susan Uttal Senior Attorney, OGC Jenny Weil Congressional Affairs Officer Martin Stutzke Senior Technical Advisor, Probabilistic Risk Assessment Technologies in the Division of Risk Analysis, Office of Nuclear Regulatory Research Eric Oesterle Acting Chief, Mixed Oxide and Uranium Deconversion Branch Division of Fuel Cycle Safety and Safeguards Office of Nuclear Material Safety and Safeguards Ata Istar Office of Nuclear Safety and Safeguards
4 P R O C E E D I N G S 1
JAMES POLICKOSKI: We'll go ahead and get started. Good 2
afternoon, or morning, for folks that are joining us on the West Coast. My name 3
is Jim Polickoski; I'm the project manager, the Division of Operating Reactor 4
Licensing here at NRC, the responsibility for the Diablo Canyon Power Plant.
5 Today's meeting between the NRC staff and Pacific Gas and 6
Electric is being conducted at the NRC staff's request to discuss with the licensee 7
the NRC staff's questions raised during the previous public meeting which the 8
NRC held on January 26, 2011, as documented in the public meeting 9
announcements, and meeting summary via Adams [spelled phonetically] ML110-10 120-564, ML110-420-183. This meeting and the previous meeting are related to 11 the licensee's plans to submit a license amendment request to incorporate a 12 methodology for the review of new geotechnical information, and the design and 13 licensing basis for Diablo Canyon Power Plant units one and two.
14 Specifically, the licensee plans to discuss the following questions 15 provided by the NRC staff, and as listed in today's meeting agenda, that is, the 16 enter criteria [spelled phonetically] and intended purpose for their long term 17 seismic program, which I'll call the LTSP for the rest of the day. The long term 18 seismic program flowchart. Clarification of how the LTSP flowchart will be used 19 in various applications, with specific reference to the existing design and 20 licensing basis. Clarification of how an LTSP evaluation relates to the existing 21 design and licensing basis. How LTSP analysis will be used in licensing actions, 22 in light of the existing design and licensing basis. And the role of the LTSP 23 analysis in future operability determinations, and how the analysis that evaluates 24 the Shoreline fault, and any future unevaluated seismic ground motions, in terms 25
5 of ASME code allowables and against the existing design and licensing basis.
1 The above was discussed in more detail in the notes for the public 2
meeting, and that is the agenda that was attached.
3 I'd like to welcome everyone in attendance and go over a few 4
details before we proceed with the meeting. This meeting is a Category One 5
public meeting, in accordance with the Commission's policy statement on 6
enhancing public participation in NRC meetings, dated May 28, 2002. As such, it 7
is intended to be a dialogue between the NRC and Pacific Gas and Electric 8
concerning issues related to the operating license for Diablo Canyon Power Plant 9
units one and two. The public is invited to observe the meeting, and will have the 10 opportunity to communicate with the NRC staff after the business portion of the 11 meeting, but before the meeting is adjourned. The licensee may respond to 12 comments or questions from the public. The licensee is not obligated to do so.
13 Please identify yourself and your affiliation as we go through the 14 introductions, and that's important today because, and it's part of also, the 15 webcast that we're -- that this meeting is being held under as well. We have a 16 court recorder and stenographer for purposes of closed captioning. So it's 17 important that, not just in the beginning here, but if we could make it a habit, as 18 we're speaking, to identify who you are as you go along for the purposes of court 19 recorder and stenographer.
20 I also had sign-in sheets, some are pre-typed, some blank, for who 21 I was -- new coming here. So please make sure you've initialed and signed in so 22 we can verify who attended. There are also public meeting feedback forms 23 available on the side table if you wish to provide any comments. This meeting 24 was noticed on March 18, 2011, and excess copies of the agenda are available 25
6 to the right as they stayed on that table over there.
1 I understand that we do have members of the public in attendance 2
locally here at NRC headquarters, that have called into the teleconference, and 3
that are most likely observing via today's webcast. The meeting is scheduled 4
from 1:00 to 4:00 p.m. Eastern Daylight Time. It is our understanding that no 5
proprietary information will be discussed, is that correct?
6 MALE SPEAKER: That is correct.
7 JAMES POLICKOSKI: Okay. This meeting is primarily for Pacific 8
Gas and Electric to convey information to the NRC. As such, no regulatory 9
decisions will be made at this meeting. A meeting summary, including a copy of 10 any presentation slides, will be made publicly available shortly after the meeting.
11 At this point, let's introduce ourselves. Again, my name is Jim Polickoski, Project 12 Manager for Diablo Canyon, from Division of Operating Reactor Licensing.
13 ANNIE KAMMERER: Annie Kammerer, NRC Office of Research, 14 Division of Engineering.
15 KAMAL MANOLY: Kamal Manoly, senior technical adviser, 16 Division of Engineering, NRR.
17 MAXWELL SMITH: Maxwell Smith, Office of General Counsel.
18
[low audio]
19 JAMES POLICKOSKI: If it's red, it means it's on.
20 PATRICK HILAND: [laughs] Thank you. I'm Pat Hiland, I'm the 21 director of the Division of Engineering, within the Office of NRR.
22 NORMAN ABRAHAMSON: I'm Norm Abrahamson, seismologist 23 with PG&E.
24 LAWRENCE SHARP: Lawrence Sharp [spelled phonetically],
25
7 senior director of Technical Services with Diablo Canyon, for PG&E.
1 RICH KLIMCZAK: Rick Klimczak, design engineering manager, 2
PG&E.
3 PHILIPPE SOENEN: Philippe Soenen, supervisor, Regulatory 4
Services, Diablo Canyon, PG&E.
5 ALAN WANG: Alan Wang, project manager, NRR.
6 MICHAEL MARKLEY: Mike Markley, chief, Plant Licensing Branch 7
8 JAMES POLICKOSKI: Start over there.
9 DAVID REPKA: I'm David Repka of Winston and Strawn, counsel 10 for PG&E.
11 JENNIFER POST: Jennifer Post, counsel for PG&E, in house.
12 GREG HARDY: Greg Hardy, from SGH, consultant to PG&E.
13 BILL HORSTMAN: Bill Horstman, senior civil engineer, PG&E.
14 NATHAN BARBER: Nathan Barber, senior PRA engineer, PG&E.
15 ERIC OSTERLEY: Eric Oesterle [spelled phonetically], NRC.
16 JAMES POLICKOSKI: [inaudible] go ahead [inaudible].
17 MALE SPEAKER: [unintelligible], Project Manager, DORL[spelled 18 phonetically], NRR.
19 MALE SPEAKER: [inaudible], NRO.
20 FEMALE SPEAKER: [inaudible]
21 MALE SPEAKER: [inaudible], NRC.
22 MALE SPEAKER: Steve [spelled phonetically] [unintelligible],
23 NRC.
24 MALE SPEAKER: [inaudible]
25
8 MALE SPEAKER: [inaudible], NRC, NRR [inaudible].
1 SUE MAY WONG: Sue May Wong [spelled phonetically], NRC, 2
NRR Division of Risk Assessment.
3 FEMALE SPEAKER: [inaudible], NRC, License Renewal.
4 MALE SPEAKER: [inaudible], NRC, NRR, License Renewal.
5 MALE SPEAKER: [inaudible]
6 JAMES POLICKOSKI: Go ahead, no, now we'll move on to the 7
folks on the phone. I understand we have a number of folks on the phone.
8 Bridge [spelled phonetically], if you can just be a little slow in helping me spell 9
names, as well. We'll start with Region IV.
10 JANE SWANSON: This is Jane Swanson [unintelligible], S-W-A-N-11 S-O-N, calling as an individual although I am affiliated with Mothers for Peace.
12 JAMES POLICKOSKI: Thank you, Jane.
13 JANE SWANSON: [affirmative]
14 CAROLINE MCANDREWS: Caroline McAndrews [spelled 15 phonetically], calling from Southern California, Edison.
16 JAMES POLICKOSKI: What was the first name, ma'am?
17 CAROLINE MCANDREWS: Caroline.
18 JAMES POLICKOSKI: Caroline McAndrews. Thank you.
19 MICHAEL PECK: Here at Diablo Canyon, we have the resident 20 inspectors, Michael Peck, Jonathan Brostead [spelled phonetically], and Christie 21 Dennison [spelled phonetically].
22 JAMES POLICKOSKI: Thank you, Michael.
23 RICHARD DEESE: Here in Region IV, you have Rick Deese, 24 senior project engineer.
25
9 LAURA UFELDING: And Laura Ufelding, U-F-E-L-D-I-N-G, public 1
affairs, Region IV.
2 JAMES POLICKOSKI: Thank you, Rick and Laura. Anyone else 3
from Region IV on the phone, Bridge? And then any members of the public, 4
besides Caroline and Jane?
5 BOB WHORTON: Bob Whorton, W-H-O-R-T-O-N, with South 6
Carolina Electric and Gas Company.
7 JAMES POLICKOSKI: And what was the first name, sir?
8 BOB WHORTON: Bob.
9 JAMES POLICKOSKI: Bob Whorton.
10 MALE SPEAKER: Okay, Im Stan [spelled phonetically], from 11 SCE&G [spelled phonetically].
12 JAMES POLICKOSKI: Thank you, sir. Anyone else from the 13 public?
14 DAVID NIKAKI: David Nikaki [spelled phonetically], with Simpson, 15 Gumpertz, and Heger.
16 JAMES POLICKOSKI: Thank you, sir. Anyone else from the 17 public? Okay, I'll take that as no one else on the phone.
18 WALLY HAFIZ: This is Wally Hafiz from [unintelligible] Exelon 19 Clinton Power Station.
20 JAMES POLICKOSKI: I apologize, sir, can you say that -- say your 21 name again, one more time, sir.
22 WALLY HAFIZ: Wally, W-A-L-L-Y, last name Hafiz, H, like Henry, 23 A-F, like Frank, I-Z, like zero, from Exelon Clinton Nuclear Power Station.
24 JAMES POLICKOSKI: Sir, I apologize. If you can just spell your 25
10 name, last name, one more time. I have your first name.
1 WALLY HAFIZ: Hafiz: H, like Henry, A like apple, F like Frank, I, 2
and Z like zero.
3 JAMES POLICKOSKI: Thank you, sir. Anyone else from the 4
public? Okay, I'll turn it now over to the other, any other NRC managers or staff, 5
for introductory remarks. Mr. Hound [spelled phonetically], do you have any 6
remarks, sir?
7 MALE SPEAKER: No, thank you. As you must realize, we've been 8
fairly busy the last few weeks. I've been able to break away, and I'm interested 9
to hear what you have to say today. Thank you.
10 JAMES POLICKOSKI: Mike?
11 MICHAEL MARKLEY: No, we'd just like to thank, this is the third 12 pre-licensing meeting we've had on this subject, and I realize a lot of work has 13 been going into seismic, both with the licensee and the NRC, so thank you very 14 much.
15 JAMES POLICKOSKI: With that, I have two final comments. I ask 16 that, during the presentation, while others are speaking, if you could please mute 17 your phone, for those that are on the phone conference, as well as here at the 18 table. Actually, here at the table, I don't mind if your mics stay red, because we'll 19 probably be in exchange. But for the folks on the bridge, if your phone does not 20 have a phone mute capability, our phone bridge allows you to press star six on 21 your keypad, and that will actually mute your phone, and then star six again will 22 unmute it on the phone bridge.
23 There's also one last piece of guidance that I was given strict 24 orders to obey, and that this room has a strict no food, no drink policy, and that I 25
11 must obey that. And that is hard for me, as I will have to survive without my Diet 1
Coke, so. But I now turn it over, unless there's any other remarks, to Pacific Gas 2
and Electric, for their presentation. And, by the way, my intention is to, after your 3
presentation, is to ensure we go through each of the six questions on the 4
agenda.
5 RICH KLIMCZAK: Thank you, so, actually, we'd recommend, for 6
answering part of the first question, instead of providing clarifications for the other 7
questions, we're going to walk through our revised flowchart, and then we'll make 8
sure that we go through the questions like you mentioned.
9 JAMES POLICKOSKI: Okay, and if you could just help us out. We 10 have it up on the -- for all attendees, we have, hopefully for everyone who 11 attended that I knew about, we forwarded the licensee's presentation, for here at 12 the -- in the hearing room, it's on the various screens, and we'll just try to -- keep 13
-- let us make sure we're navigating at the right spot. And we'll try to keep that 14 up for the folks on the bridge. But right now, we're on the PDF file, their 15 flowchart, first page.
16 RICH KLIMCZAK: Okay. This is to address question one, 17 discussion of entry conditions --criteria for use of --
18 JAMES POLICKOSKI: Rich, if you don't mind identifying yourself 19 for our stenographer, court reporter, just to make sure we know that you're 20 speaking. Each time, it helps us out.
21 RICH KLIMCZAK: I have to --
22 JAMES POLICKOSKI: Sorry.
23 RICH KLIMCZAK: -- announce myself?
24 JAMES POLICKOSKI: Yeah, if you don't -- just say your first name, 25
12 and they already have your title.
1 MALE SPEAKER: If you don't want her chasing you to get your 2
name, that's --
3
[laughter]
4 RICH KLIMCZAK: I think I'm the only Rich. So this is Rich.
5
[laughter]
6 So, the first question was discussion of entry conditions (criteria) for 7
use of the Long Term Seismic Program flowchart, and for what purposes this 8
flowchart will specifically be used.
9 So we're going to walk through the flowchart to answer that 10 question. Starting in the first block below flowchart A overview, it says, Process 11 for updates in the Long Term Seismic Program, seismic probabilistic risk, and 12 seismic margin assessment. Diablo Canyon had a license condition. As a 13 result of that, the license condition required, PG&E shall develop and implement 14 a program to reevaluate the seismic design bases used for the Diablo Canyon 15 Power Plant. We met this condition by the LTSP program.
16 This process we are about to go through will utilize the same 17 evaluation process as in the LTSP to address new geologic and seismic data 18 information interpretations. Also, in Supplemental Safety Evaluation Report 34, 19 the NRC recognized PG&E's commitment to continue to maintain a staff to keep 20 abreast of the new seismic, new geological, seismic, and seismic information, 21 and evaluate it with respect to Diablo Canyon. This process we're going to go 22 through is how we're going to evaluate that new information.
23 So, the first block I was in, I said what we were going to do.
24 There's a note there to be performed on a 10-year interval. Note one: Is this 25
13 update to be performed at less than a 10-year interval if significant new 1
information becomes available. The start of each interval to be based on 2
submittal date of the prior update.
3 Going to the next box below that, we're entering the process now.
4 Update LTSB Seismic Hazard Input Information Received by DCCP. Note two:
5 seismic hazard input is developed by the PG&E Geoscience Department. Types 6
of input include seismic hazard curves, deterministic ground motion, response 7
spectra, source characterization, and ground motion spectral shapes.
8 When we get this new hot seismic hazard information, we would 9
enter the process where we go down to the circle below this box, and we would 10 go to the right first, which we call our seismic margins assessment. It's our 11 primary path. We intend now to use that for operability determinations for the 12 plant. And this process will be run through within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of receipt of data.
13 KAMAL MANOLY: Let me interrupt you.
14 RICH KLIMCZAK: Yeah.
15 KAMAL MANOLY: Can you clarify by significant new information?
16 NORMAN ABRAHAMSON: This is Norm, and I'll try to answer that.
17 So, we are continually doing studies, or evaluating seismic information around 18 the world, for either ground motion models or new source characterization. That 19 will still be a judgment as to when it is significant enough to accelerate the 10-20 year update instead of waiting for 410 years. So that will be, generally, 21 information that we're aware of, and if it's in the general literature, the NRC will 22 also be aware of that information as it becomes available.
23 But an example would be new major ground motion studies, or 24
[unintelligible] would say, out of the Pacific Earthquake Engineering Research 25
14 Center, is going to issue a whole new set of ground motion models. That would 1
be a big change, and at that time, we would step up our evaluation. If there was 2
some new information we had on, you know, the offshore faulting, or new 3
characterization of the local faulting onshore, that indicated we had a significant 4
change to our models, then we would move that forward. So it's somewhat of a 5
judgment for us, as to when something becomes significant, but usually it's 6
enough to move the hazard in a way that matters, okay, to what the risk would be 7
at the plant, as opposed to waiting for the 10 years to then go forth and have just 8
a normal update.
9 KAMAL MANOLY: So you're saying it's an engineering judgment, 10 right?
11 NORMAN ABRAHAMSON: It's a mixture of engineering and 12 science, I would say this is mainly on the earth science judgment, because we're 13 not judging the impacts on the plant; we're saying do our design response 14 spectra or hazard curves significantly change?
15 KAMAL MANOLY: Okay. Thank you.
16 RICH KLIMCZAK: This is Rich again. Before we leave the seismic 17 margin assessment box, we have a note three: seismic margin assessment is 18 based on deterministic ground motion response spectra. All that box, we go into 19 flowchart B, and so I'll go to the next page.
20 Flowchart B: seismic margin assessments. It's the entry point from 21 flowchart A. We have received an updated deterministic ground motion 22 spectrum. Note one: the deterministic ground motion spectrum was developed 23 by PG&E Geoscience Department in accordance with current peer-reviewed 24 methodologies. That starts our process for deterministic. Our first decision box 25
15 is the updated deterministic ground motion response spectra enveloped by our 1
1991 LTSP, deterministic ground motion spectra. Probably be a good time to go 2
to the chart of the spectra, so everyone knows what I'm talking about. In this 3
chart of deterministic comparison, we'll see the dashed spectrum is the 1991 4
LTSP spectrum we're talking about, that we would compare this new 5
deterministic ground motion spectra to.
6 So if that first -- going back to the first decision box, if this new 7
deterministic ground motion response spectra is enveloped by the 1991, we go 8
off to the right, to yes. We would consider any shape changes or any impact on 9
our Heathcliff capacities for impacted SSCs, modify those, and follow the box, we 10 would update our documents. The LTSP ground motion spectra Heathcliff, 11 seismic margins. For this path, we would not be updating the [unintelligible]
12 response spectrum. We would return to flowchart A, which is flowchart B coming 13 back in, and we would submit a peer-reviewed update to NRR.
14 Going back to flowchart B, that same decision box, if the new 15 ground motion spectrum is not enveloped completely, or at all, by the 1991, the 16 answer would be no. The next decision box we would look at, does this change 17 in response spectra impact the Heathcliff capacities? If the answer is no, we'd go 18 to the next box, where we'd reassess the plant's seismic margins for impacted 19 SSCs with the new ground motion spectra and Heathcliff capacities.
20 JAMES POLICKOSKI: Can you expand on that a little bit, on how 21 you're going to go about that, because -- or are you going to get in that later, with 22 the other questions?
23 RICH KLIMCZAK: I believe the next decision box will get you 24 there. The seismic margin is the Heathcliff capacity over the demand. And if the 25
16 seismic margin is greater than or equal to one, then that will take care --
1
[unintelligible] takes in account the new ground motion spectra, the impact on the 2
Heathcliffs. We calculate the seismic margin to that criteria. And if it is greater 3
than or equal to one -- and since the last time, we used to have 1.14 in there. It's 4
1.0 now. That is consistent with SSER [spelled phonetically] 34 Section 3.8.1.8, 5
where the NRC stated the LTSP deterministic spectra will use to provide 6
assurance that the plant Heathcliff capacity estimates are at least equal to the 7
seismic demand.
8 KAMAL MANOLY: If -- so I guess, you're not providing any margin 9
beyond the 1.0?
10 RICH KLIMCZAK: Right, but there -- in the calculation of the 11 seismic margin, there is conservatism. And I'll have to --
12 KAMAL MANOLY: Well, there's conservatism in anything, but --
13 and we know that. But just in terms of the decision point here, you initially had 14 different numbers, and you were contemplating other numbers.
15 RICH KLIMCZAK: Yeah, we thought this, this is following the same 16 philosophy, and it made the decision easier. So when are you really affecting 17 operability?
18 KAMAL MANOLY: Operability?
19 RICH KLIMCZAK: Yeah. See, if we answered no to this, if the 20 seismic margin that we calculate due to the change in response spectra was less 21 than one, that's the no block off to the right -- left. And then wed have to, for that 22 SSC, where we don't meet that seismic margin criteria, we'd enter the applicable 23 tech spec [spelled phonetically] limiting condition of operation.
24 ANNIE KAMMERER: So you're saying an adequate margin is 25
17 basically [inaudible] so it's like for [inaudible] that's from -- and you're basing that 1
on SSER 34?
2 RICH KLIMCZAK: Yes. [inaudible] plus there's conservatism in the 3
way we calculate Heathcliffs. [inaudible] one of our experts talk to that.
4
[low audio]
5 GREG HARDY: This is Greg.
6 MALE SPEAKER: Into the mic.
7 GREG HARDY: Is this on? I guess so. Greg Hardy. The whole 8
seismic margin method is predicated on showing margins. So this greater than 9
1.0 is really just demonstrating you've got adequate margins. So you set up the 10 process which is consistent with the LTSP for establishing margin, and you follow 11 the SMA criteria that you used to come up with a conservative deterministic 12 failure margin. So what they're describing is the amount of margin that's been 13 required, and would be required in any seismic margin study. You establish the 14 earthquake, you go through this process, got a certain amount of allowables that 15 you're required to use, and you establish that your demand, your capacity is 16 greater than that review level earthquake demand that youre coming up with. So 17 thats really what this describes.
18 ANNIE KAMMERER: Okay, so the Review Level Earthquake, 19 though, is based on the deterministic assessment, with some sort of margin 20 thats already -- so its the deterministic ground motion times some sort of 21 allowable margins, which are defined elsewhere to give you a Review Level 22 Earthquake. Its the Review Level Earthquake thats then compared. Im a little 23 confused because the way that this is stated, it makes it seem like you 24 essentially have no margin.
25
18 GREG HARDY: Youre establishing margin, consistent to what 1
happened in the LTSP -- so this is a margin evaluation up to this kind of criterion 2
comparison. You generate this high-confidence, low-probability or failure level, 3
which is -- that high-confidence itself establishes margin -- you calculate that 4
value.
5 KAMAL MANOLY: Is that based on orderly?
6 GREG HARDY: Well, its based on this deterministic earthquake 7
characterization.
8 KAMAL MANOLY: The orderly -- how does the orderly relate to the 9
GRMS?
10 GREG HARDY: Im not sure -- could you --?
11 KAMAL MANOLY: The orderly -- the reference -- the Review Level 12 Earthquake, how does it relate to the GRMS for this?
13 NORM ABRAHAMSON: This is Norm again. We have a 14 deterministic earthquake, which is an 84-percentile ground motion from a large 15 earthquake inbounding on any of the nearby faults. In this case, this was from 16 LTSP -- it was the Hosgri fault that led to the largest ground motions in 1988.
17 Today we have different faults that are controlling it, but were still using that level 18 of shaking as our earthquake. The key here, I think what Greg was getting at, is 19 that we -- the way the Heathcliff is already done, were not setting capacity equal 20 to demand. Thats not what were doing on the margin. The Heathcliff already 21 creates margin, so as long as youre below that level, were setting -- one, is your 22 Heathcliff is already an adequate margin for operability, and then -- as opposed 23 to saying the additional margin has to be set what the Heathcliff is already 24 creating. Is that making some sense?
25
19 ANNIE KAMMERER: Yeah. So your 84-percentile ground motions 1
are compared against the Heathcliff. The Heathcliff itself, by definition, is a high 2
confidence of a low-probability of failure -- not the median likelihood of failure.
3 NORM ABRAHAMSON: Correct. And so its five percent chance 4
of failure using lower bound properties -- or strength properties. I should say 5
lower estimates of the strength properties.
6 GREG HARDY: Right.
7 ANNIE KAMMERER: Okay. Thank you for the clarification.
8 RICH KLIMCZAK: Okay, this is Rich again. Since we went off to 9
the left, you know, if we didnt meet that criteria, whatever SSCs didnt meet it, 10 wed enter the applicable tax-back [spelled phonetically] limiting -- the limiting 11 condition of operation -- and then the box below, we would consider maybe 12 compensatory measures to restore that margin, so we could say we could meet 13 that LCO requirement. And then, if we cant -- and also to resolve the 14 compensatory measure, wed have to develop modifications to restore the 15 seismic margin. Going back to the decision box, is minimum seismic margin 16 greater than or equal to 1.0? If the answer is yes, if we are greater, we still need 17 to submit a license-amendment request because -- were on this path because 18 the new deterministic ground motion spectra exceeded the 1991 LTSP. So if you 19 go back to the deterministic spectrum charts --
20 JAMES POLICKOSKI: But right now, your license specifically 21 states the three earthquakes -- your DE, your DDE, and your Hosgri -- and that 22 probably jumps to the other questions ahead -- but the amendment request 23 needs to modify something related to the three earthquakes, and Im trying to 24 figure out how youre bridging it to LTSP, which was a margin-verification license 25
20 condition.
1 RICH KLIMCZAK: Thats true. And it was to address new seismic 2
information, so were following that same process. As a result of going through 3
the LTSP process, for example, back to the spectrum, if you look at the LTSP 4
spectrum, the dashed line, you will see when its compared to the Hosgri, which 5
is the blue line; that above 15 hertz it exceeded it.
6 JAMES POLICKOSKI: No, I understand the curve. Im asking --
7 this is a licensing-space question. Not a technical question.
8 LOREN SHARP: Hes headed there.
9 JAMES POLICKOSKI: Pardon me?
10 LOREN SHARP: I think hes headed there.
11 RICH KLIMCZAK: As part of the LTSP program, it allows you to 12 address these kinds of exceedances, and then the LTSP we did, and the NRC 13 concluded -- agreed with those -- was an insignificant impact on our SSCs, and 14 they did not require us to modify the Hosgri design spectra because of that 15 exceedance.
16 JAMES POLICKOSKI: I cant -- I dont --
17 RICH KLIMCZAK: Following this process, if you re-meet all the 18 criteria, there is no impact on your design basis earthquake. Were not changing 19
[unintelligible], were not changing the spectra -- ground spectra -- were not 20 changing the damping values, were not doing of that. Were going through this 21 evaluation to tell us whether we do impact those.
22 JAMES POLICKOSKI: Id prefer to bounce the question if we get 23 into that, because that is the guts of some of these relationship issues to the 24 balance of the designer licensing basis -- when you get to where the values are 25
21 closer, and the terms of hazard, and how it relates to the engineering it can make 1
-- in our assessment, it can make some portions of the spectrum where the 2
Hosgri is not the only thing thats limiting now. But --
3 NORM ABRAHAMSON: This is Norm again. Part of the reason 4
why we were set up looking at the LTSP spectrum deterministically, and the 5
LTSP hazard curves, is because for those cases we have margins evaluated. So 6
we know when were below those levels, were going to have at least as high of 7
margins as what we estimated before. So those are done, theyre reviewed, we 8
have fragility curves done for those parameters, and so forth. And so to evaluate 9
safety at the plant, and impacts of new information, LTSP gives us the best 10 baseline on which to work from. The other values -- we dont have a Heathcliff 11 value -- a margin set up for the other earthquakes. Theyre not taken to the 12 same level of analysis that was done during the LTSP program to establish what 13 those margins are, to establish the fragilities, and so forth.
14 JAMES POLICKOSKI: No, I understand the level of quality 15 difference, and I -- especially with the change in technology and the evaluation 16 methodologies have a full respect for that. But I think the challenge -- and I am 17 getting ahead -- but the challenge is how do we relate it to, I agree, -- especially 18 the other two earthquakes, because LTSP has a relationship to Hosgri, but to the 19 DE and the DDE, because -- I understand there are places where -- that theres 20 potential when you relate the hazard to the engineering that they could be 21 potentially more limiting, and how we bridge that, the fact that the evaluation 22 methodology hasnt been brought up to the same quality. I think thats a 23 challenge for us.
24 MICHAEL MARKLEY: But it -- just to bring it short -- I mean, this is 25
22 one of the things were going to have to struggle with in reviewing what youre 1
proposing is; you have certain values that are established in FSAR, and you also 2
have LTSP. And the values in your FSAR are your design basis. And this is 3
another piece -- this is a seismic margins analysis, so -- when we look at things, 4
we say, Okay, the values in your FSAR and LTSP. Not just LTSP. So thats --
5 LOREN SHARP: This is Lorne. I think, if we can defer for just a 6
little bit, so [unintelligible], I think well get to a better discussion on those topics if 7
you can wait a little bit.
8 JAMES POLICKOSKI: Okay. [unintelligible].
9 RICH KLIMCZAK: Okay, I was back up to the -- first, the decision 10 box -- because the new ground motions factor was not enveloped by the 1991 --
11 so if you go to the spectrum again, you know, you can pretend that these spectra 12 here shifted to the left, for example, and lets say that peak popped above the 13 LTSP, or even the Hosgri. Thats what were talking about when were going 14 down that flow path. It is not completely enveloped with the new deterministic 15 ground motion spectrum. And thats why we need a license amendment, 16 because with this proposed license amendment, that LTSP spectrum is going to 17 be our licensing basis. And were going to -- when get new seismic information, 18 were going to assess it against that to determine whether we do have impact on 19 our design, earthquakes or not. The same way the LTSP program did.
20 LOREN SHARP: This is Loren. So in general what he is saying is, 21 weve had the 1991 long term seismic program in place, we committed to it as a 22 license condition that we would continue to implement that process through the 23 letter, through shiffer [spelled phonetically] and, in general, thats the process 24 weve been using. So this would provide clarity for the record, on how we 25
23 continue to do this process going forward to provide the documentation, as weve 1
talked previously, on how we would review new geotechnical information. So we 2
lose any confusion, or lack of clarity; thats really our process for an OAR 3
submittal, to remove the clarity. So thats our motive for the OAR.
4 JAMES POLICKOSKI: But, I want to make sure from what you 5
stated that youre separating the evaluation methodology from the design and 6
licensing basis itself, you still -- my understanding from the previous meeting, you 7
still hold that your licensing basis, in terms of hazard and hazard related to the 8
engineering of the plant, is still the three: DE, DDE and Hosgri [spelled 9
phonetically] is that correct?
10 RICH KLIMCZAK: Yes we do all our design, our SSCs to those 11 earthquakes.
12 JAMES POLICKOSKI: Okay.
13 BILL HORSTMAN: This is Bill Horstman --
14 MALE SPEAKER: Into the mic, Bill.
15 BILL HORSTMAN: Oh yes.
16 JAMES POLICKOSKI: Theres -- also theres a mic over there for 17 all the folks as well. If we can get a hold of a portable mic, too.
18 BILL HORSTMAN: Okay. This is Bill Horstman. Just to kind of 19 clarify on that when Hosgri was introduced in 77, we did not go back and 20 redefine the design or double design earthquake, we still use those. And then 21 when long term seismic program earthquake was finalized in 91, that did not 22 redefine the Hosgri earthquake, either. So were using that solely for the seismic 23 margins and the seismic risk assessment. So those two changes in the 24 earthquakes didnt go back and affect the earlier earthquakes and thats just the, 25
24 kind of the historical approach that was taken on this, during the licensing of the 1
plant.
2 JAMES POLICKOSKI: Thats an important issue because from our 3
assessment of the licenses, that we did not see that they changed the validity of 4
their existence in the license. You now had additions to your license, not 5
deletions.
6 BILL HORSTMAN: We keep adding further earthquakes, yes.
7 JAMES POLICKOSKI: Okay. I just wanted to clarify that point, 8
because the way you were saying it was in essence it did not redefine them. I 9
want to be clear that youre saying that they did not get removed from your 10 license?
11 BILL HORSTMAN: They did not get removed.
12 JAMES POLICKOSKI: And they still have validity as much as 13 Hosgri?
14 RICH KLIMCZAK: Yes, but they did not -- this is Rich, and they 15 did not get modified as a result of the LTSP.
16 JAMES POLICKOSKI: Right, and that connects to Norms 17 comment of -- to the increase of quality level, which I know we respect that issue.
18 RICH KLIMCZAK: So that -- Im going back to the submit LAR box, 19 second from the bottom. Theres an arrow down to the document, that arrow 20 wouldnt take place until we got the license amendment approved from the NRC 21 for the LAR and we would update the documentation, return to flow chart A.
22 JAMES POLICKOSKI: Before we move on, I know Annies got a 23 comment so if we can stick on flow chart B just for a second.
24 ANNIE KAMMERER: Yeah. Sorry, Im still having a problem with 25
25 the margin of one because --and, okay, I work in a probabilistic world, I dont 1
work in a margins world, so perhaps you can explain to me why this is the case.
2 But for new reactors the way our point of comparison is the ground motion 3
response spectra with some, you know, design factors which become an SSE.
4 The SSE is compared to the Heathcliff with an additional margin of 1.67. So why 5
would -- and thats because then that gets us to our ultimate risk informed goals 6
from the agency. So -- and you can make the same argue there that the 7
Heathcliff is inherently -- inherently contains margin by its very definition. So, 8
because were not necessarily going back to what happened in the past, what 9
were looking here is codifying a new approach. Im having a bit of a hard time --
10 why for new reactors wed be looking at an additional margin of 1.67, here we 11 dont have that additional assurance.
12 NORM ABRAHAMSON: I can -- this is Norm again, I would start by 13 saying a couple of things. One; your new reactors should be safer than the old 14 reactors. I think that just moving forward you ought to expect improved 15 performance. What were looking at here is the plant operability. Is this an 16 immediate, sort of, the fact that we shut down issue. What we are also doing in a 17 parallel path is providing you with the numbers that youre really after, which will 18 be the risk numbers. So if we get to the next flow chart, we not only do this, but 19 we run our core damage frequency so that we can provide you with the risk 20 number and you can see what those are and are they fitting with the risk values 21 that youre looking for.
22 So this is sort of -- we have to have a simple way to move forward 23 to make a fast decision on operability. Its a different way of doing things then 24 what is typically done on -- as new information comes in, because were trying to 25
26 look at impacts on the plant. Do we have an immediate safety issue? Do we 1
have, you know, a less immediate safety issue that needs some remediation or 2
has the change in the seismic loading not had a strong impact on our core 3
damage frequency? Thats really what were trying to get at.
4 ANNIE KAMMERER: Okay, I get that -- those arguments. The one 5
complication there, though, is that youve asked that this is a pilot for generic 6
issue 199 and if thats the case, and depending on how that goes, that argument 7
requires that both sides of these are a requirement. And I understand that you 8
are saying for you guys, these will be. This is part of your license amendment, 9
but -- and this is just a comment not a question, that may have an impact how --
10 depending on how that programs goes, whether or not this is viable as a pilot 11 because that -- if someones only going to do a margins, depending on how that 12 works out that number would have to be different then, wed be looking at 13 something else because it wouldnt just be operability.
14 LOREN SHARP: Annie, this is Loren. Just a clarification, when we 15 talked earlier before, what we had intended to say is were certainly further along 16 in many utilities on where we are in this space. So our intent was to provide it as 17 a pilot information. Clearly as you or the rest of the staff review this, its 18 intelligence for you to use for insights on how you might solve the GI-191-99 path 19 rather than exactly duplicate. So our intent is to basically provide you all insights 20 that weve gained, so that you can use that knowledge in whatever method you 21 decide to do as you move forward. So thats what I would offer.
22 MICHAEL MARKLEY: This is Mike again. They are not a pilot at 23 this point in time. They have not requested anything officially; its just been a 24 discussion item for the prior meetings. Thats all.
25
27 JAMES POLICKOSKI: Any further questions on flow chart B?
1 Okay, go head Rich.
2 RICH KLIMCZAK: Okay. So now were going back to flow chart A.
3 Were going over to the left side; weve have updated seismic hazard information.
4 There is the deterministic ground motion spectra, and then theres the seismic 5
hazard curve; so now were over to the left. The seismic probabilistic risk 6
assessment: We consider this a confirmatory path -- you know, what this change 7
in seismic information, how does that impact risk? And, it will be used for a 8
safety risk assessment; it cannot start until the seismic hazard curves are 9
available. Note Four: seismic hazard curves are typically available within thirty 10 days. And typically this assessment as we go through it, will take about six 11 months to complete.
12 Well go to flow chart C now. Flow chart C, weve entered from flow 13 chart A. We have an updated seismic hazard curve and updated ground motions 14 spectral shapes. Note One: The seismic hazard curve and ground motion 15 spectral shapes are developed by PG&E Geosciences Department in 16 accordance with the current peer review methodologies. So, we get that 17 information when we enter this process, we would conduct a seismic probabilistic 18 risk-assessment analysis to determine the impact on seismic core damage 19 frequency, when we will use updated input information.
20 Note 3: Input information includes the seismic hazard curves, 21 spectral shape, and fragilities. And updated methodologies, Note 2 and 4. Note 22 2: The seismic probabilistic assessment will be based on a capability category 2 23 of ASME/ANC RA-Sa 2009 or the approved -- whatever the approved NRC 24 version of that is -- as modified by Reg Guide 1.200.
25
28 And Note 4: The fragilities would be based on the ground motion 1
spectral shape, and peer and current peer review fragility calculation methods, as 2
identified in the ASME/ANC standard out of the NRC-approved version, as 3
modified by Reg Guide 1.200 and those three [spelled phonetically] EPRI 4
documents for calculating fragilities.
5 When we complete that evaluation, we will notify the NRC and we 6
will, you know, document the results of all those, enter in the record. Turn back 7
to Flowchart A, and we would submit a peer reviewed, updated information to the 8
NRR. And after that, we would start the 10 year cycle again for updating.
9 ANNIE KAMMERER: So, if you went through -- let's say that you 10 went through and you -- and when you were doing your seismic PRA, you 11 determined that you were going to have plant modifications. Would you go 12 through, then, and also go back and re-do your margins assessment and provide 13 additional -- an update to that, based on the plant modifications as well, so that 14 all the information was coming in was consistent?
15 RICH KLIMCZAK: Yeah. We would -- if we modified that structure 16 system, we'd have -- that would impact Heathcliff calculations on the seismic 17 margin calculations.
18 ALAN WANG: This is Alan. I just had a question. So, can we go 19 back to Flowchart, I guess, B? You used the Shoreline Fault as an example.
20 There you would have said it was bounded by the LTSP, so you would go to the 21 right.
22 RICH KLIMCZAK: [affirmative]
23 ALAN WANG: So, if you went to the right, would you then conclude 24
-- if you were able to go to the right, would you then conclude that you meet on 25
29 your current licensing basis, your DE, Hosgri, and SSC?
1 RICH KLIMCZAK: We would conclude they are not impacted.
2 ALAN WANG: Okay.
3 JAMES POLICKOSKI: Let me pull that string -- this is Jim. Let me 4
pull that string a little farther. The thing that -- and again, we've had some 5
discussions -- into all the staff is that it's been -- relating the hazard to the 6
engineering has been our challenge. And, because this whole discussion is 7
heavily on hazard, and it doesn't rope in to the operability call, the engineering, 8
and the three earthquakes are, in essence, equipment performance criteria. And 9
what the equipment is allowed to do is different for each performance criteria and 10 where the hazards get closer, for example, whatever the new evaluated hazard 11 is, let's say Shoreline. And for example, the -- using the -- as you got to the right 12 side of the curve on your deterministic slide, there's points where because the 13 criteria for those three -- for the equipment performance criteria is the 14 engineering criteria of the hazard side, but the engineering criteria coming off 15 those hazards use different values in how they calculate the endgame of what 16 the equipment -- what the equipment had to respond to.
17 It makes it so that, yes, the hazard might have been worse, in this 18 case, for Hosgri or whatever. But because we're holding the equipment to a 19 tighter equipment performance criteria for, let's say, the DDE, then actually DDE 20 can become limiting. And that's been the hard part for us, is bridging the 21 assessment to the engineering and ensuring that how the SAR describes the 22 earthquakes, it goes from the hazard to the engineering. And then that's where I 23 see that main central diamond, where you end up making the call of operability; 24 because that's, in the end what the engineers are going to hand to the operators 25
30 on making that ultimate call, is whether the equipment will perform in the 1
2 NORM ABRAHAMSON: This is Norm, again. I think the 3
fundamental issue that we need to work out with you and understand NRC's 4
approach is when you get new information, new natural hazard information, what 5
do you with it?
6 Our fundamental approach is to say, What is the impact on safety 7
at the plant? It is not to go back and say, We re-designed the plant. That's not 8
the first thing you do. You look at the impacts on safety. If the impacts on -- if 9
they're -- let's say there are no significant impacts on safety. Then those old 10 design bases are still okay, because they are leading to adequate safety. All 11 right, that's the -- the goal is not to go back -- as I understand it and re-do your 12 design bases every time you get new information. You want to say, Does my 13 design basis lead to adequate safety? That's the fundamental question.
14 The way we address that is looking at what is the core damage 15 frequency; whether its a risk? And we look at the margins; so we're doing it both 16 ways in our analysis. But that doesn't change what the design basis was. It 17 stays the same. If that design basis leads to adequate safety, then those rules, 18 even though they were developed back in 1965, are still doing their job. If we 19 find they didn't give us adequate safety, then we need to do a revision, like in 75, 20 when they discovered the Hosgri, the old design basis wasn't covering 21 everything. And so, an additional design spectrum had to be imposed.
22 But the fundamental question ought to be impacts on safety, not, 23 Let me go re-do the design basis every time. And I think that's -- if -- we have 24 to get through that question or we're never going to solve this issue.
25
31 KAMAL MANOLY: So, you were saying earlier that if we have a 1
larger -- if you discover a new fault that has a major change from the LTSP, it will 2
invariably affect the margin and the seismic core damage frequency in a way that 3
will compel you to revisit your licensing basis. Is that what you're saying?
4 NORM ABRAHAMSON: Correct. And so -- I'll say -- and this is 5
Norm again. I'll try to keep putting my name in to make it clear to people on the 6
phone.
7 Fundamentally, if we find something that increased our core 8
damage frequency significantly, you know, so to a level that's not safe enough, 9
we need to -- you would shut down and make plant modification and then you, at 10 that time, would have said, My old design rules weren't giving me adequate 11 safety, so I now need to do something else, something [unintelligible]. And at 12 that point, you change your design basis or you add another one. You know, we 13 may -- whatever it's going to be, I just keep adding them on top each other. But 14 that's -- you have to get to -- if it's -- if there's agreement that the way you look at 15 new natural hazard information, its impacts on safety, then I think what we're 16 laying out can -- we can work out to achieve that. If you're saying, This seismic 17 information means you go re-do your design basis every time, then what's laid 18 out here doesn't do that at all.
19 JAMES POLICKOSKI: The one part, I guess, Norm. I follow your 20 point. I do. It's just -- you're separating the phrase impacts on safety and design 21 basis, as potentially mutually exclusive in how I asked the question. But the 22 license, in our respect, in terms of defining operability, that defines operability 23 and then -- safety could be -- operability might not be the ultimate margin you 24 have left; hopefully not. There's more margin on top of operability. But how we 25
32 define operability is with the license, and that's why I'm trying to make sure I 1
bridge it to what I know the license to be --
2 NORM ABRAHAMSON: Right.
3 JAMES POLICKOSKI: -- which is DE, DDE, Hosgri, and then 4
however Shoreline shakes out.
5 NORM ABRAHAMSON: This is Norm. So one more time I'll say 6
my piece here, as how I think things make most sense is that the -- when you get 7
new information, I think the question you're asking is, Does the current design 8
basis lead to adequate safety, given this new information? Is it still doing its 9
job?
10 Okay? So you can then be always checking how we met the 11 design basis and followed those rules. But -- it -- the basic question is: Did we 12 find some new information that shows that old design basis is not leading to 13 adequate safety? Okay, that's different than saying, Do we revise it? because if 14 I was going to build something new today, I would do it differently; that's a very 15 different question. And it would help us to know -- on your side how do you guys 16 see approaching this? We think the approach to GI-199 has been following the 17 approach of, Yes, there's the design basis. I'm not going to go re-do that. Is 18 that design basis leading to adequate safety as we review new information on 19 ground motion models or source characterization in the Eastern United States?
20 Right, but as opposed to saying, Every time something new 21 happens, re-do your design basis. You'll be in a never-ending cycle if you try to 22 do that.
23 JAMES POLICKOSKI: I have one more. But I'll defer to you, sir. I 24 don't remember your name, sir.
25
33 GOUTAM BAGCHI: My name is Goutam Bagchi. I just wanted 1
clarify on your question. Sorry, I don't pronounce your last name very well.
2
[laughter]
3 JAMES POLICKOSKI: It's common in my life. Don't worry.
4 GOUTAM BAGCHI: Mine is hard, too.
5
[laughter]
6 Norm has a point with respect to safety, but the operability issue is 7
not related to that. The operability will always be limited by DDE, as you pointed 8
out. What is the purpose of operability? If it doesn't operate, you go into the 9
NCO condition and then you can go back, and do your evaluation, and determine 10 if we approve your proposal, that this becomes your rule -- operability 11 determination basis, then you can do that operability determination and you 12 either proceed or you don't. That's, I think, a point we needed to review first, 13 based on what you just said. Thank you.
14 JAMES POLICKOSKI: Thanks, sir.
15 KAMAL MANOLY: I just -- a follow up on what Tom said. It's a 16 screening tool for operability. That's what he said.
17 JAMES POLICKOSKI: Right. Say that again, Kamal.
18 KAMAL MANOLY: It's that the screening tool for operability?
19
[speaking simultaneously]
20 LOREN SHARP: Yes.
21 KAMAL MANOLY: I'm asking, I --
22 MALE SPEAKER: I would say yes.
23 JAMES POLICKOSKI: Let me zero in more on that question and 24 then keying off the comment just made -- this is Jim again -- that I understand 25
34 how -- and I apologize for the gentleman -- is that Bill? Yeah. That stated that 1
you had -- that earlier, because that does reflect the history of the license was 2
developed, but there's one key thing: Is that what this flowchart doesn't make 3
reference to is at looking at also any impacts to whether the DE and more 4
importantly, the DDE still confines safety. And using your words. Because it is.
5 Does that -- as also part of the licensing basis -- determine if the plant is safe, 6
because it had different criteria that it is holding the plant to, that even Hosgri --
7 MALE SPEAKER: Yeah. Right.
8 JAMES POLICKOSKI: So, that's important is --
9 NORM ABRAHAMSON: This is Norm again. So, we would still 10 meet all the criteria for the DE, and for the DDE, and for the HE -- the 77 HE 11
[unintelligible]. Those are all met, I mean, so if we didn't meet those, then you're 12 clearly failing. All right? So maybe, I mean -- our assumption here is the 13 equipment and everything else has satisfied, all our systems, structures, 14 components -- satisfied the DE, the DDE, and the HE, with their allowables, all 15 right? Because they're in there now.
16 This is new information on the seismic loading. Does that change 17 it? And then so the fundamental question then is: Do you re-do your design 18 basis and start over again? And, so we would still do our -- the exact same 19 checks. I mean, you would be able to say, Have you satisfied the DE? Have 20 you satisfied the DEE? You may find conditions where those still are controlling 21 when you're doing design or replacing a piece of equipment. That will still 22 happen. But new information is really, again I'll say, my understanding is the 23 goal of treating of new information, deciding what to do, is looking at it in terms 24 of, you know, what are the impacts on your risk? Are things changing or not?
25
35 ALAN WANG: Yeah. This is Alan. I think that's one of our 1
questions, though, was exactly that: Is when you did your operabilities that you 2
compared it to the LTSP, and since it was bounded you were okay, our question 3
still was, is: Did you do those comparisons against the DE, the DE and HE?
4 NORM ABRAHAMSON: Right.
5 ALAN WANG: And if you did that, then I don't think we would have 6
a question about operability.
7 NORM ABRAHAMSON: Then we need to make that clear. Yes.
8 All right? So, all of these would --
9 RICH KLIMCZAK: No, I think what they're saying is with this new 10 information, did you modify your DE, DDE spectrum?
11 MALE SPEAKER: No.
12 MICHAEL MARKLEY: Did you evaluate against it?
13 RICH KLIMCZAK: No, no.
14 NORM ABRAHAMSON: We --
15 MALE SPEAKER: [unintelligible] Go ahead. I'm sorry.
16 MALE SPEAKER: DE, DDE and Hosgri: all those components at 17 this time are qualified to the criteria.
18 NORM ABRAHAMSON: So I think we can solve -- this is Norm 19 again. We can solve this very easily. If you would like to see this satisfying all of 20 those earthquakes, that will be fine. That should be no issue for what our chart 21 is. We see those as unchanged.
22 MICHAEL MARKLEY: Yes.
23 NORM ABRAHAMSON: And what we are looking at are things that 24 are changing. All right, so that the -- what we see is there's, let's say, higher 25
36 loading. How is that changing the safety of the plant, given its current design?
1 And that has met those other earthquakes. But if we put in here that we're going 2
to meet all those other earthquakes as is, that would sure makes things simple.
3 JAMES POLICKOSKI: I think one breakdown in communication --
4 this is Jim again -- could be that it almost comes across to me, and I can't say 5
you've necessarily said this, but let me get the question on the table: that DE 6
and DDE are, by definition, subsets of Hosgri and LTSP.
7 But the challenge it's been to us is that there are parts of the 8
spectrum where when they're translated to the engineering criteria against the 9
ASME code or whatever other criteria reins in, that because we're holding, let's 10 say, DDE by the grouping of the equipment groups or something, that it could 11 potentially be slightly harsher than Hosgri, for example. And that could make it 12 so that you can't just treat it as some Venn diagram of concentric circles. There's 13 somewhere -- there's some spillage potentially, when you get down to the 14 engineering, not just the hazard.
15 NORM ABRAHAMSON: So this is Norm again. And I would say, 16 Yes. We would completely agree with that. Our question or issue has -- that I 17 have been, let's just say, arguing with these guys as well, is that we do not revise 18
-- change the DE, the DDE. They are what they are. They're that certain level of 19 shaking with certain acceptance criteria [unintelligible]. They are fixed, okay?
20 We don't change them and we always satisfy them. What we're looking at now is 21 as we have new information, do we think that the design that resulted from that 22 design basis is still adequate? Is it still safe enough, because we have new 23 information that might change the frequency of earthquakes, or the loading rates, 24 or whatever.
25
37 ALAN WANG: This is Alan again. I -- so, yeah. Actually, that goes 1
back to my original question, because I said -- when you say it's -- when you go 2
to that first diamond and said it's bounded by the LTSP, did you go to the right?
3 And I had asked you, Does that imply that you meet your DE, your DDE, and 4
HE? And you said, Yes.
5 But does it meet that because it's bounded or does it meet it 6
because you actually did something to confirm that those things were met, that 7
those earthquakes are met?
8 MICHAEL MARKLEY: I think what we've been struggling through 9
here for some time is are there boxes or diamonds leading up to that, with each 10 one of those other design basis questions?
11 NORM ABRAHAMSON: I'll let --
12 ANNIE KAMMERER: Yeah, maybe the -- if I can express the way I 13 think about it, it can be maybe clear.
14 Okay, so the DE and the DDE are set ground motions. They are 15 what they are. The performance criteria that's tied to each of those are set.
16 They are what they are.
17 JAMES POLICKOSKI: Right, right.
18 ANNIE KAMMERER: So really what's changing, in a probabilistic 19 sense, is the return periods or the probability that those ground motions occur, 20 the DE and the DDE are changing as a result of the new information. But that 21 doesn't change what the actual ground motions are. But the license criteria is a 22 set ground motion and a set performance criteria. And I think that -- and, you 23 know, same for DE and the DDE. And what we're really looking at is new 24 information that's beyond those additional criteria.
25
38 So I think what we do need to do is get -- just have something in 1
here that says, Any existing license criteria remains an existing license criteria, 2
and this is an addition to it, because what I think is, maybe, is what is confusing 3
people is this inherent understand that the likelihood that the DE and the DDE 4
are seen is changing. We all kind of get that concept. But there are specific 5
ground motions that are deterministically based, and so how likely they are 6
doesn't play a part in a license itself. So, if we could just get that clarification in 7
here, I think that that would go a long way towards satisfying some of our criteria.
8 Because I think that there's confusion that maybe somehow, there's an 9
implication that that's not the case.
10 JAMES POLICKOSKI: I'm playing off -- this is Jim again -- off of 11 Alan's question. I understand that. And I separate them; I had the hazard from 12 the performance criteria. But I am really laser-guided on the performance criteria 13 and my question is that -- you're right your license says, the equipment -- thou 14 shalt do this. The pipes shalt hung there, it shall take up this much elastic or 15 inelastic loading and it shall respond thus.
16 And that's what I'm really focused on is, when you have a new 17 hazard, was it evaluated against those criteria of how the pipe hung on the wall --
18 of how much it's going to deliver to that pipe -- was that reassessed through 19 some modeling or something, where, as Alan was suggesting, there are boxes 20 that we don't see that are inside boxes, because that analysis, in essence, was 21 done. And that, it spits out a DE number, a DDE number, something where, yes, 22 that pipe -- we handled it at Shoreline, we hanged it at some, you know, new 23 seismic information and the pipe performed at the existing design criteria to that 24 pipe performs fine when we handled that earthquake. That's, I think, the hard 25
39 part for us is because it's not just the hazard, it's also the engineering.
1 LOREN SHARP: Rich needs to answer that.
2 RICH KLIMCZAK: This is Rich again. The answer is, No, again 3
because of what Annie was saying. We got new information, but that doesn't 4
change our DE or DDE spectra. [unintelligible] our criteria we used to code allow 5
[spelled phonetically] those [unintelligible].
6 JAMES POLICKOSKI: It doesn't change -- I agree, it doesn't the 7
spectra, because that's its license. But the equipment has to perform --
8 RICH KLIMCZAK: -- relative, to the new hazard.
9 JAMES POLICKOSKI: Relative to the hazards is our issue. And I 10 agree, the performance criteria didn't change either. But the variable now is the 11 new hazard. It has to be translated to how it's going to affect that point.
12 RICH KLIMCZAK: If you consider it a new hazard, you're going to 13 have to have impact on spectrum.
14 NORM ABRAHAMSON: This is Norm. Could you tell me what you 15 mean by there's -- to start with, for example, adding the Shoreline faults. It 16 doesn't change the DE spectrum. It doesn't change the DDE; they're what they 17 are. The allowables are what they are. So the Shoreline fault being there 18 doesn't do anything to the way that we do to meet the criteria for the DE, the 19 DDE, or the Hosgri spectra.
20 JAMES POLICKOSKI: I concur for what your plant was licensed to 21 for the pipes as built and as constructed. But now you have a new outside piece 22 of data that determine operability, and again I'm focused on operability, does -- is 23 that hazard present input that the engineering design cannot handle, in terms of -
24
- I'll just pick DDE in this case --
25
40 NORM ABRAHAMSON: But that's --
1 JAMES POLICKOSKI: But, I can't --
2 KAMAL MANOLY: I think I know what Jim is -- when you discover 3
the Hosgri, you evaluated the components --
4 JAMES POLICKOSKI: Right.
5 KAMAL MANOLY: -- through Level D, right?
6 JAMES POLICKOSKI: Yes.
7 KAMAL MANOLY: Essentially, right? So, I think that's what Jim is 8
saying. We have to evaluate it to some extent or level, and [unintelligible] Level 9
D. So, we still have to read Level D limits when we do the evaluation of 10 components, right?
11 GOUTAM BAGCHI: Can I clarify a little bit? This is Goutam again.
12 With respect to the seismic capacity evaluation, you don't go by any specific 13 code-required criteria. You go by an evaluation which says it will function based 14 on the fragility of the CDFM, conservative deterministic failure model, that's used 15 normally for the seismic margin. Those things have not changed and they are 16 what they are. They're capacity. But if the hazard curve changes, response 17 spectrum changes, and right where they were capable, it has increased 18 substantially, which is highly unlikely, then your capacity is no longer the same.
19 However, if it changes, you got another frequency, you could look 20 at that and determine that nothing has changed in your capacity. And I'll throw 21 out one more example. If this new fault comes much closer to a certain safety-22 related entities -- I don't want to clarify this anymore -- then your failure mode --
23 the common mode of failure effects are going to affect your seismic system 24 faultry [spelled phonetically] event sequences will change, and you may even 25
41 need to look at the system logic. I just want to leave it at that. The capacity is 1
capacity based on those response spectra. The response spectrum curve 2
changes substantially in an area where the equipment has natural frequency, 3
then it can be effected. Otherwise, not.
4 GREG HARDY: Let me see if I can add to that. This is Greg 5
Hardy, but -- let me step back and take you away from Diablo and just say this is 6
any plant, and they have two earthquakes they're designed to: the OBE and 7
SSC [spelled phonetically], which have different allowables that govern in certain 8
areas. I really don't view this as any different than any other plant. Much like GI-9 199, new information comes out that potentially could affect the plant and maybe 10 we believe earthquakes in this case are larger or maybe the criteria for 11 generating design -- some fragility aspect is changed.
12 As A46 happened, this has happened in the past, several times, on 13 an industry wide basis. And the solution is, as Norm said, to assess it -- and Jim 14 used the word 'as it hangs,' the pipe -- you're assessing the plant as installed.
15 Whatever your designed criteria is, it's agreed to license: boom. It resulted in a 16 certain condition of the plant, with a certain amount of strength, different levels of 17 margin.
18 And that's incumbent on us, then, with new information, to go back 19 and understand whether that affects the safety of the plant. As it stands, 20 whatever resulted in it, it's got a certain size anchors. They got a certain size --
21 certain type of re-label -- whatever drives the safety of the plant is now there and 22 you have to come back and understand whether the new information affects that.
23 So, for A46, for IPEEE people went back and did that, resulted in 24 maybe some upgrades, but it's not a design basis issue. Whatever it took to get 25
42 you there, that's what happened. Now, you've got to go and then evaluate it to 1
this new information. So, you get new information, you're going to have to do this 2
for GI-199. You're going to have to go through a process like this to do a best 3
estimate. As Goutam says, the capacity -- what you do to evaluate what really is 4
the failure is the level, what margin you need may not depend on any of those 5
criteria. All three of those that have changed over time -- the codes change --
6 you're going to use your best available information to do that evaluation now.
7 That's what you did to get the hazard. That's what you've got to do to get the 8
margin of fragility and you estimate your risk based on what the plant is today --
9 might have changed on what your design was. Maybe they've added new 10 system, new components. All those have to be taken into account and in order 11 to meet the standard -- either PRA or margin -- that's what you've got to do.
12 So, I view the design basis as how you got there, not how you get 13 out of it. You've got to address what you really believe the risk is and margin, 14 based on your best estimate of what the plant condition is in terms of what's 15 there, aging effects -- whatever happens, it's your, now, best estimate today.
16 KAMAL MANOLY: How do you define the demand?
17 GREG HARDY: How do you --
18 KAMAL MANOLY: Define the seismic demand?
19 GREG HARDY: Well, there's a whole process you've got to go 20 through, based on the new information. If a hazard changes, that sets the 21 demand. So you just -- like you would do in any PRA, you now have to set that, 22 generate it through some best estimate -- I mean, it does depend now whether 23 you're in a margin or a PRA, but there's two different set criteria and methods 24 you go through to get that demand.
25
43 KAMAL MANOLY: Or margin.
1 GREG HARDY: Well, you've got to set your earthquake and do 2
some kind of a best estimate response. You start off with whatever it is and go 3
through your best estimate response. You've got to go through soil-structure 4
interaction, got to go through the -- I mean, it's no different than it was. It's just 5
using state-of-the-art techniques to do it.
6 KAMAL MANOLY: But with new information you have a new 7
demand.
8 ANNIE KAMMERER: Right.
9 GREG HARDY: All right, say that again.
10 KAMAL MANOLY: With new information, you have new demand.
11 GREG HARDY: Maybe, yes. That's what you're checking. New 12 information can be less demand.
13 KAMAL MANOLY: Oh, yeah. But I'm assuming, obviously. If it's 14 lower than, it's not an issue.
15 GREG HARDY: Well, but there's all kinds of lower and upper, you 16 know. It can be higher and high frequency, and lower, lower frequency and --
17 KAMAL MANOLY: I understand.
18 GREG HARDY: -- you know what I mean. There's -- yes, you have 19 to assess it. And that's -- this flowchart describes that. You've got to go through 20 it pretty carefully to address all the changes and you have to step through the 21 whole process two different ways. I mean, this is unique to commit to do it twice, 22 two different methods, kind of, I guess, based on LTSP, there's some precedent 23 for having to gone through that.
24 ANNIE KAMMERER: Okay, so based on this conversation, let me 25
44 ask a question of the whole table, because maybe this gets to some of the lack of 1
understanding.
2 At least on my part, I'm not sure of the answer to this. So in the 3
licensing basis, okay, so you got these static ground motions, which are the DE 4
and the DDE. You've got a static performance criteria, right, and some sort of 5
vilinear [spelled phonetically] behavior is typically what we see in the SSC ground 6
motion. And you have to analyze the SSC, your structure systems components, 7
to assure that they meet the required performance criteria for that particular 8
ground motion.
9 The tools in which you do -- that you use -- the assumptions that 10 are made in that analyses are very important and I guess my questions is, one:
11 To what degree are those defined in the licensing basis, because perhaps part of 12 the confusion, or at least my confusion as well, is that say, for example, damping; 13 the kind of damping that you're going actually going to see naturally coming out 14 of the structure during a DDE level ground motion, which is much lower than, 15 say, what we would see from the highest grade ground motion. You're going to 16 see a lot higher damping inherent in the structure throughout that event.
17 So, I guess perhaps some of the confusion, perhaps some of my 18 confusion, is within the licensing basis, how much of that is defined such that we 19 can be assured that you're not going to use, say, damping that's more 20 appropriate for a Hosgri-type ground motion, to show that the DDE performance 21 criteria are met.
22 BILL HORSTMAN: May I? Bill Horstman again. In our license, we 23 defined the criteria and methodologies separately for each of the three 24 earthquakes. We have a tabulation of damping, based on material or structure 25
45 type. And then there's three categories. There's a value that goes with the DE, 1
there's a value for the DDE, and a value for the Hosgri. So we may have small 2
bore piping; DE is a half a percent, DDE is 1 percent; and Hosgri is, say, two 3
percent.
4 Now, if you've got a ground motion that's at a DE level, you know 5
the damping is lower. You can't take the Hosgri damping at two percent and then 6
apply it, ever, to the DE level-earthquake; but those always go together. The 7
same thing on allowables. You know, DE, we use 60 percent of yield strength; 8
DDE, we may use 90 percent of yield strength; and Hosgri, we use 1.0 times 9
yield strength.
10 So those methods and acceptance criteria always go with the 11 particular earthquake. When it came to long-term seismic program, the 12 acceptance criteria we used there to develop our capacities, the Heathcliff values 13 are based upon the seismic margins guideline, basically the EPRI, the NP-6041 14 SL report, that has median centered damping. It has 95 percent cophonous 15
[spelled phonetically] material properties.
16 So again, the LTSP, the fourth curve has its own acceptance 17 criteria, which is not the same of any of the other three earthquakes, but we 18 always keep those -- we don't mix and match between the criteria and the 19 different earthquakes.
20 JAMES POLICKOSKI: That's an important point. We do not hold 21 that your license is the LTSP. We hold your license is the three earthquakes.
22 BILL HORSTMAN: Yes.
23 JAMES POLICKOSKI: And the way you stated it was actually 24 pretty well. And, you know, from my read. And that they have criteria. And 25
46 rolling back to Annie's question, in the end, if new seismic information comes in, 1
it's going to produce what it's going to produce, but it has to be measured against 2
those three yardsticks you just described pretty well. Because that's your 3
license; that's how we define safety, for what it was worth at the time.
4 Now, it may not have been built by the best quality at the time, 5
because things have dramatically improved; and I understand that. And that's 6
something that probably is a topic for a separate meeting. But that's how we 7
understand the license and how we define operability for the moment. And I 8
understand you want to make this amendment, which in a lot of respect, is a lot 9
of goodness that I know the staff sees in what you guys want to include in the 10 amendment. But we also have to look at the license for what it is. We 11 understand what we're changing it from.
12 KAMAL MANOLY: Would you clarify, if -- would you classify this 13 amendment as introducing a tool for operability determination?
14 RICH KLIMCZAK: It's a tool to assess new seismic information.
15 KAMAL MANOLY: Well, yeah, but to determine operability, 16 because when -- typically, if you discover some new information about -- let's say 17 you discovered a component that you thought had a certain yield strength 18
[unintelligible] is lower, you will have to re-do your analysis based on the lower 19 yield strength, because you discovered you had an error in the CMTR or 20 something like that.
21 So here, you discovered new information but you said, I'm not 22 going to revise my licensing basis. So you're really using it just as -- for 23 operability.
24 GREG HARDY: No, [unintelligible]. You're really assessing the 25
47 safety. This has happened. You were involved in it. A46 and IPEEE; it's the 1
same issue and it wasn't the licensing basis and it wasn't an operability issue. It 2
was a safety issue. You determined that by a margin or a PRA.
3 KAMAL MANOLY: But A46 was to -- [unintelligible] that were not 4
licensed to IEEE -- 1970 --
5 GREG HARDY: Why was that? Because the methods changed.
6 Some of these plants were licensed without any real seismic considerations. Did 7
you go back and force them to change the -- you didn't evaluate their license 8
basis. That would be foolish. They really had no seismic licensing basis.
9 You did it to a criteria to assess whether it was safe or not. You 10 were required to bring them up and do some things in terms of mods, right?
11 Similar to this. Same with IPEEE -- it came on top of that. New information 12 became available, and that was primarily hazard, not just methods, in the IPEEE 13 case.
14 You did an evaluation, not to operability, not to the design basis. It 15 was based on that level of safety that you felt comfortable with and had to show 16 that. I -- that's got to be it, because Diablo has a more confusing history of their 17 design. Think of what you're saying and how that applies to other plants that had 18 little or no seismic design basis. You're going to let them off the hook for doing 19 nothing because they had not committed anything? You have to hold everybody 20 to the equal standard of safety.
21 MALE SPEAKER: Greg, excuse me. Oh, sorry.
22 JAMES POLICKOSKI: Well, I just -- this is Jim again. We've got to 23 watch how we used the word, How it impacts safety and operability, okay?
24 Those -- because impact safety is the end, the ultimate mission, okay, for, you 25
48 know, for us. But we also have a line where we put it in the license that our 1
immediate license line for safety, before we might require further analysis if that 2
line gets crossed, is operability.
3 And that's a critical line. And we defined it through these 4
yardsticks, which Bill described. And that's -- I understand the challenge and it 5
had some history here, and I respect that. But we all have to focus on what you 6
as Diablo are bringing and -- but that's -- that is the huge disconnect is how --
7 and I think why we're having an impasse in communication is that -- is we totally 8
understand that you have new seismic information, new hazard, let's say, that 9
comes in. But in the end, the yardstick is not LTSP; the yardstick, by which you 10 ultimately declare operability, is what the license states. I understand it may be 11 antiquated. I understand that --
12 NORM ABRAHAMSON: Could you explain to me, given the 13 Shoreline fault --
14 JAMES POLICKOSKI: Okay.
15 NORM ABRAHAMSON: What would you do to evaluate 16 operability? My DE or DDE, and my Hosgri, weve agreed are static in terms of 17 their spectra --
18 JAMES POLICKOSKI: Right.
19 NORM ABRAHAMSON: -- they're static in terms of their 20 allowables. So the Hosgri fault or the Shoreline fault has no impact on those 21 three design events and their criteria. So, what would we do different?
22 FEMALE SPEAKER: Incorporate the license amendment.
23 JAMES POLICKOSKI: Hosgri is part of the license as a special 24 case earthquake, yes. The -- I think what we -- in fact, even looking at the 25
49 reports you're giving us for Shoreline and -- is that it is a science assessment, in 1
essence, of the hazard. What -- and there's been previous items that -- of review 2
at Diablo, even recently, for certain pieces of -- I mean -- for certainly safety-3 related equipment, SSCs, that the limiting earthquake was not the Hosgri -- and 4
therefore --
5 NORM ABRAHAMSON: Could you tell me -- I hate to be really 6
specific --
7 JAMES POLICKOSKI: No, please.
8 NORM ABRAHAMSON: -- but what would you do differently --
9 JAMES POLICKOSKI: Right.
10 NORM ABRAHAMSON: -- because the Shoreline fault is there or 11 not. Okay, let's say I didn't have the Shoreline fault. You evaluate your piece 12 equipment against the DE with its allowables, the DDE with its allowables, the 13 Hosgri with its allowables, and the LTSP with its margin requirements. You do all 14 those and you meet it. Now you say, I have a new fault, the Shoreline fault.
15 JAMES POLICKOSKI: Right:
16 NORM ABRAHAMSON: How does that analysis change at all?
17 JAMES POLICKOSKI: I can give you a direct answer. The issue is 18
-- the question that has to be asked, in my opinion, and I'm not necessarily 19 polling, speaking for the entire NRC staff, is that the FSAR has to be evaluated, if 20 it is truly bounding in terms of your license condition -- in terms of your license.
21 If the FSAR is not bounding -- meaning you have found a hazard 22 that can cause a non-conservative impact in terms of the three criteria -- then 23 therefore, that hazard now --
24 NORM ABRAHAMSON: How do you do that? I don't even know --
25
50 JAMES POLICKOSKI: You've -- in my assessment, you have done 1
Step 1, which is evaluated the hazard.
2 NORM ABRAHAMSON: But, what do I do with the hazard? How 3
do I even tie it to a DE? The DE is a spectrum and a set of allowables. I don't 4
change that spectrum.
5 JAMES POLICKOSKI: My understanding is that, and actually, from 6
listening to you, especially the January 19 meeting, is you have equipment 7
groups that are very sensitive to specific areas of your spectrum. There's 8
probably equipment groups that are more sensitive than others in each band of 9
the spectrum and that those would probably have to be targeted to see if they 10 are, in fact -- is there a chance that the pipe that's hanging on the wall could be 11 effected worse in the Shoreline, since that's the example we were talking about, 12 than through the earthquakes, as licensed.
13 NORM ABRAHAMSON: And that's what we're doing. But when 14 we're doing that evaluation, we're using our -- what we're trying to say -- what will 15 really happen to it. Okay? And, so using modern estimates of the capacities of 16 the systems and modern estimates of the shaking. That's what we're saying, 17 here.
18 I'm still trying to figure out, do you want to make a change to the 19 spectral values used for the DE?
20 JAMES POLICKOSKI: It's not a matter of changing the spectral 21 values. You've been handed a new spectrum with Shoreline, for example. It is 22 what it is. And it is going to be different than DE or DDE. That just is what it is.
23 But it's going to cause the equipment to respond in its own unique way --
24 NORM ABRAHAMSON: Okay.
25
51 JAMES POLICKOSKI: -- depending upon where it is in the plant, 1
what spectrum, which frequency causes it the worst.
2 NORM ABRAHAMSON: But the allowables that we would use in 3
the evaluation would be the most up-to-date engineering practice, not --
4 JAMES POLICKOSKI: Is that meaning separate from how the 5
license was developed? Is that what you say --
6 NORM ABRAHAMSON: You have to say it because the license 7
goes with those damping values, go with the spectral values; they're a pair; you 8
can't separate them. Building codes -- you can't take one piece and say, I'm 9
going take something from 40 years ago and I'm going to shove it together with 10 something modern. They have to -- they fit together in a way that is 11 unseparable.
12 MICHAEL MARKLEY: It's Mike Markley. We've been on the same 13 question for 45 minutes. I'd like to hear the rest of --
14 NORM ABRHAMSON: They're all related to the --
15 MICHAEL MARKLEY: Yeah.
16 NORM ABRHAMSON: -- the same fundamental issue.
17 RICH KLIMCZAK: All the answers are the same.
18
[laughter]
19 ANNIE KAMMERER: I think people have to be careful too, to stop 20 talking about earthquakes and start talking about ground motions, because I 21 think part of the problem is that people think about these things as it being an 22 earthquake or fault or whatever, and that's not what engineering is based around.
23 It's based around ground motions.
24 ANNIE KAMMERER: So, if we could start with that change, I think 25
52 that would be really helpful.
1 JAMES POLICKOSKI: Okay, and I'm using a licensing phrase, 2
which is -- because the earthquake encompasses the -- all of the above. You get 3
everything with it, but the hazard and the engineering criteria behind it. And I'm 4
focused on the engineering here. And Norm, I apologize if I was unclear on that.
5 And -- but, it just -- I do agree with you to move on. Let me just get 6
this last question out. If we're going to talk about it in more clarity later, Rich, 7
then we can cover that. It's that -- I understand your point because it's a 8
licensing point too, but in the end, if the pipe has to be held to certain 9
parameters, it cannot elastically or inelastically deform but so much. Then that is 10
-- that's the building code, so to speak. And if Shoreline makes it do worse than 11 that, and then that's not good. That's how we look at it. That's the black and the 12 white part of operability, at least in my narrow view. I won't speak for the whole 13 staff here. But, you know, and that's the part that -- how do we know you did that 14 if, in those places where the pipe will perform worse compared to the building 15 code we held it to. That's the part we're having -- we can't see in your analysis.
16 KAMAL MANOLY: Let me try to take a shot at what he's trying to 17 say. I'm not too concerned about the Shoreline fault, but let's say that Shoreline 18 fault has spectrum that some above the LTSP. And he's saying, How do you 19 evaluate the components on a spectrum that's much higher here? I expect that 20 you're going to be doing -- using the same design rules for -- the highest one is 21 Level D, for ASME, right? Isn't it? I mean, correct me if I'm wrong. Whatever 22 reloading combinations for the highest level of loading? I mean --
23 RICH KLIMCZAK: What are the level -- what are the loading 24 combinations?
25
53 KAMAL MANOLY: No, I mean whatever the loading combination --
1 RICH KLIMCZAK: Right, right.
2 KAMAL MANOLY: -- you know, for Level D --
3 RICH KLIMCZAK: Theres a set of loading combinations to meet 4
Level D criteria.
5 KAMAL MANOLY: Whatever you've been using for in your 6
licensing, right?
7 RICH KLIMCZAK: Right.
8 KAMAL MANOLY: So, but isn't that -- isn't that the answer to his 9
question or -- I mean, I know you're not saying that. But I don't want to answer 10 for you?
11 BILL HORSTMAN: May I?
12 KAMAL MANOLY: Bill, go ahead.
13 BILL HORSTMAN: We use the Heathcliffs in the new information, 14 be it Shoreline or another earthquake. We come up with a new demand based 15 upon the new ground motion. We either use the same Heathcliffs we computed 16 for a long-term seismic program back in 88 or we update those, if necessary, if 17 there's a change in the spectral shape, so that it's more dominant in one 18 frequency, since the Heathcliff values are dependent on the average spectrum of 19 acceleration between 3 and 8.5 hertz, or how we define them.
20 If we re-define them, but we still follow the same rules. The rules 21 that are define the Heathcliff are based upon median damping, 95 percent 22 cophonous material properties, Level D allowables for ASME, certain increases 23 for that concrete code allowables, depending if it's a concrete structure or an 24 ASME structure. So those rules are implicit in the LTSP evaluation from 88 25
54 timeframe. And the ground motion definition should not affect those --
1 KAMAL MANOLY: I was trying just to clarify --
2 BILL HORSTMAN: Yes.
3 KAMAL MANOLY: -- Jim's question.
4 RICH KLIMCZAK: Yeah.
5 BILL HORSTMAN: But maybe another thing I wanted to mention --
6 which, I don't know, maybe it's kind of terminology -- that, you know, we keep 7
talking about operability and in a classic sense, at least to me, operability, you 8
look at when you have degraded or non-conforming conditions. Is something 9
broken or do you find, like, an assumption error or an analytical error? You 10 mentioned, you know, the incorrect CMTRs. So that's actually affecting the 11 physical condition of the plant. A new seismic hazard doesn't affect the installed 12 condition of the equipment in the plant. It's just a new, outside piece of 13 information.
14 JAMES POLICKOSKI: That is why I clarified that Norm's question 15 why the issue begins at the FSAR. Is the FSAR correctly bounding or not? And 16 if it is not, then it comes back to looking at the SSCs to verify, are they built to a 17 potentially hazard that was not included in your FSAR previously, but now you 18 realize the FSAR is not bounding enough for what the environment might be 19 handing the site, and that's how that changed.
20 The comment is well-taken. But still, it doesn't mean it gets 21 ignored; it means the FSAR is moderating the best starting point, because the 22 FSAR evaluate -- in terms of Chapter 2 and Chapter 3 -- the best known data at 23 the time.
24 ANNIE KAMMERER: Okay, I've been asking a question. I'm 25
55 getting different answers, so maybe we can clarify this as part of the problem.
1 After the LTSP, there was -- it was an evaluation for safety to a new 2
ground motion spectrum, which we've seen. Subsequent to that, was there a 3
license amendment such that now there are three licensing bases, or three 4
ground motions with their coupled performance criteria and assessment 5
methodologies in the license or not?
6 In other words, was the license ever modified so that it includes the 7
DE, the DDE, and the HE? Or was the HE just more sort of a safety 8
assessment that came after?
9 RICH KLIMCZAK: This is Rich. The license was amendment and 10 we have the three earthquakes: the DE, the DDE, and the Hosgri. And they 11 have their own set of acceptance criteria.
12 ANNIE KAMMERER: And was it then, was it defined as a ground 13 motion? Or was it defined as a ground motion resulting from a specific fault?
14 RICH KLIMCZAK: The ground motion -- in fact, the NRC and the 15 SSC are 78-34 and ASLB hearings said they met the criteria of the SSC Part 16 100. [spelled phonetically]
17 NORM ABRHAMSON: It was set as a ground motion.
18 RICH KLIMCZAK: A ground motion?
19 NORM ABRAHAMSON: Its a spectrum and its a ground motion, 20 and acceptance criteria.
21 KAMAL MANOLY: Let me just ask a simple question. In the -- info 22 conference, you guys mentioned that the Hosgri was downgraded to a very 23 different shape than whats shown here? Is [unintelligible]
24 MALE SPEAKER: Do you want to answer that?
25
56 LOREN SHARP: Yeah, I think that the answer is it's not the Hosgri 1
spectrum is still the curve shown that we have continued to judge ourselves 2
against, but what the research was done, recently in the Shoreline report, shows 3
that it -- the Hosgri itself -- if it were analyzed in today's world with today's 4
knowledge, would be the lower curve.
5 KAMAL MANOLY: Oh, okay. But you don't intend to change --
6 LOREN SHARP: No, we do not, no.
7 BILL HORSTMAN: It's -- let me say -- this is Bill speaking again. I 8
want to say something to Annie on this, maybe a little clarification for what Rich 9
said.
10 Okay, our license has three deterministic earthquakes with their 11 own acceptance criteria: the design, the double design, and the Hosgri. Now, I 12 don't think you were around for this, but the license condition from the Atomic 13 Safety and Licensing Board was we had to re-evaluate the plant over a 10 year 14 period for new information. So that culminated in the long-term seismic program 15 final report in 88, after the plant was operating. That was part of our license 16 condition. That's what's evaluated in Supplement 34 to the Safety Evaluation 17 Report.
18 So that's part of our license and that fourth earthquake has its own 19 acceptance criteria, the seismic margins criteria. So that's the dashed curve on 20 our figure there, which is independent of the Hosgri -- what we're calling the 77 21 Hosgri -- which is the one that the plant was retro-fitted for, prior to operation.
22 ANNIE KAMMERER: Right, but meeting the license condition 23 doesn't necessarily mean that your license -- it doesn't inherently change your 24 licensing basis.
25
57 BILL HORSTMAN: But we --
1 ANNIE KAMMERER: Your legal license [inaudible] --
2 BILL HORSTMAN: In our FSAR, after the license condition was 3
satisfied, we, be it as it may, we added in Chapter 2.5; there's a brief discussion 4
of the fact that we re-evaluated for the long-term seismic program. It references 5
the reports that were submitted and it references the NRC review and SSER34 6
[spelled phonetically] and that's discussed in Chapter 2.5 of our FSAR, in terms 7
of it being a seismic margins evaluation for the plant. So that at least introduces 8
the fourth earthquake. It was not through a license amendment process. It was 9
after the close out of license condition -- what is? 2.7 or 2.C.7 I think it is?
10 ANNIE KAMMERER: Well, then there's three.
11 BILL HORSTMAN: Yes.
12 ANNIE KAMMERER: Just because, [inaudible] license [inaudible]
13 JAMES POLICKOSKI: Okay, we're going to take a break here and 14 we'll recess until -- 10 til that clock right there on my left. That gives us 12 15 minutes and I know there's a suggestion to have an internal [unintelligible] -- So -
16 17 MALE SPEAKER: Yeah.
18 JAMES POLICKOSKI: Okay. All right, so we'll take a 10 minute.
19 For those on the phone, we will recess until 2: 50 Eastern Daylight Time. And if 20 you haven't signed in, please sign in. I think I have a -- you know, the sheets 21 here on the table are by the door.
22
[break]
23 JAMES POLICKOSKI: Okay. Thanks. We went a little long there 24 to our folks on the other end of the line. And we do have a few questions on our 25
58 end, but I do want to let Rich finish if you had further, more formal parts, of your 1
presentation.
2 RICH KLIMCZAK: I would like to say something before we begin 3
because we went through a lot of the same kind of debate outside of here that 4
we went through in here. And I think one of the things that would be really 5
helpful to us as we go forward -- I mean some of the classic terms that were 6
talking about safety and operability and how you walk through that. Maybe as 7
you proceed toward developing your actual submittal, that you clarify that 8
decision making process a little bit better would be probably very helpful and 9
even how youre evaluating the margins. Thats all.
10 JAMES POLICKOSKI: Did you have more formal -- I mean we sort 11 of hijacked there in the middle there and dug into the questions. It looked like 12 you might have had more formal news, Rich.
13 RICH KLIMCZAK: Yeah, this is Rich again. I do have responses to 14 all the questions. We can go through them. Okay, we kind of lumped questions 15 two, three and four together. We have a generic response to all three. Two is 16 clarification of how the LTSP analysis flow chart will be utilized to qualify new 17 plant equipment, perform plant modifications, perform condition evaluations and 18 are evaluating non-conforming degraded conditions with specific discussion of 19 the LTSP analysis and licensing basis relationship to existing design and 20 licensing basis of the operating basis earthquake and DCP, which is the OBE 21 which is DCPPD safe shut down, SSC, Diablo Canyon, DDE, Hosgri and 22 regulations from Title 10 of Part 50 Appendix Alpha, GDC 2, General Design 23 Criteria 2, design basis for protection against natural phenomena and 10 CFR 24 Part 100 reactor site criteria.
25
59 Question three, clarification of how results of the LTSP flow chart 1
either deterministic, probabilistic or both for LTSP evaluated ground motions 2
specifically relate to the three license associated and existing design ground 3
motion equipment performance criteria, OBE, SSE, Part 50 Appendix Alpha GDC 4
2 and Part 100. And four is discussion of how the LTSP analysis results will be 5
used in conjunction with the OBE, SSE, Hosgri, Part 50 Appendix Alpha, GDC 2 6
and Part 100 as a licensee basis for future licensing actions. So the way were 7
responding to that, were looking at the purpose of our flow chart is to evaluate 8
new, geologic and seismic data information and interpretations for impact on the 9
DCPP seismic design basis.
10 Were looking at that in two cases. One, we got a new determines 11 of ground motion spectra and its completely enveloped by the 1991 LTSP, just 12 as we discussed in flow chart. For that case, this new ground motion spectra 13 would not be used to qualify new plant equipment, perform plant mods, perform 14 condition evaluations or [unintelligible] graded non-conforming conditions. There 15 is no adverse impact on the original existing design licensing basis OBE and 16 SSE which is DEDD, Hosgri or our compliance to the Code of Regulations, Part 17 50 Appendix Alpha GDC2 or Part 100. The other case is when we have a new 18 determines of ground motion spectra which is not completely enveloped. We 19 have an exceedance in some frequency range. If -- as you saw in our process, if 20 the seismic margin acceptance criteria are met, were concluding the SSC has 21 sufficient capacity over demand to perform their safety function.
22 There will be no immediate impact on the qualification of new plant 23 equipment, performance of plant mods, performance of condition evaluation and 24 our non conforming degraded condition. A licensee then will be submitted to 25
60 address the impact on the SSEs and the frequency range of exceedance of the 1
1991 LTSP spectrum. The result of the license amendment may result in a 2
revised LTSP spectrum and maybe the Hosgri return on where the exceedance 3
is. And then once we get that license amendment, those amended spectrum for 4
LTSP and possibly Hosgri would be used for the qualification and new plant 5
equipment, plan mods, conditioning [unintelligible] and or evaluation of non-6 conforming degraded conditions.
7 There is a second part to the second case where, you know, we 8
have an exceedance of the LTSP and possibly Hosgri, is where we dont meet 9
the seismic margin acceptance criteria for 1.0 or greater or less than that. We 10 would have entered, you know, the applicable LCO, declared the NFSC 11 inoperable and at that time we would look at possible development of 12 compensatory measure for that, those impacted SSEs to restore that margin so 13 that we can meet that acceptance criteria. And again we would need a license 14 amendment because of the exceedance to resolve the issue.
15 KAMAL MANOLY: I have a question, just a clarifying question. So 16 if youre spectrum exceeds the LTSP sum frequency but you still pass the 17 threshold on the right and left side, would you request an amendment or not?
18 RICH KLIMCZAK: Yes.
19 KAMAL MANOLY: Even though you meet the threshold in margin 20 end [unintelligible]?
21 RICH KLIMCZAK: Because we consider that LTSP spectrum our 22 licensing basis.
23 KAMAL MANOLY: I see, okay.
24 RICH KLIMCZAK: And if we have --
25
61 KAMAL MANOLY: Im sorry, I understand. Im not saying I agree, I 1
understand what you are saying.
2 RICH KLIMCZAK: Any other questions?
3 ANNIE KAMMERER: OK, so based on the discussion that we had 4
during our caucus, I think that I understand where some of the confusion is lying 5
or some of the miscommunication. Lets say for example that the Shoreline fault 6
has not even been identified. That were going back to, you know, prior. I think 7
that theres an impression that its the viewpoint of perhaps some PG&E staff that 8
when youre looking at say new equipment or operability of the plant on a longer 9
term, ongoing basis, just day to day operations that theres -- that by checking 10 against the Hosgri ground motion and using all of the tools and allowables that 11 are associated with that, that that sort of somehow by default means that you are 12 going to be able to meet the performance criteria of the DE and the DDE.
13 And that, thats maybe more of a problem on a longer term basis 14 and that that impression exists and so that may have been leading to some 15 situations within in the plant prior to this. And so I think theres some misgivings 16 or maybe some lack of understanding that here -- what youre saying here, which 17 is a completely separate thing from the requirements that existed previously to 18 meet those three performance criteria before that really in practice only one of 19 them was being considered. And so that as were looking at codifying a new 20 license amendment that it really needs to be made very crystal clear that the 21 need to always check against those other criteria is ongoing, is separate any new 22 information that may be found. And so I think the inclusion of a very robust 23 description of that fact, that those three license conditions must always be 24 considered.
25
62 Not just the HE ground motion needs to be incorporated, because I 1
think that theres still an impression that its the viewpoint, again of some staff of 2
PG&E, not necessarily people here, that sort of if you can show that youre okay 3
in the [unintelligible] ground motions and the higher ground motions, that sort of 4
by default, you can sort of prove the others. And thats not the case and thats 5
the viewpoint of NRC staff. And theres some specific, I guess, examples where 6
that has been shown to not be the case where actually the more stringent 7
performance criteria for the DDE turned out to be the illuminating case. And so 8
we have to really, I think, clarify that in order to be able to do an amendment like 9
this.
10 RICH KLIMCZAK: Address the impact on the DE and DDE.
11 ANNIE KAMMERER: Well the fact that those, all those 12 requirements before are still in place, will continue to be in place. That all this 13 does is address new information.
14 MICHAEL MARKLEY: How its screened against those basically?
15 LOREN SHARP: Let me clarify a little bit. This is Loren. So 16 essentially what Bill Horstman and others have identified is that when were 17 doing new modifications or when were doing changes to the plant, what we have 18 always maintained is essentially that we would design a new modification to the 19 DE, the DDE, the Hosgri and the LTSP. We would look at all four of those 20 because we believe the way that we have implemented our process in such a 21 way that when the license condition was met, we committed to continue on and 22 do the LTSP process as part of our commitment to do that. So right now the 23 engineers are doing all four.
24 MICHAEL MARKLEY: And thats the understanding that we have 25
63 and didnt fully appreciate I think through all of the discussion.
1 LOREN SHARP: And again as we have agreed in the past, we are 2
just continuing down the path that we previously did, identified in 34 that when 3
we find the information, we were judging that new information for new insight 4
against the LTSP process we previously been reviewed and accepted by the 5
staff.
6 MICHAEL MARKLEY: Okay, good clarification.
7 RICH KLIMCZAK: Now I want to ask for a clarification, this is Rich.
8 So are you saying when we get new seismic hazard information that we have --
9 and the ground motion spectrum is developed, spectrums developed, that we 10 have to take that and assess it against the criteria for DE and DDE and Hosgri?
11 ANNIE KAMMERER: No, because the new hazard information 12 doesnt impact the DE and the DDE. It does impact the capacity and it does 13 impact those ground motions. I think the challenge is more that there is some 14 residual viewpoints from maybe in the past just in the ongoing operability rule 15 reviews or work thats been happening at the plant. But there hasnt been that 16 awareness, that there are actually all of these different review level ground 17 motions and theyre accompanied requirements.
18 So no, I mean, new seismic information does not impact what the 19 ground motions are for the DE and the DDE or what their requirements are or the 20 methods and tools that are used to assess them. Right? By definition it doesnt.
21 All it does is changes our perception of how likely those events are but thats 22 taking a probabilistic understanding into a deterministic world. Right, thats not a 23 part of the licensing basis but I think that theres, again, some residual hesitation 24 because of a view that that maybe that didnt always happen in the past, just on 25
64 an ongoing basis.
1 GREG HARDY: So this is Greg. This is actually clarifying 2
something that I didnt think wed get to but youre exactly right. If you separate 3
this from new information, what youre talking about is defining what your design 4
basis now is and how you do it. Then this is something on top of that for new 5
information which --
6 MALE SPEAKER: Right.
7 GREG HARDY: Maybe thats why we were so far apart. I still think 8
that its very clear to me how this process has worked. The NRC has, on every 9
case that I can think of, used this kind of safety risk implication to decide what to 10 do. So I think it does go back to the design basis, maybe theres a 11 misunderstanding or a misinterpretation or whatever to whats being done in 12 terms of all these earthquakes.
13 But again if you take it away from Diablo and take it into another 14 plant thats got an SSE and OBE, defining what you do and when the SSE 15 governs and when the OBE governs and when the two actually do that for any 16 new piece of equipment, that should be incumbent on the utility to do and define 17 it. And they should do it and if theyre not doing fine but it doesnt affect how you 18 treat new information. And hasnt whether its a real earthquake or a new hazard 19 or whatever it is, always that I can think of, youve used that kind of litmus test of 20 does it affect the plant safety and it may indeed end up affecting the licensing 21 basis but only after youve gone through that exercise.
22 MALE SPEAKER: Do you want to go on?
23 RICH KLIMCZAK: I cant let this go, sorry, Rich. So what Im 24 hearing -- because Annie you talked about theres maybe somewhere on our 25
65 side of the house people think that if were okay for the Hosgri, we dont have to 1
consider the impact on the DE or the DDE. In other word, how is it screened 2
against the DE and DDE? So and then I heard, it doesnt impact the spectra for 3
the DE and the DDE and that this new information doesnt -- so I got this new 4
Shoreline fault ground motion spectra, how do I screen it against DDE? I just 5
simply say, its new information for this process? Its not impacting the DE, DDE 6
qualification?
7 ANNIE KAMMERER: The requirements for your ongoing 8
operations to be consistent with their licensing basis in terms of maintaining the 9
equipment against the DE and the DDE performance basis remains. And your 10 information doesnt change the fact that you have to continue to maintain your 11 plant such that it needs to be licensed performance criteria.
12 RICH KLIMCZAK: We agree with that. I just want to be clear.
13 JAMES POLICKOSKI: Right and thats been part of the challenge.
14 ANNIE KAMMERER: Im not a license person, Im a seismologist.
15 So if Im not using --
16 JAMES POLICKOSKI: That point has been part of the challenge, is 17 the discussion focuses on LTSP which has a relationship to Hosgri but what it 18 doesnt do -- and the discussion is easy when youre trying to build a new -- put a 19 new mod in because going forward its easy. You have the three criteria and you 20 assess that mod. But when its reversed process, which is not a hazard change 21 potentially and youve already got existing SSEs sitting in your plant, its the 22 backwards path thats the challenge.
23 RICH KLIMCZAK: Right.
24 JAMES POLICKOSKI: And the screening, as Annie just put it, is 25
66 the challenge and what weve been presented is mainly an LTSP HG discussion.
1 What we didnt see is any of the work to insure that any performance criteria 2
against the DE and DDE was assessed. Its not that were saying the equipment 3
is self-changed, were not saying that because the equipment thats hanging on 4
the wall didnt change and the licensing basis itself did not change. Its is the F 5
star limiting or not because that describes the hazard your plant will face. And 6
then it could have a resultant impact of the ability for the equipment as built to 7
perform or not. And thats the challenge, its the backwards approach is the 8
challenge. The going forward --
9 MICHAEL MARKLEY: I think we can visualize what youre saying.
10 JAMES POLICKOSKI: [unintelligible] mostly on this and it may be 11 there and we just, some people dont see it. I maybe dont see it at times but 12 never the less I think its probably built into your process. But it needs to be more 13 conspicuous.
14 KAMAL MANOLY: Just one clarifying question, when youre buying 15 the equipment to replace all the equipment what -- levels of earthquake do you 16 qualify to only do [unintelligible] qualification?
17 RICH KLIMCZAK: This is Rich again. DE, DDE and Hosgri, if its 18 seismic category one --
19 KAMAL MANOLY: But not LTSP.
20 RICH KLIMCZAK: Theres a sub set of the equipment that we 21 committed to assessing impact on seismic margin.
22 KAMAL MANOLY: So some will require qualification for LTSP and 23 some dont?
24 RICH KLIMCZAK: Thats correct.
25
67 KAMAL MANOLY: What -- would make one go versus the other?
1 RICH KLIMCZAK: That was developed in the LTSP program and it 2
was primarily the SSEs that impact seismic risk that had a seismic margin of 3.0 3
G or less.
4 BILL HORSTMAN: Heathcliff?
5 RICH KLIMCZAK: Heathcliff? [unintelligible]
6 BILL HORSTMAN: Bill Horstman speaking again. Our criteria for 7
new equipment or modifying existing equipment, we have a list of components 8
that came out of the LTSP evaluation, the seismic margins evaluation and the 9
seismic PRA that were considered the high contributors to risk or core damage.
10 And they used the cutoff of anything which had [unintelligible] low probability 11
[unintelligible] of capacity of less than 3Gs but where our deterministic demand is 12 1.94Gs, so its basically anything with less than a 1.5 over that demand. We said 13 if we change that, weve got to look at that. So when we get a new breaker that 14 we have to shake table test, we do a DE shake for the number of five OBE levels 15 and then we do the SSE level and then if we can we actually do a margin, a load 16 to failure or to the limit of the table.
17 So well say, Okay its good for, you know, 5Gs and that qualifies it 18 for the Hosgri, and then we crank it. And okay, it doesnt break, so we get up to 19 6Gs, we get up to 7Gs. We try to do that, we do fragility tests if its possible on 20 the equipment. Otherwise well do a fragility analysis, well have it done 21 analytically if we cant actually fragility test the component. But thats only on the 22 ones we identified in 1991 as the limiting combone [spelled phonetically] as the 23 contributors to seismic risk.
24 KAMAL MANOLY: But thats all in your current procedure, so that 25
68 has nothing to do with the amendment youre proposing.
1 BILL HORSTMAN: No, we are not changing that, were clarifying.
2
[unintelligible]
3 JAMES POLICKOSKI: Go ahead, Rich.
4 RICH KLIMCZAK: Theres two final questions. Question five, 5
discussion of how the LTSP analysis flow chart will be utilized in the performance 6
of future operability determinations to include specific discussions on the 7
employment of each side of the LTSP analysis flow chart. I believe we answered 8
that by going through the flow chart.
9 JAMES POLICKOSKI: And youre talking about the bravo --
10 RICH KLIMCZAK: [unintelligible]
11 JAMES POLICKOSKI: With the kick out to the left on the --
12 RICH KLIMCZAK: Right.
13 JAMES POLICKOSKI: -- grade to the 1.0.
14 RICH KLIMCZAK: Right. And the last question for the Shoreline 15 fault in future unevaluated seismic ground motion clarification of how the 16 American Society of Mechanical Engineers Boiler and Pressure Vessel Code 17 allowables for safety related structures and components are being evaluated for 18 exceedance for OBE, SSE, DDE, Hosgri and the LTSP ground motion specter is 19 not immediately or only marginally bounding and safety related SSEs are 20 relevant in the applicable primer range. So for our answer for the case where 21 1991 LTSP ground motion spectra is not bounding the new ground motion 22 spectra, the effected SSEs, seismic margin is compared to our seismic margin 23 acceptance criteria.
24 That seismic margin evaluation method utilizes static capacity 25
69 equations for components for ASME covered components based on ASME 1
section three service level D limits which is the faulted values. The ASME code 2
allowables for DE, DDE and Hosgri are unchanged by this evaluation process.
3 Changes to the ASME code allowables for DD, DDE and Hosgri would require a 4
license amendment.
5 KAMAL MANOLY: It changes as we record levels?
6 RICH KLIMCZAK: This is asking -- the question was asking 7
whether they change and Im saying no.
8 KAMAL MANOLY: Ive never seen amendments requesting 9
changes at recorded levels.
10 RICH KLIMCZAK: I know, well I mean were not intending to, I 11 want to answer your question.
12 JAMES POLICKOSKI: Thats not what the question asked.
13 RICH KLIMCZAK: What did the question ask?
14 JAMES POLICKOSKI: It did not say, Would you change the code 15 allowables? It is saying how would you evaluate if you were not bounded or 16 marginally bounding for those things. How would it be evaluated in terms of 17 whether you have exceeded the code, because thats also another part that we 18 havent actually seen in your analysis, how you handle whether the code 19 allowables are exceeded or not.
20 RICH KLIMCZAK: Again, our seismic margin process, which we 21 are using for our criteria whether we have operability or not for ASME code 22 components utilizes level D limits.
23 JAMES POLICKOSKI: Okay, how is that analysis propagated to 24 that level so that it could be reviewed?
25
70 RICH KLIMCZAK: To the level of the DE, DDE and Hosgri?
1 JAMES POLICKOSKI: Right. I mean is that something that is 2
going to be inspectable, viewable?
3 RICH KLIMCZAK: Based on our previous discussion, our 4
clarification of how this process impacts DE and DDE would have to cover that.
5 JAMES POLICKOSKI: You mean something that youre going to 6
incorporate in this amendment is what youre saying.
7 RICH KLIMCZAK: Yes based on this, you know, as you pointed 8
out, this methodology that were proposing only talks about the LTSP and the 9
Hosgri. It does not talk about the DE and DDE. Hearing what you have told us, 10 we need to talk about how this process impacts those and along with that, that 11 would have to address that question.
12 KAMAL MANOLY: I guess you want to --
13 ANNIE KAMMERER: Are we done? I have a question, what 14 happened to the Delta CDF on flow chart C?
15 NORM ABRAHAMSON: We had decided, based on some other 16 discussions that this was not -- that was a number that was causing you guys a 17 bit of discomfort. That we would put a formal risk based number that we would 18 be trying to go after. So here we have left it in terms of looking at what the risks 19 are and well basically let you know and work through what has to be done if the 20 risks have gone up or gone down. So well report them to you, so that youll have 21 them available but we didnt want to set a number that said exactly, If were 22 below this number, were not going to do anything.
23 LOREN SHARP: This is Loren. We listened to you very well. We 24 understand that youre not risk based, that youre risk informed. So we try to 25
71 keep it that way.
1 ANNIE KAMMERER: So now youre going to determine a CDF and 2
presumably youll pull the Delta CDF pretty easily out of that and then youre 3
going to provide that for us. And then were going to see what we think about it 4
versus you guys having a hard number. Thats the change in the process.
5 NORM ABRAHAMSON: Correct.
6 JAMES POLICKOSKI: Is that per go around or with the 7
amendment? I missed how you were going to provide it to us. Is that hard and 8
fast in the amendment or per evaluation that that gets notified to NRC in the next 9
block?
10 RICH KLIMCZAK: This is Rich, per evaluation.
11 JAMES POLICKOSKI: Okay.
12 RICH KLIMCZAK: And the license amendment, both.
13 JAMES POLICKOSKI: Oh, so you will have a number in the 14 amendment?
15 RICH KLIMCZAK: No, no, not in the amendment because until its 16 our licensing basis then we have to include it. So only in the updates of the 17 seismic PRA we would have those values.
18 JAMES POLICKOSKI: Per evaluation, not in the amendment, 19 thank you.
20 RICH KLIMCZAK: Right.
21 JAMES POLICKOSKI: I know there was additional question.
22 Kamal, Ill turn it over to you in the 1.0.
23 KAMAL MANOLY: Yeah, I guess I want more discussion on that 24 number 1.0. I think [unintelligible] expressed their views earlier. You guys were 25
72 kind of contemplating different numbers and now you bought it down to 1.0. And 1
I guess we have some level of discomfort about that number.
2 RICH KLIMCZAK: Are you comfortable with the 1.0 for operability 3
criteria to conclude the SSE can perform --
4 KAMAL MANOLY: [unintelligible] in the SCR, I mean, I dont have 5
it in front of me so, whatever is written in the SCR, it is what it is, read the 6
English.
7 RICH KLIMCZAK: Right.
8 ANNIE KAMMERER: What wed accept in 1991 and what wed 9
accept today are not necessarily the same thing. I mean this is a determinate 10 notification that were accepting that this is sort of a permanent licensing change 11 versus you know, that we have time to think about a priority and work through the 12 implications. And I certainly again not being someone who works on margins 13 world a lot dont necessarily understand all the implications. Ill have to go back 14 and read the SSCR 34 but, you know, to be in situation where this, all of a 15 sudden this Hosgri, you know, seismic zone comes up and being in that situation 16 versus deciding something 20 years later, that this is a number we can live with 17 permanently. And that also other plants are going to look towards for guidance I 18 think we have to, we as the NRC staff, I think we need to look -- by the way, Im 19 not saying my name. Im assuming since Im the only female voice that you can 20 figure out whos talking.
21 NORM ABRAHAMSON: This is Norm. Annie, we will provide the 22 NRC with the risk calculations so that you can make your judgments. This was --
23 we were trying to set something where if we have new information we need to 24 make an immediate decision, is this such a safety risk we shut down or not.
25
73 Thats really what were talking about here, as opposed to saying, Okay, its 1.0 1
and were never going to look at anything more. This doesnt mean the 2
evaluation stops, right, because the risk calculation still goes through. So if the 3
risk numbers are not good enough, you would still need to do something to bring 4
the risk values down so that theyre small. This is --
5 ANNIE KAMMERER: Right, right, but thats sort of saying that the 6
margins assessment, well this is exactly what youre saying, the margins 7
assessment is only for operability. But I mean thats basically what youre saying 8
and I think that we just need to think about that a little bit. Or at least I need to 9
think about it a little bit more because youre basically going from a deterministic 10 basis to where, you know, its just for operability to where youre really making 11 your decision in term of modifications or anything like that to the plant in a 12 probabilistic risk role. Of course, thats the world that I live in so Im comfortable 13 with that but because, I think, at least for my own edification I need to dig into it a 14 little bit more.
15 MICHAEL MARKLEY: I think the burden is to explain why youre 16 picking what youre picking. You had a justification and a rational and an 17 analysis supporting the prior number you bought and now you have an obligation 18 to provide the same for whatever new numbers relative.
19 KAMAL MANOLY: When [unintelligible] and the plant evaluated for 20
[unintelligible] point 3G and Laughlins [spelled phonetically] SSE was much 21 lower. So it was a lot of [inaudible].
22 GREG HARDY: It wasnt operability though, I mean thats not 23 shutting the plant or not if you find youre below that RLE. This is sort of a 24 different piece of the puzzle that theyre talking about here.
25
74 KAMAL MANOLY: I keep going back to you saying that this is 1
really my operability call. Thats what you are saying.
2 GREG HARDY: Thats what were doing. [unintelligible]
3 JAMES POLICKOSKI: Norm, just one quick question, this is Jim.
4 Are you separating whether we have to shut down or not from entering an LCO 5
or are you just saying that for clarity of your point? I noticed you said that a 6
number of times when in essence that kicks you out to an LCE or are you trying 7
to separate an immediate safety question to the health and public or are you 8
meeting operability LCO?
9 NORM ABRAHAMSON: The whole operability, so not --
10 JAMES POLICKOSKI: Okay.
11 NORM ABRAHAMSON: Its really though trying to do something 12 on the very short term, what do we have to do as opposed to weve got some 13 new information, weve looked through the risk which takes a longer time to run 14 through all that analysis. And as you mentioned, nobody else is trying to do a 15 dual approach, right. They either do the margin or they would do the 16 probabilistic. And we wouldnt advise that this be the only criteria and you dont 17 have to do the probabilistic. The other question is how else could we do an 18 operability assessment with new seismic information because that was part of 19 what we were being encouraged to try to come up with an approach with that and 20 this is the approach that weve come up with right now.
21 ANNIE KAMMERER: I would encourage you in the documentation 22 discussion of the fact that this is -- that the margins now is moving into operability 23 space. And it really is that decision is being made because this is a two part 24 process, I think you would do the industry a big service by making that very clear 25
75 that that in and of itself is not enough. That this really is part of a more holistic 1
approach.
2 NORM ABRAHAMSON: Okay.
3 JAMES POLICKOSKI: All right, weve gone through the agenda, I 4
appreciate that Rich. I just want to insure for formalitys sake that we covered 5
that and sense that we also got some nuances off there. Is there any media 6
questions because I do need to give some time to our Region Four brethren as 7
well as the public? Is there any media questions on the topic? Look around the 8
room. Okay, Ill turn the floor over to Region Four or the site, is there any 9
questions from Region Four or the site from the NRC staff?
10 MICHAEL PECK: Michael Peck from Diablo.
11 JAMES POLICKOSKI: Go ahead Michael.
12 MICHAEL PECK: Hi, I have a question on operability. Of course 13 the site inspector operability is a process that we look at to insure that theres not 14 an immediate safety question or immediate safety issue. And so Im looking in 15 front of me at the deterministic comparison that was part of the hand out and I 16 just, I guess Im going to ask PG&E just to step me through a specific example.
17 So if I look at a component on the reactor, the reactor head, which we spend a lot 18 of time looking at a similar metal weld and we know that for the reactor to be 19 operable in other words to maintain the integrity during an earthquake combined 20 with an accident, we say it has to meet the code allowable stresses associated 21 with that.
22 And we know that from our reactor head inspection that the double 23 design earthquake is more limiting than the Hosgri for that particular case. And 24 we know that the no design earthquake had a peak round of acceleration of 25
76 about.4G. So now if I go here and I look at for example the San Luis Bay 1
spectrum thats one this comparison, this margin comparison to the Hosgri, I see 2
thats about 60 percent higher or has about a 60 percent higher peak ground 3
acceleration than what was used to demonstrate that this particular weld could 4
hold together during an earthquake. And so from an immediate operability 5
perspective using this proposed process, how can I feel comfortable that this 6
earthquake, this new information, in this case the San Luis Bay earthquake, if it 7
should occur, that that would induce greater than the code allowable stress on 8
this particular weld?
9 RICH KLIMCZAK: This is Rich. So following our process, the way 10 our license amendment process works, we would again follow through with this 11 new ground spectra, compare it to the LTSP, consider any impacts on the 12 Heathcliff values and assess the impacts against the seismic margin of 1.0 to 13 determine any impacts on the plants SSEs to perform their safety function.
14 MICHAEL PECK: Just to follow up, the long term seismic program, 15 did it include all the SSEs that were required to be qualified for the double 16 design? And I say that because I know that not all seismic class one SSEs that 17 were qualified for the Hosgri were also -- excuse me, all the SSEs that were 18 required for the double design were not required to be qualified for the Hosgri.
19 So the long term seismic program with the H cliffs, would that include all plant 20 seismic qualified equipment or just those associated with the Hosgri event?
21 RICH KLIMCZAK: This is Rich again, the components for the 22 LTSP were the ones that impacted seismic risk of the plant and are your major 23 structures, containment building, ox building and major components, diesels, 24 safety injection pumps, those kinds of things.
25
77 MICHAEL PECK: And one last question.
1 JAMES POLICKOSKI: Michael, hold on a second.
2 MICHAEL PECK: The safe shutdown earthquake is defined by our 3
regulations requires that equipment that either prevents or mitigates an accident 4
has to be -- remain functional following the accident. And part of the way that the 5
code accounts for that is it includes the loading on equipment, not only from the 6
earthquake and the dead weight but also the loading combinations including that 7
of the loss of coolant accident. The Hosgri is accepted as an exemption from 8
that accident loadings. It just assumes the earthquake and not the accident. So 9
when Im looking at this margin curve against the Hosgri design spectrum, does 10 that margin curve when youre looking at the H cliff, does that include the 11 accident loads or does that just include the loading associated with the Hosgri 12 earthquake?
13 RICH KLIMCZAK: This is Rich again. I dont know the answer to 14 that off the top of my head.
15 MICHAEL PECK: Thank you.
16 JAMES POLICKOSKI: Any clarification, you guys can provide later 17 I guess.
18 RICH KLIMCZAK: Pardon me.
19 JAMES POLICKOSKI: This clarification you can provide later?
20 RICH KLIMCZAK: Yes, well have to look into that to get back to 21 Michael.
22 JAMES POLICKOSKI: OK, I did have one clarification question of 23 what Michael just asked. LTSP is based on risk based equipment groups only?
24 Is that what I understood you to say for PRA?
25
78 RICH KLIMCZAK: The set of components that are modeled in 1
PRA, right.
2 JAMES POLICKOSKI: Only, not the deterministic group of SSEs?
3 RICH KLIMCZAK: Not all of them.
4 JAMES POLICKOSKI: OK, all right.
5 ANNIE KAMMERER: And those were identified through the PRA 6
that you guys undertook that started the LTSP?
7 RICH KLIMCZAK: That is correct.
8 ANNIE KAMMERER: I know that, as I recall, you were going to be 9
reviewing or revising your PRA. So are you going to look at that as potentially 10 informing the potential that there might be more equipment that should be 11 incorporated in the list? Right because it is came out as the critical equipment 12 out of the original PRA and youre going to be redoing your PRA, presumably you 13 may be able to find some new accidents sequences or some things that you may 14 feel is important and might identify new equipment particularly in light of, you 15 know, some recent developments.
16 JAMES POLICKOSKI: Nathan, could you answer that?
17 NATHAN BARBER: Nathan Barber. Were at this point starting a 18 gap assessment process on our PRA.
19 JAMES POLICKOSKI: Could you speak up just a little bit?
20 NATHAN BARBER: Sure, were starting to perform a gap 21 assessment on our PRA that includes our system response models as part of 22 that gap assessment if we identify anything that would result in new PRA 23 modeling than we would include those in the PRA model. And I would assume 24 that they would be included in our LTSP for our methodology going forward.
25
79 JAMES POLICKOSKI: Are you implying that the goal is that to 1
have that gap analysis complete for the amendment or -- I want to make sure I 2
understood that.
3 NATHAN BARBER: Its going to be as I understand it, proceeding 4
in parallel with the licensing amendment. So by the time -- we are granted the 5
license amendment, we would have that PRA available.
6 JAMES POLICKOSKI: Okay, so theyre connected but its not 7
necessarily in the amendment. Youll make reference to it in the amendment, 8
Okay. Thank you. Any other comments from NRC staff Region Four site?
9 Questions?
10 MICHAEL PECK: Just one more question if I could. On this 11 deterministic comparison -- this is Peck at Diablo -- shows that theres margin for 12 the long term seismic program to the Hosgri spectrum that also demonstrates 13 that the re evaluation of the three earthquakes show margin to the long term 14 seismic spectrum. Would it be possible to get a comparison also with the new 15 earthquakes with the double design earthquake to demonstrate, you know, 16 where that is in terms of margins?
17 NORM ABRAHAMSON: Yes. Thats what you question is? Yes.
18 MICHAEL PECK: Thank you. I havent been able to find a 19 spectrum for the double design.
20 JAMES POLICKOSKI: I want to make sure that I know what just 21 got yesd. Okay, so he asked for, go ahead.
22 NORM ABRAHAMSON: This plot here, so our spectra plot, he 23 wants to see the double design earthquake compared to these.
24 JAMES POLICKOSKI: Okay, Ive got it. And Norm, you said you 25
80 were willing to do that, okay, on deterministic comparison plot, okay. Any other 1
questions, comments from Region Four NRC staff?
2 Okay hearing none, Ill turn it over to our members of the public and if you can 3
just, again, state your name for the record so we understand whos speaking and 4
then go ahead with your question. Not sure who we have out there.
5 JANE SWANSON: Jane Swanson, do you hear me?
6 JAMES POLICKOSKI: Yes, maam. Go ahead, Jane.
7 JANE SWANSON: OK, I have one question and I will sound like a 8
lay person, because I am, but I didnt hear any talk or have not seen anything in 9
writing about plans to do thorough studies of the San Luis Bay fault or the Los 10 Osos fault. You know, all the studies on Hosgri and Shoreline are appreciated by 11 members of the public but are there plans to do similar studies on those other 12 two faults?
13 NORM ABRAHAMSON: This is Norm and the answer is yes.
14 There is a plan thats going on right now for onshore geophysics for the Los Osos 15 fault and theres additional 3D work being done for the offshore part of the San 16 Luis Bay fault and an onshore for the San Luis Bay fault will be captured by those 17 same seismic lines that are mainly geared on covering Los Osos. So yes, that 18 work is beginning, I think the planning is starting this year and well probably be 19 conducting some of the surveys, they should be started by next year.
20 JANE SWANSON: Is there --
21 NORM ABRAHAMSON: I [unintelligible] I have to always, you 22 know, we have to get the permits to be able to do it, but we have budgets and 23 plans to do them assuming the permits come through.
24 JANE SWANSON: Okay, so it sounds like you cant predict when 25
81 those would be completed, just when theyre going to start. Is that correct?
1 NORM ABRAHAMSON: Thats -- they generally if we have 2
permits, they should be completed within a year.
3 JANE SWANSON: Thank you.
4 LOREN SHARP: But that, this is Loren, that is a key piece. Once 5
a permit is issued, that we cant predict that time frame nor what Norm is saying.
6 It would be done after the permit is issued.
7 JAMES POLICKOSKI: And Norm just for clarity, what groups are 8
involved in that work you just said?
9 NORM ABRAHAMSON: This is being run by the Geo Sciences 10 Department and so well --
11 JAMES POLICKOSKI: PG&Es?
12 NORM ABRAHAMSON: PG&Es Geo Sciences is coordinating the 13 work and still seeing bidders, you know, bids to do those surveys.
14 JAMES POLICKOSKI: Say that last part again.
15 NORM ABRAHAMSON: Its open bids for --
16 JAMES POLICKOSKI: Open bids, oh, Ive got it.
17 NORM ABRAHAMSON: For doing the surveys.
18 JAMES POLICKOSKI: Okay but its going to be under your 19 contract, okay.
20 NORM ABRAHAMSON: Correct.
21 JAMES POLICKOSKI: Okay, go ahead, Im sorry Annie.
22 ANNIE KAMMERER: Im sorry, I was just going back over my 23 notes and I realized that I didnt ask one question that was a follow up from the 24 very, very beginning which is the question of significant, because you responded 25
82 to Kamals question basically, you know, theres some of course ways you could 1
know, you could tell kind of quickly like what moves a needle and what doesnt.
2 But you know, starting down this path you necessarily -- once you start down it 3
by the time you get to the end, youve done a bit of work, right and so is there, 4
what would be the process if NRC staff believe that something has been 5
identified that maybe significant like maybe -- whatever, maybe its some new 6
information found out about Los Osos. And you guys say, well, we dont think its 7
significant and we do. What would the -- and maybe this is to both sides of the 8
table, what would the process be then for NRC staff to initiate this check?
9 JAMES POLICKOSKI: Ill quickly answer that because theres a 10 method, theres a number of avenues we can go, confirmatory action letter, an 11 order, theres many paths depending on how significant we see the issue, how 12 immediate threat to public health and safety. We have a bunch of legal paths 13 that can very much drive the licensee or it could just be an inspection space 14 where were in operability review and it could be purely in violation space. It 15 could run that gamut from inspectable issue and violation that there is margin 16 remaining, we felt they were not conservative all the way to potential shutdown 17 order. It can run the gamut. Its hard to even guess.
18 MICHAEL MARKLEY: But the bottom lines is safe operation of the 19 plant is licensees responsibility.
20 JAMES POLICKOSKI: Right.
21 MICHAEL MARKLEY: I dont want to short change the publics 22 opportunity to chat here either because weve had plenty of time for ourselves.
23 JAMES POLICKOSKI: Okay, sorry Jane. I hope we didnt cut you 24 off. Did you have a follow up?
25
83 JANE SWANSON: No, thank you. My question was completely 1
answered. Thank you.
2 JAMES POLICKOSKI: Okay, any other folks from our 3
teleconference? And again just a reminder to the folks, I know you can hear me 4
on the webcast but you cant yell at your computer screen, you have to talk on 5
the teleconference. Any other questions from the public? I dont want you all to 6
lose out. Okay, Annie, did you have a follow up. Public, Ill check back with you 7
in a second. Annie, did you have a follow up?
8 ANNIE KAMMERER: Yes, in terms of all the different processes 9
that you just mentioned, given that this isnt whats going to be a somewhat 10 unusual licensing element, is there any clarification that needs to be made to 11 make all those processes consistent? Or is the fact that, as Mike said, if theres 12 any [inaudible] that comes up, the processes fall into place no matter what or I 13 just want to make sure that if there is something that we need to bring up now in 14 terms of that, that we do.
15 JAMES POLICKOSKI: To be clear, our processes are -- other than 16 the fact that were, you know, once we receive this amendment request and we 17 process it and we codify in their license, that has no specific bearing on actions 18 we can take on our own with the code, Ill grant somewhat our own policies allow 19 us to do as the license holder. Yes, public health and safety is ultimately their 20 responsibility in running their plant, but we as the oversight regulator have a 21 number of paths. But it doesnt mean that theres no caveats in their amendment 22 that they would submit to that because our policies exist over and above that as 23 backed up by the code. And Im not trying to be wishy-washy in the answer but 24 thats how it works.
25
84 MICHAEL MARKLEY: I would like to just say one thing. This is in 1
many respects a voluntary submittal. And we do believe that over time and when 2
we sort through all these questions that will clarify the design and licensing basis 3
for both the licensee and the NRC. Im not going to hesitate to say that well 4
probably have more discussions where it takes time to work through the mutual 5
understanding and I appreciate your patience and taking the time to do this. It is 6
important; I think the last couple of weeks have increased our sensitivity to it.
7 Not that we werent already working on it because I think at least as far as Diablo 8
Canyon is concerned, weve been working on seismic for a very long time. And 9
again, I think this is a good initiative on your part and others will probably learn 10 from it. And were going to be questioned a lot more about all aspects related to 11 this, so.
12 LOREN SHARP: This is Loren. We do appreciate that and in our 13 mind and role where well see where we take the input from this dialogue as well 14 as the previous ones and our intent essentially is to submit the LER and start that 15 dialogue as you mentioned as we work through the process. We understand that 16 this could take some time as you work through the review and approval process 17 in an amendment like this.
18 NORM ABRAHAMSON: This is Norm. Did you have any feedback 19 on the 10 year update?
20 ANNIE KAMMERER: I say, Yay. Im really glad that youve 21 incorporated that because it takes away the question of when is this triggered, 22 what is significant, a lot and I mean I think theres been a lot of discussion in the 23 broader technical community about how often we should be doing these.
24 Currently the NRC has a program thats with DOE and EPRI, the Central Eastern 25
85 U.S. Seismic Source Characterization Project and weve been, you know, we 1
even put in there that we felt thats about as far out as you can go in the seismic 2
hazard world and still have creditability. So I really applaud the fact that you 3
voluntarily incorporated that.
4 JAMES POLICKOSKI: Ill respond to just one other comment 5
because we did provide some feedback in the January 26 meeting in that regard 6
and I think we alluded to it in December. There was kind of two angles to the 7
comment that we had raised which is there has to be -- we were looking for some 8
sort of -- enforcement may not be the right word but checking capability as the 9
regulator to insure that youre still on track because this amendment can be 10 viewed as slightly open ended is the problem. And how do we as the regulator 11 come back and agree that youre number one youre keeping a good threshold 12 and number two, your process is truly as up to date as you state.
13 And so its two fold, its allowing us to double check it and make 14 sure the technologies and we rely on our experts to insure youre keeping pace 15 with industry. And the 10 year scratches the first itch, definitely, and the second 16 point, I defer to Annie on whether it scratches that itch because the one part, in 17 fact I had a question I failed to ask is how youre going to document peer review 18 methodologies so that we understand when it says peer review, thats an open 19 ended term. You know, its got to pass the NE sniff test and other folks in the 20 staff to insure, that you know --
21 NORM ABRAHAMSON: For us, thats actually a review by our 22 Seismic Advisory Board, so we have an outside board of consultants and they 23 would need to essentially agree that the methods were using are, you know, 24 appropriate. So we will have a letter or documentation from them saying, Yes 25
86 they have reviewed these methods and we are following, you know, state of the 1
practice or state of the art.
2 JAMES POLICKOSKI: And would you just said, would that be 3
covered under the amendment Loren?
4 LOREN SHARP: I would just add that this is really a continuation 5
of what we currently do, so yeah, we can address that as part of this ongoing 6
process that we have.
7 RICH KLIMCZAK: Lets let Nathan address how the seismic PRA 8
is peer reviewed.
9 NATHAN BARBER: This is Nathan and I think you know, we 10 reference the ASME standard in our process as well as something were going to 11 use to make sure that were up to date. Well be using whatever the most recent 12 version of that is to update our peer reg including the updated hazard, fragilities 13 and the peer remodel itself.
14 JAMES POLICKOSKI: Thank you. Ill go around one more round 15 of questions, see if theres any other final thoughts. Ill give it to the public one 16 more time. Is there any other thoughts from around the table or here? Region 17 Four, do you have any other final thoughts, comments, questions or the site?
18 Hearing none and the last to the public, since we had a few folks from the public 19 on the line, is there any folks from the public who would like a final comment, 20 thought or question? Okay, Michael, I lost my other senior manager, would you 21 like to have any closing comments?
22 MICHAEL MARKLEY: Ive already summarized I think.
23 JAMES POLICKOSKI: Okay, I will thank you. I appreciate PG&E 24 for making the trip out here. This really helped in our dialogue. I appreciate the 25
87 folks from the public especially in light of the recent events in Japan, it matters 1
more to have the public aware of our process in an open way. Thank you very 2
much and this will close the meeting.
3
[Whereupon, the proceedings were concluded]
4