ML20154F213

Transcript of 880504 Meeting W/Util in Rockville,Md Re Tech Specs.Pp 1-82.Proposed Tech Spec Changes Also Encl

ML20154F213
Person / Time
Site:	Seabrook
Issue date:	05/04/1988
From:	Office of Nuclear Reactor Regulation
To:
Shared Package
ML20154F202	List: ML20154F213
References
NUDOCS 8805230150
Download: ML20154F213 (159)

Text

.

ORIGiunt UNITED STATES NUCLEAR REGULATORY COMMISSION NUCLEAR REACTOR REGULATION In the !!atter of: )

)

fiEETING REGARDING )

)

TECHNICAL SPECIFICATIONS )

)

FOR SEABROOK )

i PAGES: 1 through 82 PLACE: Rockville, Maryland DATE: May 4, 1988

==="

.m==. m=======================~==============

't HERITAGE REPORTING CORPORATION osesWAverare 1220 L saw, N.W, Sets me Wenhagion. D.C. 20005 eeosaaof90 acosto PDR ADOCK 0b000443 (2g3) M P PDR 1

_ _ _ _ . , _ . . . . ~ _. _._.___ . ___ ,_ _ .. _ __ _ _ . . , . _ _ _ _ _ _ _ . .

cn

• 1 UllITED STATES NUCLEAR REGULATORY COMMISSION 2  !!UCLEAR REACTION REGULATIOli 3

4 In the Matter of: 5

)

)

5 MEETIt!G REGARDIl3G TECHNICAL )

SPECIF1CATIO11S FOR SEABROOK )

6 )

7 8 Wednesday, May 4, 1988

. 9 Nuclear Regulatory Commission 10 11555 Rockville Pike Room No. 14-B-13 11 Rockville, Maryland 12 The meeting convened, pursuant to notice, at 1:00

, 13 p.m. +

s 14 -

BEFORE: DOllALD BRINKMAll Chairman 15 CALVIN MOOli 16 Technical Specifications Branch 17 ATTE11 DEES:

18 ROB SWEEllEY 19 WARREN HALL 20 RICHARD BELA11GER 21 22 23 21 25 Heritage Reporting Corporation (202) 628-4888

2 101. BRINKMAN:

1 Good afternoon, everyone. My name is 2 Donald Brinkman. I am assisting Victor Nerses in his duties as 3 Project Manager for Seabrook.

4 This meeting her been requested by the Seabrook 5 licensee, and its purpose is to discuss the technical 6 specifications for the Seabrook operating license.

7 Calvin Moon from the Technical Specifications Branch 8 is here to assist me in today's meeting.

9 The tech specs for,the Seabrook Station operation 10 license will be based upon the tech specs issued with the 11 October, 1986 fuel load license. The tech specs were issued as ;

1

\

12 t1UREG 1207.  !

l 13 Subsequent to the issuance of the fuel load 13 cense  !

14 tech specs, various reviews have identified certain required l l

l 15 changes to those tech specs. j l

16 I have a package of replacement pages that contains l

17 some required changes that have been identified to date. I 18 have a copy of the replacement pages for each 6f you.

19 The changes are marked with change bars in the l

l 20 margins. And these changes include the following topics:

l i

l 21 typographical, editorial changes, corrections to reactor trip j 22 setpoints for steam generator water level and pressurizer 23 pressure, additions of some notations to make the tech specs ]

l 21 more consistent with plant design in its as-built 15 configuration, relocation of the seismic instrumentation, Heritage Reporting Corporation l

r (202) 628-4888

3 eq 1 revisions to permit leak testing of a reactor coolant system at 2 reduced pressures, and interim updating of the licensee's 3 organizations charts. However, understand that this area will 4 require a further change when the provisions of generic letter 5 8806 are implemented. In addition, an addition, which requires 6 the licensee to implement a program for accident monitoring ,

7 i'nstrumentation gradually exceeding S percent of weighted 8 thermal power.

9 Yesterday, I received a package of additional changes 10 which are being -- which were prepared by the licensee. I have 11 made copies of these proposed changes and I have copies of the 12 proposed changes for each of you.

13 Cal and I are prepared to discuss those proposed 14 changes at this meeting.

15 And I think with that as an introduction, Rob, I'll 16 let you start from there.

17 MR. SWEEMEY: Okay. Well, I would like to just get 10 into these tech specs that we've been discussing for a while.

19 John, I take it this package is the package of 20 information, the list of items that we wanted to discuss?

21 DR. BRINKMAU: That's the package that I received i

22 from you people yesterday.

23 MR. SWEENEY: Okay. Well, I guess our best bet is to

'4 just look into things page by page unless George or Warren or i

25 Rich has anything to add. I will probably want to turn it over 1

./

l Heritage Reporting Corporation (202) 628-4888 l

4 c:,

1 to Rich or Warren, whatever you like, as we go through page by 2 page. And I'll just add one other item. If anybody has any 3 problems with what Mr. Brinkman handed out, we can discuss them 4 now or later. It's up to you folks.

5 MR. BRINKMAN: Do you want to take them first if 6 there's any problems with that? That's fine with me.

7 MR. SWEENEY: Whatever. We can go through our 8 package or yours first. It doesn't matter.

9 MR. BRINKMAN: It is my understanding that the 10 package that I handed out is work that was developed over the 11 past several months prior to my becoming part of the project.

12 MR. SWEENEY: Yes. Several of the items had been

1. 3 discussed with the project manager and Ed Cartier, who was an 11 engineering support individual for Rick at the time. We will 15 just go through that package quickly and if there are any 16 questions and clarifications, we'll address them.

17 MR. HALL: We are going to go through this one first, 18 the second one he handed out, or the first one he handed out?

19 MR. SWEENEY: The first one. Let's go through that 20 first, because I think ours is going to require more time and 21 explanation. Let's just go through page by page. Warren, do 22 Vou want to start?

23 MR. HALL: Yes. Okay. We had been through this, we 21 went through this this morning and I didn't have -- I ran into

'S a few glitches. Nothing really major. I think it was a typo, I

Heritage Reporting Corporation (202) 628-4888

. . s/

.~.

5 1 on Page 3 , let's start with 41, that's the seismic monitoring 2 instrumentation. We had', after we had the April meeting a year J ago, where we put this package together, we submitted a formal 4 request or request of information that we had discussed with 5 Gus Giesekoch regarding the seismic instrumentation, and the 6 relocation of that instrumentation, and we subsequently 7 received a lett'er from the staff stating that they didn't have 8 any problems with what they were going to do, and they had 9 changed our tech specs,,per se, and they would issue them at a 10 later date. And with that,in mind, we have some changes to 1.1 reflect that that we would like to point out at this particular t? point.

Il MR. BRINKMAN: All right. I was under the impression tt that the changes in here reflected that, but if there are 13 errors, let's correct it.

1. 6 MR. HALL: That's why we wanted to bring that up 17 right at this point.

10 MR. BELANGER: What is here actually reflects what we 19 had agreed to at the meeting on April 7 of last year and it 20 does not incorporate the changes for re3.ocating the monitors.

21 MR. BRINKMAN: Okay. I stand corrected. If that's 22 the way it is, let's get it straight.

23 MR. HALL: Okay. On Page 3-41, with the relocation

~' t of the three monitors, the 4332 surveillance on the third line

'S starting with "except" -- "except the triaxial peak Heritage Reporting Corporation l (202) 628-4888  !

l

6 s

1 accelographs, 1 FMXR 6702 and 6703 shall be restored within j 2 seven days." That should be deleted.

3 Now, I can go back and give you some history as to 1 why that should be deleted. Cal, if you remember when we  ;

i 5 talked about this last April, when we were asking that this be i 6 done, it was becauce of the location of these two things with i

7 regards to getting to them if we had to have a shutdown, and so O forth, and that was the reason that this was a problem, because 9 we couldn't get to them within the 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> that had originally 10 been in there. So the seven days was granted.

11 Now, with the relocation of the transmitters, this is 12 not necessary.

13 MR. BRINKMAN: Okay. Go back to exactly what we

'1 u. sally had.

15 MR. HALL: Basically, yes.

16 MR. THOMAS:' It was a letter to the staff?

17 MR. HALL: No. In the letter that we sent to you and 10 was approved by the staff and they sent the letter back.

19 Now, if you would turn to the next page, 3-42, Item 20 1, triaxial time history accelographs A, B and C are okay, i

21 Item 2, triaxial peak accelographs, 1-SM-XR-6702.

l 22 How, its location now should be accumulator tank SI-CK-9C. l 23 MR. BRINKMAU: Would you repeat those numbers?

3 ,1 MR. HALL: It you want to just keep that, Don, why 15 rion't you do that?

I i

Heritage Reporting Corporation (202) 628-4888 1 i

7 1 MR. BRINKMAN: All right.

2 MR. HALL: Now, in Item 3, the reason we did not 3 submit, we didn't delete the triaxial switches like we did in 4 the copy that you handed out in your package is because we 5 really had never been issued those to delete, okay, so we 6 couldn't delete something we didn't have, or have the authority 7 to delete.

O So at this point I would say we would scratch those r) out, just like you have it in the package you gave us.

10 MR. BRINKMAN: Use exactly what I have in the package 1.1 that I gave you under 3. Is that correct? Is that right?

I? MB. BELANGER: Yes. These changes reflect only lj changes resulting from the relocation of the monitors and not 11 those changes which were discussed at the meeting last April.

15 So in other words, the three instruments, 1-SM-XR-6702, 6703  ;

l e, and 6706, on your page, should have their locations changed to ,

i 17 reflect what's on this page.  !

10 MR. BRINKMAN: Okay. I understand that. And we will '

19 take what you just handed me and include it as an attachment to 20 the transcript.

1 i

21 MR. HALL: And th*e deletion of the seismic switches i 22 in 3 is also okay. It shows on your markup. It shows on your 23 paper.

• 1 MR. BRIUKMAU: Item 3 What we have in our handout I l

'S made is accepted.

Heritage Reporting Corporation (202) 628-4888 1

J

8

~

1 MR. HALL: That's correct.

2 MR. BRIllKMAN: And what is in your submittal here 3 showing four switches should be corrected to just one?

4 MR. HALL: Yes.

5 MR. BRINKMAN: I understand.

6 MR. HALL: There is one thing. On your Page 42, Item 7 3, under 6709, it should be elevation 26, minus 26, not 27.

8 MR, BRINKMAN: Minus 26 rather than minus 27.

9 MR. HALL: Right. It is correct on the next page.

10 MR. BRIllKMAN : Okay.

11 MR. HALL: So you have Page 42 and 43, so I won't I? bother with 43.

!' MR. BRIT 1KMAti: Correct.

11 MR. HALL: Okay. There wasn't anything else on the l 15 seismic, was there?

l 16 MR. BRINKMAN: . Warren and Richard, if you would like 17 a break, I will make a copy of what they had and then give you 18 a copy.

19 MR. HALL: Is there anything else in this package, 20 Rich, that we had a comment on? I don't believe there is.

21 MR. BELA!!GER : I'm going back through it. I do not 22 believe there is anything else in question here.  !!o , that was

'3 Lt.

21 HR. SMEEllEY: There is one item in the package, and 35 that we'll get to later in our package, but it's on the H'-itage Reporting Corporation (202) 628-4888

9 1 organization charts.

2 MR. BELAUGER: Realizing that there are -- packaged, 1 in the second package you handed out which impacts upon this.

1 MR. BRINKMAN: I realize that, particularly in the 5 administrative control section.

6 MR. HALL: Okay. I guess we are ready for the next 7 package? The second package.

8 Okay. I guess it is my turn to ask you, the second

? package that you handed out, we had given this to them, 10 correct?

11 MR. SWEENEY: Yes. The other day.

1. ? MR. HALL: To look at. " And I wondered if you guys l' had any questions on any aspect of it, or do you want us to go 14 through each page?

1. 5 MR. BRINKMAN: We have comments on various pages. I 16 understand on the first page, Page 2-4, these are changes 17 associated with your change in transmitters.

18 MR. HALL: Correct. We're changing our Ve'rifax 19 transmitters and replacing them with Rosemounts. The change 20 has been cumpleted. The Rosemounts are in place and we are 1.1 living with the tech spec set forms that we had for the old ,

l 22 'leri f ax . l l

23 MR. BRINKMAN: I have no real particular problem with

'l these changes. We will take, at the completion of this effort,

?S we will take all the pages that have been changed and we will 1

. 1 Heritage Reporting Corporation (202) 628-4888 i

l

10 1 transmit them to you, as we did before the licerse was issued, 2 and identify the changes that have been made as I did in the 3 first package I gave you alth the margin bars. We will ask you 4 to review that in conjunction with the rest of the tech spec 8

3 package and begin certifying the accuracy of them to us.

6 MR. MOON: One question. Are there any changes in 7 the FSAR or SER that are needed at this time or were they taken 8 care of before?

9 MR. HALL: I think with the package that we will 10 submit on the Rosemounts we'll have FSAR corrections in them 11 and should point out any discrepancies in the SER. I'm not 12 sure that there was anything in the SER that would directly 13 impact --

11 MR. SWEENE'i: Well, the safety evaluation is the 15 responsibility of the NRC. However, we will be submitting to 16 you folks a letter that will basically outline the technical 17 basis and indicate where the FSAR will be changed in the FSAR 18 update.

19 MR. RALL: That has to be part of our design change 20 package.

'1

. MR. BRINKMAN: Then I think we're ready to go on to 22 the next page which is 1-1 in Section 3 of the LCOs. The 23 change there is basically acceptable, will simply end'the

/1 phrase, make it equal to 1.3 percent billed to KOK period. The i 25 rest of that phrase is simply a restatement of the I

Heritag9 Reporting Corporation (202) 628-4888

.s 11 1 applicability.

2 MR. SWEENEY: Don, do you have the lotter?

3 MR. BRINKMAN: Yes, I do.

4 The next page, 1-8, I believe, Cal, this is a 5 variation from the Westinghouse standard tech spec change, 6 isn't it?

7 MR. BELANGER: That is correct.

O The reason this is proposed is to make the action 9 requirements consistent with the statement of applicability 10 where you are, the requirements apply only in modes 1, 2, and 11 3. Therefore to be consistent with specification 303, the 12 action statement should only drive you down to mode 4, not down 13 to mode S.

It MR. BRINKMAN: I fully understand that.

15 Unfortunately, we are I think required by our own internal 16 procedures to ask you to want this change pursuant as they are 17 being planned to a generic change. I 19 I understand your point, and basically agree with it 1 "J but we are construed by our own--

70 MR. HALL: At this point let me ar'n--

21 MR. BRINKMAN: Guidance.

, MR. HALL: Let me ask a question. When we were 23 issued the tech specs that, and I'll address this to Calvin, he 11 may be ebl9 to better enswer it. -- wrote in his letter that

'5 if the -- would entertain the improvements, if they would I

Heritage Reporting Corporation i (202) 628-4888 l

a O

. 12 1 entertain improvements at a later hour, are we still going to 2 able to put this forth, or are'we going to be constrained by 3 changing actions in the specs? ,

4 MR. MOON: I believe our operating procedures will 3 change to suit that point. If you are speaking in terms of the 6 Seabrook tech specs - ,

7 MR. HALL: 'Right. i 1

0 MR. MOON: I believe that the first line of the other {

l 9 procedures has gone, at least,to the override, that thing you {

10 obtain - . -

1) MR. BELANGER: So that if we were to pursue any of 12 the other changes from the tech spec improvement program, they 13 would have to be undertaken on the leave of plant basis, is 1

1. 4 th'at correct?

15 MR. BRINKMAU: That's my understanding of it Cal, is I 16 that--?

17 MR. HALL: Well, if we were trying to give -- in that 10 situation.

1? MR. MOON: Okay, first of all, the question is, is it 20 a generic issue. This one obviously is. Right. Two things we 21 have are one, you may request the change and then we can ask 22 you to get the owners we have endorsed whether it is done with

!3 the plant from high up.

24 If you do not want to do that, there is one

?S possibility the staff itself could take it upon them, or the Heritage Reporting Corporation

(202) 628-4888

13 1 plant as we now do, treat it as a generic issue, which would 2 lead up to tho issue both from a generic level, in fact.

3 I believe in this case that it would be -- likely to 4 endorse - . 1 guess there is a question here, Don, as to 5 whether er r!ot this should be done prior to the -- flight or 6 af ter the -.., I guess it could be done at wither time.

7 MR, BRINKMAN: Yes, I don't have a strong feeling or 8 guidance on it.

9 MR. MOON: I think that is up to you, isn't it? If 10 there is any constraint on the part of Mr. Wilson or on -~

11 MR. THOMAS: Yes, it should be up to us to determine L2 how we proceed.

13 MR. BELANGER: That might be covered under Item 2b of 14 the Agenda, additional short term improvements, I think on Item 15 2a.

16 MR. BRINEMidi: I think that takes us to the next page 17 then, 1-9 where you're proposing to add in the word, )

i 10 centrifugal, to make it one centrifugal charging pump for LCO 19 3.1.2.3. This is something that I have seen in the past, and I  ;

)

20 have advised against it in the past in that the tech spec is i

21 written permits you to use any charging pump as a means of

 ? injecting boron while in a shutdown moce. You would, with your

'3 change, restrict that to only a centrifugal charging pump and

't would exclude the reciprocating pump.

25 MR. HALL: h'ou ld it exclude it? If you read that, it x

Heritage Reporting Corporation (202) 628-4888

i .

14 1 says, one charging pump in the boron injection flow path 2 required by spec 3.1.3.1. shall be operable and capable of 3 being powered from an operable emergency power source.

4 If you were to' change it, I understand what you're

saying, I'm just trying to figure out if it really would G exclude that you couldn't --

7 MR. BRINKMAN: If you add in the word, centrifugal, I 0 think it requires a centrifugal pump.

9 MR. BELANGER: Yes, but I don't think that would 10 preclude using the positive displace pump, only require the 11 centrifugal pump be operating.

I? MR. BRINKMAN: Oh, you could use it. I agree you 13 could use it for injecting the boron, but my point was if you IJ change the tech spec as you propose, then you must have a

1. 5 centrifugal pump operable. My original tech spec would say any 16 charging pump could meet the LCO.

17 MR. THOMAS: One of the considerations with that is 10 due to a specific plant design. The specification and the 19 requirement in the specification of having the capability of 20 being powered by an operable emergency power source can't be 21 done under certain conditions whe*n you have, say, diesel out of 22 service. And as a result of that, I understand what you're

'3 saying, this would give us more flexibility under that 1

't condition.

M MR. BRI!!KIW1: Which would?

1 Heritage Reporting Corporation (202) 628-4888 l

1 s 15 1 MR. THOMAS: What we're proposing.

2 MR. BRINKMAN: I don't understand why it would give 3 you more flexibility. When you put in the word, centrifugal, 4 it, by putting it in, to me, excludes counting on a positive 5 displacement pump.

G MR. THOMAS: You're right, it would.

7 MR. BRINKMAN: And I think the original wording of 8 the tech spec gives you the max 1.num flexibility and satisfies 9 our requirement for having a pump to inject boron.

10 MR. THOMAS: It would, it does. I think one of the 1.1 considerations here is because we've been in MODE 5 for a 12 period of time, that there would be some advantages to running I' the positive displacement pump. And in certain conditions, it 11 can't be run because of the first wording of this spec. For 17, example, when the diesei's out of service.

14 MR. BRINKMAN: I understand that, but then you could 17 use a centrifugal charging pump to meet the LCO.

18 MR. THOMAS: That's right.

l? MR. HALL: I see what you're saying.

1 10 MR. BELANGER: Yes, but we can use the centrifugal  !

l 11 pump to meet the LCO but under surveillance, we're precluded l' from using one to meet the LCO and another one to actually do j 1

' .1 the charging.

'l MR. HALL: But I think I understand what he's saying.

'n Maybe we ought to think about it.

Heritage Reporting Corporation (202) 628-4888

,. 1 s 16 1 MR. THOMAS: Well, and I think that's why we're.

2 having this discussion to put it out on the table. We haven't 3 officially submitted the change request yet.

4 MR. MOOll: I think all he's saying is it doesn't add 3 anything to it and it doesn't take anything away from it.

6 MR. BRI!!KMAN : Yes, the original wording. It adds 7 flexibility if you --

8 MR. SWEEllEY: Are you saying what we're proposing is 9 more rigid? ,

10 MR. BRIl1KMAll: Absolutely.

1.1 'MR . THOMAS: Under some conditions it is, and under 12 other conditions, it isn't. And for an example, what we're

1. 3 proposing would allow us to have both a positive displacement lot pump and one centrifugal charging pump in service.

l '., MR. BRIllFMAN t Yes.

1. 6 MR. THOMAS: liow , that would again allow us to run 17 the positive displacement pump without running the centrifugal 18 pump. Now, that would be the advantage to us under those 19 conditions.

20 MR. BRI!1KMAll: Okay, now the question then becomes, 21 is your low temperature over pressure protection analysis valid 22 with a centrifugal charging pump and a positive displacement 2 '3 pump both running?

'4  !!R . THOMAS: The answer's yes. It has been designed

'5 to meet that situation. That's why I say we would have to Heritage Reporting Corporation (202) 628-4888

's . -

17 4

1 submit something if we were to go ahead and definitely propose 2 this because of that consideration.

3 MR. BRI!1KMAN: Yes, it would.

4 MR. THOMAS: But, yes, it has been designed to be 5 able to handle that capacity.

6 MR. BRIl1KMAll: Did our review of that include that 7 possibility df two pumps?

8 MR. THOMAS: That I couldn't answer. I'd have to go

? back and take a look at that.

10 MR. BRIllKMAtl: I don't know either.

11 MR. THOMAS. I don't know. It's been a while.

I/ MR. SWEE!!EY : Well, is this an item that should be t' looked at more?

11 MR. THOMAS: Oh, I think there's no question about 15 it.

16 MR. BRIl1KMAN : I'm not ready to accept this one right 17 now because of the --

In MR. THOMAS: I understand. We should go back and I? take a look. I understand and I think that's why we wanted to

'O bring it up to talk with you about it and tell you we were

'I interested in it. It does have some advantages under certain 22 operating conditions for us.

/1 MR. BRIllEMAll: Shall we proceed on?

It MR. THOMAS: I think so.

?5 MR. BRIllnMAll: Page 1-10 again is the same discussion Heritage Reporting Corporation (202) 628-4888

a .

18 1 we had earlier on engineering change.

2 MR. BSLANGER: Yes, it's the same changes we had on 3 page 1-8.

4 MR. BRINKMAN: Page 3-20.

5 MR. BELANGER: Yes, we would like to withdraw 3-20

'l 6 and 3-22, 7 MR. BRINKMAN: Okay.

8 MR. HALL: 3-26 was also part of the Rosemount.

9 MR. BRINKMAN: I thought it was. Let's go on then.

10 Page 3-28 is Rosemount associated.

11 MR. RALL: Page 3-33. Let me ask for an 12 interpretation here. I'll tell you how we interpret what this

13 means.

14 Emergency feedwater manual initiation motor driven i 1

i 15 pump, turbine driven pump, the surveillance requires a trip '

i 36 actuating device operational test for this particular item. i

) 17 I will ask you how do you interpret this? How do you j 18 interpret this refueling outage trip actuation device test?

j 19 What is *.his thing supposed to do?

20 MR. BRINKMAN: Do you have manual actuation buttons  !

1 21 or switches for this?

22 MR. HALL: We have buttons, if you're asking if we l 23 have a button that says, manual feedwater actuation, the answer 24 is, no.

i 25 MR. BRINKMAU: You have a motor driven pump?

i

)

Heritage Reporting Corporation 1

(202) 628-4888 L i

f

~

, . ,o 19 1 MR. HALL: We have a pump start or a switch that 2 will start the motor driven pump, excuse me, the steam driven 3 pump by opening the valve. That's all it does, opens the valve 4 and allows the steam to the turbine. We have a switch that 3 starts the motor driven pump. It does not give you feedwater 6 actuation.

7 MR. THOMAS: There are individual component control 0 switches that could be used and would be used to manually 9 activate the system and I would use,the surveillance test for 10 example for individual components of the system. There is not 11 one single switch that allows you to manually activate the ,

1. 2 system. And that's the reason we brought it up, because we 13 don't really feel because of our specific design that this is 14 truly an' applicable requirement because of the system design.

15 MR. BRINKMAN: The controls that you were just 16 describing can start the motor driven pump, start the power to 17 the pump, where are these controls then required to be tested i 18 in the tech specs on an annual basis?

19 MR. HALL: That's the question here. We have in 20 Table 3.3.3., we have the manual initiation for the turbine 21 driven pump and the motor driven pump, and we nave the proper 22 channels for the valves,

'3 MR. BRINKMAN: That's operability.

24 MR. HALL: -- and that's the operability requirement 25 for this surveillance.

Heritage Reporting Corporation (202) 628-4888

i 20 f

1 And now the question here is how do we handle this 2 surveillance to make it --

3 MR. THOMAS: The response to the question, do we have 4 operability requirements, requirement testing of the pumps. Do 3 we have operability requirement testing on the valves specified 6 somewhere either in here or in a document that's connected with 7 this. I think --

8 MR. BRINKMAN: I think that's the question, yes.

9 MR. THOMAS: -- that's the question.

] 10 MR. HALL: Yes. Well, before I say, yes, let me 11 look. I 12 t'R . BRINKMAN: The purpose of this surveillance is to

.13 require you to periodically test those manual actuation 11 devices.

15 MR. HALL: We have, in the auxiliary feedwater spec, 16 we have surveillance that requires us to verify that the motor 17 driven pump develops a discharge pressure of greater than or 18 equal to the -- which you can't do unless you start it.

15 MR. BRINKMAU: That's true, but that doesn't say i 20 where you start it or how you start it.

21 MR. HALL: This is true but we can always work that, )

22 we can always come up with that point. And I would guess, and l 23 if I'm not mistaken, I would think that that's how we satisfy 24 part of the surveillance for these two would be through the 25 manual initiation control starting these items, verifying that Heritage Reporting Corporation (202) 628-4888  ;

4 21 they do start and then come up to speed and get discharge.

1 2 pressure. I can't say that that's a fact without verifying the 3 procedure.

4 MR. MOON: So what would be the reason for deleting 5 the tech spec surveillance. ,

4 6 MR. HALL: If the Staff is interpreting the tech spec 7 to mean that this manual initiation starts the whole feedwater 0 system from starting the pump to opening the valves to putting 9 water in the generator, no, it doesn't do that. And we just 10 want to get that straight up front.

11 MR. BELANGER: There is no single control switch l 12 which is manual initiation for emergency feedwater. There are  ;

a 1i switches for individual components of the system.

1

.14 MR. HALL: We're trying to eliminate a point of  ;

13 confusion is where we're headed.

16 MR. BRINKMAN: I think what we're looking for as I 17 recall is a demonatration that those switches do their 10 functions.

19 MR. MOON: That when needed, you can do all of these j 20 things.  ;

21 MR. HALL: That's not a problem. Can you add a j 22 sentence or two in the basia to explain what's meant there? [

23 MR. BRIDEMAN: We could do that, yes.

'i MR. HALL: It's not a problem, okay, as far as i 75 testing each one of the components in the system. They are l 1 i 1

l

' Heritage Reporting Corporation  !

(202) 628-4888  !

22 L surveilled and they are survellied per the tech specs.

2 MR. THOMAS: The question is are they survellied by 3 the tech specs versus their manual activation device. And 4 that's what we've got to go back and look at. I'm quite sure 5 that they are but I'd like to go back and recheck the 6 procedures.

1 And the reason I'm quite sure that they are is 8 there's no effective way to test them other than by the manual 9 activation device.

10 MR. HALL: And we just did not want a point of 11 confusion here with this that someone comes in and says, okay, 12 where's your manual initiation.

IJ MR. BRI!1KMAll: The tech specs are not, I'll say it -

it again, I've said it many times , are not intended to make you 15 put in such a button, or make a design change for that. But 16 the tech specs are intended to require that you test these 17 devices that you have. And you may certainly do one operation 10 and count perform several surveillancen.

19 MR. HALL: Right.

10 MR. THOMAS: Assuming that we go back and check that, 21 and as I said, I'm quite confident our check will indicate that 22 wa don't do it, do you feel that if that's the case, that by 23 changing the bases indicating it will be tested that way would

'I be an adequate wey of doing it in handling this problem?

5 MR. BRIT 1KMAll: My feeling would be if you want to add Heritage Reporting Corporation (202) 628-4888

23 I something to the bases, we will certainly entertain that,.but I 2 would be inclined to leave this requirement here and in your J bases explain what you're doing to satisfy this requirement.

4 MR. HALL: That's fine.

5 MR. BRINKMAN: Okay.

6 MR. MOON: I don't feel that we necessarily agree

. 7 that there are changes needed.

O MR. BRINKMAN: No, I don't. We may add something for 9 you. I don't feel that the change is needed. W hat I hear you 10 describing and what I've seen in other plants is not unusual.

11 I think it's the'same at other plants.

12 MR. HALL: Well, our folks are concerned over

1. 3 interpretation by one party or another differently from what we 14 actually had, and they felt that this was indeed not a true 15 realization of what they interpreted this thing to mean, anc 16 they were saying, hey, we don't do this, we test each component 17 individually, so why don't we delete this.  ;

10 MR. THOMAS: Well, okay, but at the same time, if we 19 have a common understanding, we can administratively handle 20 this, i

21 MR. HALL: Yes, we can handle that through -- )

12 MR. BRINKMAN: If you have any problems, can you 23 discuss it at all with the residents?

M MR. HALL: fio, we haven't had any problems with the '

75 residents. Our surveillance people were kind of concerned that i i

l Heritage Reporting Corporation (202) 628-4888 l l

e 24 I some people may interpret it differently, but if we can spell 2 it out to those folks in the bases or in some of our own 3 internal documents. ,

4 MR. BRINKMAN: If you can handle it in your own 3 internal documents, it's probably very convenient.

6 MR. BELANGER: We're approaching it as a possible 7 future problem area'which we would like clarified at this G point.

? MR. HALL: You said this would be handled on a

10 generic basis.

11 MR. BRI!1KMAN: Yes. Page 4-11. Okay, now page 5-1.

I? MR. HALL: You can scratch that one.

13 MR. BELAllGER: Scratch that.  ;

1. I MR. BRIllKMAII: Page 5-3.

15 MR. HALL: I think we have already discussed that i

16 with the Staff and I think they had already --

17 MR. SWEENEY: I had contacted Ed Schrondier and my '

10 recollection from telephone conversations I had with him, he 19 said he'd touched base with certain staff people and they j 20 didn't have a problem with it. It's basically lends itself to 21 afford the opportunity to do maintenance of the valve from my

?' understanding.

j 23 MR. THOMAS: As the spec as presently written does

't-not allow maintenance to be done on the valve without going out j ?S of the action state, going beyond the action statement as 1 ,

' I

~

4 Heritage Reporting Corporation (202) 628-4888 l

l

25 1 presently written.

? MR. SWEENEY: And by all means, we want to be able to 3 maintain the status.

4 MR. HALL: The way this thing is set up right now,  !

5 we're stuck between MODES 1, 2, and~3, we have to have them 6 open at a thousand pounds above and in MODES 4 and 5, we have 7 to have them closed at over a thousand pounds below. And we a have no -- there's no place in there where we can maintain the 9 valves.

10 MR. MOON: I think our only question here is the form 1.1 in which you've done this. I think it's not clear. This 12 applies only in MODE 5 Is it also intended to apply in MODE 13 4, or MODE 5 only. So I think you meant to say MODE 4, comma,

1. 4 without MODE 5.

i 15 MR. BRINKMAU: I think what you need here is to a l 16 location on the mode in which you intend to apply this 17 exemption rather than the phrase that you've added there.

10 MR. THOMAS: Double asterisk.

19 MR. HALL: Double asterisk on MODE 5 with a note at 20 the bottom.

^? 1 MR. BRINKMAN: Yes. That would be fine. Do you wish

'2 to draft a note? i 21 MR. HALL: Yes, we'll propose it and get it down to 24 Rob.

S MR. THOMAS: You wouldn't want to be working on these Heritage Reporting Corporation (202) 628-4888

- __----_l

. . i r

26

s 1 valves even though, tech spec wise, you could do it, physically 1

2 you wouldn't want to do it. It would only be a MODE 5 item.

B 3 MR. HALL: I'd like to talk to Greg and find out. He 4 was the one that had proposed.

5 MR. BRINKMAN: I think you understand my -- you want 6 a note --

7 MR. HALL: Yes, and I would want to check with our 0 tech support people that had tb!.s and find out, because I think 9 he was looking at potentially MODE 4 and M. ODE 5, but I'll talk 10 to him and find out. .

11 MR. BRINKMAN: Page 6-9. ,

l 12 MR. HALL: This is part of the Rosemounts, also.  !

13 Convoluted that --

14 MR. BRINKMAN: It sounds pretty convoluted to me.  !

15 MR. HALL: Trust me. Let me find the other -- l

) 16 MR. SWEENEY: The technical packages forthcoming will l

17 have --

10 MR. HALL: Yes. B0sically what this is saying is that 19 there was a requirement or a discussion at one time about 20 putting in a high energy line break alarm in the containment 21 consisting of pressure sensors. And this was due to the fact I

22 that we had the problem with the referenced heat-up with the 23 rear track transmitters. When we installed the Rosemounts, 14 temperature and environmental qualifications and performed the

25 calculations for our particular environment, we found that the 4

Heritage Reporting Corporation (202) 628-4888 4

d- .

i 27

, 'N 1 reference leg heat up was in essence not any -- was no problem.

2 The reference leg heat up error changed something like three

3 tenths of a pound in a harsh environment from normal operating  ;

t 4 activity temperatures to a harsh environment temperature in the 5 containment, and therefore there was really no need for the i 6 high energy line break alarm which was going to be part of the 1 7 technical package to do away with that.

l 8 And as such with the reference leg we felt that this 9 was also a viable change based on the stability of the 30 Rosemount transmitters during that type of, during a harsh 11 e nvironn ent . We do have the capability in the tech specs to ,

12 keep the purge valves open. We do have the capability to open '

l l 13 those things and use those fans to keep --

1 14 MR. THOMAS: There was a restriction or there is a 13 restriction in our existing specs on opening those valves when tG either in MODE 1 or MODE 2, pending resolution of what 17 effectively amounts to the high energy line break. And the 10 high energy line break issue thus solves that problem and thus l  !

19 will allow us to remove that restriction on opening the eight 20 inch purge valves. ,

1 21 Now, when you do that, that allows you then to purge

)

22 when in MODE 1 which would then allow this note to be added.

23 That's how you cet there. l MR. BRI!!EMAth I think there's another consideration j 'S here which I haven't heard being discussed. Typically, the 1

. Heritage Reporting Corporation l (202) 628-4888 11

[

i 28 1 lower limit on this spec, in this case, 14.6, seems a little ,

1 high for what I'm thinking of, but the typical consideration 3 here is that there is some lower limit on pressure in the i

4 containment such that if there is an inadvertent spray i

3 actuation during that time when you're at that lower Jimit, you i

6 will not ha'e an excessively negative pressure in the 7 containment.

O MR. THOMAS: That is correct and that is the basis of 9 the 14.6 psi.

10 MR. BRIllKMA11: All right. Ilow , if you remove that 11 limit when these purge valves are opened, what does that do to j 12 that --

? ,

13 MR. THOMAS: Okay, what it does to that is it means 14 that the pressure inside and outside the containment are 15 equalized or the internal pressure is no higher than the fan 16 differential, the purge fan differential above it, but it 17 certainly doesn't allow the containment to be at a lower l t0 pressure than outside.

1 l' MR. BRIlirMAll: Well, there'll be some transient 10 there. Is that analyzed as the spray comes on, cools the 21 containment atmosphere?

'2 MR. THOMAS: I'm not talking about that now, I'm

'3 talking about a situation where the plant is sitting there and i

't it's operating in MODE 1. And when that is the case, you would i

j 75 normally be limited to 14.6 psi as the lower pressure, i

i

Heritage Reporting Corporation (202) 628-4888 4

29 1 MR. BRINKMAN: Yes.

2 MR. THOMAS: Okay. Now, what this note will allow 3 you to do is if you drop below the 14.6 psi due say to a low 4 pressure condition outside for an extended period of time, then 5 you could open those valves at which point in time once the 6 valves are opened, you ocualize pressure. Start the purge fan, 7 and then the way this spec is written would not be able to il reclose those valves until the pressure was above 14.6. Now, 9 the differential pressure across the fan is greater than a 10 pound per square inch. So basically, what this would be used

1) to do is to build up the pressure inside the containment.

12 It's a pressure control mechanism.

13 MR. MOON: I'm trying to recall, the fans push in the u -- -

15 MR. THOMAS: That's correct.

16 MR. MOON: There is no suction. -

17 MR. THOMASt There is not.

18 And again, this is how the system was originally 19 designed and has been licensed to operate with the removal of 20 that restriction.

21 MR. MOON: But do you need this footnote in order to 22 pump up the pressure in the containment?

23 MR. THOMAS: Yes, because there's no other way to get

?I the pressure up there. Now, this would only be used it we had 25 an extended low pressure condition during operation.

Heritage Reporting Corporation (202) 628-4888

l 1

30 1 MR. MOON: But what I'm trying to say is, you are i

2 permitted to start these fans and operate them, right?

3 MR. THOMAS: That's correct.

l 1 4 MR. MOON: Even without this footnote?

5 MR. THOMAS: We are not under there's another page i

i 6 that goes along with this.

4 7 MR. HALL: And it's missing from this Spec.

3 MR. THOMAS: There is another page that goes along 3

') with that and it is page -- ,

i, 10 MR. HALL: 6-12, I believe.

11 MR. THOMAS: ' Oops, I'm sorry. Yes, it is 6-12. Yes,

12 I have it. And if you note in LCO 3617, part b, it says, the 13 eight inch containment purge supply and exhaust isolation 11 valves shall be sealed closed except when open for purge system i 15 operation for pressure centrol. Then in addition to that, 16 you've got the asterisk down at the bottom that prohibits that 17 in MODES 1 and 2. Now, what the Rosemount change will allow us i la to do is eliminate the asterisk.

I l '.' MR. BRINKMAN: Are you talking on page 6-12, now?

20 (R . THOMAS: On 6-12.

t 21 MR. BRINKMAM: Right.

i 22 MR. THOMAS: llow, because these two are connected, if 4

23 you go back to 6-9, that's how one would do it, by opening 1

'l those valves. And that's why the proposed asterisk is in i

] '5 thete, l

1 i

, Heritage Reporting Corporation (202) 628-4888

e . .

31 -

l' MR. BRINKMAN: I think I'm beginning to understand i i

2 your concern. However, I am confused as to whether or not this  !

2 i

3 notation that you put on page 6-9 is needed there. I believe i i 4 that what you're explaining to me you need something on page 6-

] 5 12 to permit you to open the valves and equali:e pressure, but  !

1 i

6 I think that the limitation on differential pressure on page 6- ,

! > 9 is still necessary. -

n MR. MOON: As a matter of fact, it doesn't look like i

i ') you even need to add anything on page 6-12.

In MR. BRINKMAN: You can delete --

11 MR. THOMAS: No. When you would need that is again

12 if your atmospheric pressure was such that it was below 14.6  ;

i 13 because if you didn't have that, once you open those valves,

34 containment would then equali:e with the 14.6 and you would be 1

15 out of the spee. This allows you to pump the containment up i

16 without going out of the spec. .

i 17 MR. MOON: That's not what the words say, as I read j Ut them. f

r 19 MR. BRINKMAN

Me either.  !

i i

l 20 MR. MOON: It just says you can operate at less than l 1

i

< ~1 14.6.  !

i  !

l 22 MR. THOMAS: With the valves open. But only with the !

! i 2 .1 valves open. It's . question of how to get to increasing the i

', i 11 pressure to do pressure control. That's what this is allowing J

1 '3 you to do. And if the outside air was below 14.6, thus causino t I l i

! Heritage Reporting Corporation  !

] (202) 628-4888 (

i i

I 32 t

'~

1 your containment pressure to go below 14.6, the only way to do 2 it would be to open those valves to get the air source to pump f

3 it in.  :

4 That's why you need this. ,

I 5 MR. MOON: But is it not possible to pump the [

r pressure up to say 15.43 and then close the valves and turn the j i

7 fans off? i i

0 MR. THOMAS: Yes, it is.

9 MR. MOON: And therefore cannot you not live within l t

10 14.6 limit without the footnote? ,

11 MR. THOMAS: The question is can you start the fan l 12 before you open the valves to be able to do that. And I don't f 13 know what the answer to that is. That's something we'll have f 14 to look at. .

e 15 MR. BRINKMAN: George, your discussion of the outside 16 air pressures below 14.67 l

17 MR. THOMAS: Yes.

10 MR. BRINKMAN: And then you open the valve to -- it i

19 will not immediately equalize. It will take some time for that 20 volume of air to equalize.

21 MR. THOMAS: That's correct.

22 MR. BRINEMAU: And I'm concerned with the structure 23 of this footnote here. It really removes the portion control 21 as I see it, and I don't think that's appropriate.

75 MR. THOMAS? It's not intended to. It's not intended Heritage Reporting Corporation (202) 628-4888

t i

33 !

i 4 1 to.

0 MR. BRINKMAN: It may not be intended to. But I  !

i 3 think if we put this in the tech spec, it in effnet removes the 4 limitation that we see necessary on that.  ;

5 MR. HALut I gress I'm not real sure how because if l

\

i G you read this note it says that the only time this 14.6 would ,

i 7 not be applicable is when the fan is running and the valves are <

i i

8 open, which would be when you're trying to equalite pressure.

9 You wouldn't iust open those valves and let it sit there to ,

l 10 drop below 14.6. The only time you would do that would be when  !

l 1.1 the fen is running and the suppi.y valves are ope'n, as allowed 12 by spec 3.6.1.7.  ;

l 13 MR. THOMAS: The reason for the latter part of that  !

14 note is to insure that that would be the only time that they i l

, 15 were being opened. That's what that second part, as allowed by c

]

16 spec 3.6.1.7 is supposed to indicate. It i s n ' ': supposed to I

17 indicate that you could operate with these valves open so as to l i

j 10 nullity the intent of this.

19 MR. RALL: I think this is similar to what they did 20 at Palo Verde to use those valves to pressuri:e the, so you'd 21 maintain pressure control in the containment.

1 J

72 MR. BRINEMAN: I see no problem with using the valves 1

i 23 to maintain pressure control, but I think that is basically i

i l pernitted by the spec on page 6-12. But I an not at all 1

'5 convinced yet that this is needed, the proposed footnote is

\ -

] Heritage Reporting Corporation (202) 628-4888 i

d 4

l 34 1 e

l needed on page 6-9.

1 i

2 MR. HALL: Well, it would be if we were going to try l

l 3 and maintain pressure if you had a low pressure system and your i 4 outside pressure was below 14.6, it would be a problem. l f

5 MR. BRINKMAN: It's a problem if you open the valve j l

! 6 and let the pressure equalize with the outside pressure. i l l a 7 MR. HALL: Without running the pump. You wouldn't do 1 l  !

O that because if it was that low and you open the valve, you'd j 9 start the pump. That's the whole key, is starting _the purge I

10 fan and opening the valves together, or you know, in the i i 1.1 appropriate sequence and keep the pressure in the containment

) U with whatever the pressure l's you're operating to outside. l

! U MR. MOON: Is what you're saying you can't manipulate l

! (1 the valve and the tan so as to merge them both to 14.6 ,

J 15 transiently?

I 16 MR. HALL: Yes. That's right. l

{ 17 MR. SWEENEY: Yes. Would it be appropriate to just  ;

t 1R footnote the applicability whereby the outside, this is  !

l a 1. 9 applicable when the outside pressure is equal to or greater j 20 than 14.7 or something? l l  !

I l

'l MR. THOMAS: No. Because it doesn't have to be,

?2 because that'e the only '.ime you need pressure control . The  !

t

23 original intent of page 6-12 was to provide pressure control,

{ 't and that would be the only time you would need it.

i  ;

I '3 MR. MOON: The middle of pressure also enters into  ;

1 ,

J l Heritage Reporting Corporation +

! (202) 628-4888  !

i

.s u l

I

. t 35 i

i the ECCS calculations, in addition -- no, the starting pressure 2 I believe enters into the lower limits on the ECCS.

3 MR. HALL: Are you referring to the containment i 4 spray? l 5 MR. BRINKMAN: The RHR. +

6 MR. THOMAS: The NPSA requirements 7 MR. BRINEMAN: Yes. Which also enters into i l \

n containment spray on research. It's both those. l 2 MR. HALL: Bruce looked at that.

?

10 MR. MOON: I guess I don't understand why it is you j 11 can't avoid this transient below 14.6?  !

l 12 MR. HALL: We have no control over the pressure if l 13 the pressure drops, we don't have any control over atmospheric 1I pressure if the pressure falls.

15 MR. BRINKMAN: You don't have control over the i

16 outside pressure but you do have control over the pressure in i 17 the containment. And -- r 18 MR. HALL: We don't control the differential 19 pressure.

! 'O MR. THOMAS: But that isn't what the question was, l

21 and we have to go back and look. f 22 MR. BRINKMAN: I think you have to go bach and look 23 to see. you start the pump, open the valve. sets the pressure 14 in the containment doesn't drop and discharge air into the fan l

.' S immediately.

Heritage Reporting ' Corporation l (202) 528-4888 I b

n 36

! MR. MOON: It would be a slow transient, so you ought 2 to be able to get the pumps going before the pressure drops, 3 MR. THOMAS: Absolutely, yes.  !

4 MR. MOON: So it doesn't seem like you need the 5 footnote.

6 MR. HALL: Why? If you open the valves and you start 7 the thing, the fan, and your outside pressure is less than n 14.6, you can't do it.

? MR. MOON: No, you do this while your pressure's at 10 14.6.

! 11 MR. HALL: How do we know whether or not the i

1 12 pressure's going to drop below that. l 13 MR. THOMAS: The reason it was proposed the way it is j 1

1 14 is this: is you've got some purge inlet and some purge outlet '

J5 valves. You have the fan on the supply side or between the i 16 atmosphere and the purge inlet valves. The proper valving

17 operation here is first of all you don't want a pressure in transient down the line. What you would do is open the purge

39 outlet valves to equali

e --

20 Excuse me, let me go back. You are in a situation j i

l 21 where atmospheric pressure was below 14.6. And you felt that 22 you had to increase pressure in the containment. The logical 23 way to do that is to open the outlet valves and equalize j l

) 'l pressure with the atmosphere, so when you open the inlet l l "al.es, vou don't get a pressure surge back through there, i

4 l Heritage Reporting Corporation i j

(202) 628-4808

37 1 okay, 2 Then close the outlet valves, start the -- and I 3 don't recall now whether yoi start the fan first or then open 4 the inlet valves -- but the reason for this is so you don't get 5 e pressure surge back the line and as a result of that have 6 pressure from inside the containment coming back through that 7 fan.

O That was the reason it was proposed in that way. It 4 would allow you to equalize pressure before you brought that 10 fan on to increase pressure.

11 MR. brill}: Mall: I guess my thought on that would be

1. 2 why don't you leave the outlet one closed, start the fan and 13 open the inlet valve and dump some air in?

14 MR. T!!OMAS : They looked at that. They feel that the 15 instrumentation was within the accuracy to be able to detect

1. 6 it. At the same time, they felt that it was a better operating 17 practice to go this way, better operating practice in the 1, n overall scheme of things.

1. 9 If you folks feel that it is a problem, and --

20 MR. BRIl1}*. Mall I see the problem, yes.

'l MR. THOMAS: Okay. Let us go back and first take a J2 look at it, and second of all, again, we've indicated this

?) would be part of the Rosemount package, and we'd have to submit 1

'l -

obvious justification as part of that.

]

23 I have question. Is your concern with the fact that

)

Heritage Reporting Corporation '

(202) 629-4888 j

l i

38 (

j 1 you're concerned about what we've looked at the two ,

2 considerations you've brought up. The NPSH was done on the >

j 3 lowest possible atmospheric pressure and I don't know what that .

l 4 was right now, but it was well below the 14.6.

5 The other consideration of the spray is obviously l

i l 6 when you're equall

ed with the atmosphere, you're not going to j 7 be below the atmosphere. The spray limitation is when the  ;

i 0 outside pressure is high and containment pressure is low.

j, 9 MR. BRINKMAN: That's true.  ;

4

, 10 MR. THOMAS: And then you could go down from there.

j 11 MR. BRINKMAN: Yes.  !

i .

j l .' MR. THOMAS: So strictly from a safoty analysis point '

j 13 of view, those two concerns have been looked at.

i j [4 MR. BRIMEMAN: The other concern that I have is a l 4

l l 15 notation here which would in essence say don't worry about the l j M internal pressure of the lower limit with this footnote, and I '

l

, 17 just have a bad feeling about that.

J 10 MR. THOMAS: Okay. And maybe we've got to make this 19 a little stronger. I feel that the second part of the sentence 1 10 on 6.9 that says, the supply valves are open as allowed in Spec 1

21 3.6.1.7, it was our attempt to solve your concern. But maybe l 12 we could make it stronger than that.

'3 MR. BRINEMAN: Okay, I think you should.

I

] 'l MR. THOMAS: Okay.

. MR. BRINEMAM: Are we ready to go on, then?

i Heritage Reporting Corporation *

(202) 628-4889

. .. -. . - - - - _ . . = = . . _ . . ... - - _ _ _ . . . . . - .

e - - .-

i  !

1 1

39 i

1 MR. THOMAS: Yes. ,

2 MR. BRINKMAll Okay. You've handed me here a page 6- l l

3 12 which was not in the package that I handed out at the j 4 beginning of the meeting. Is that intended to be in there or  !

5 not? I had not seen this before. l 6 MR. SWEENEY: Yes.  ;

i 7 MR. THOMAS: It should have been in there. l l

0 MR. HALL: Do you have page 6-12 there, Cal? That as l 3

9 you can see, that was part of the, that was the high energy l 10 line break alarm that I spoke of earlier that was. required to 11 be put in. And when we put in the Rosemounts, we did the  ;

l 12 calculation, and determined that it really was not necessary 13 eince the environmental change in the reference leg heat up j 11 error was only three tenths of a pound. -

15 MR. BRINEMAD: Okay, and that'~s in an analysis to be 16 submitted?

1. 7 MR. RALL: That is an analysis, and in fact if you'll 18 look at the stuff we've done, it only affected steam generator 19 water level by three tenths of a percent, and we threw in a lo little bit of extra conservatism into the set point and set it 21 at 14 percent using ths Rosemount transmitters and felt that 22 would obviate the need for putting in a new alarm.

'3 MR. BRINKMA!!: Okay. There's a page here which the

't observers have not seen before because it wasn't in their

'5 package, and if you want this included, I will make a copy of i "

l Heritage Reporting Corporation (202) 628-4888 l

i i

40 i

1 it at a break here and provide everybody a copy. ,

2 MR. HALL: That's fine.

l 3 MR. SWEENEY: In essence, that footnote was put in .

4 there back during the review as a limitation on those valven 5 because of the initial conditions per se of the analysis that 6 was done at that time.

7 MR. HALL: That's true. That's why we ended up 8 putting the 14.6 in there.

9 MR. BRINKMAU: I see the notation here on page 6-12 i 10 and the last part of it is, until installation of the narrow l

It range containment pressure channels alarme have been dompleted. l t

I? I think what you're telling me now is that's completed. So -

13 there's no -- .

f 11 MR. IIALL: No, what we're saying is that we don't .

?

15 need it. l l

i r, MR. BELAllGER: That was so we did not hava to take  !

17 into account reference leg heat up error for th's set points we lo used with the veritrack transmitters. The set points we've 19 proposed with the Rosemount transmitters which we've shown here

)

)

20 incorporate the maximum reference leg heat up error already and j

)

21 that's in the package that will be fully explained in the l l

2? p a c k a g e .- i l

'3  !!R . M00ti: I think the staff's going to have to be '

't aatisfied what's in the SER before thic change is made.

MR. SWEE!!EY : There will be significant amount of Heritage Reporting Corporation (202) 628-4888

. 1 i

i 41 1 technical review that they will require safety evaluation 2 checks.

3 MR. BRINKMAN: Before we can meet the 6-12, but I'll 4 provide everybody a copy of it here in a few minutes.

5 Let's go on to page 6-13 then.

6 MR. HALL: This was a request and we didn't feel it 7 was unreasonable by our operations department shift 8 superintendents that they wondered why the necessity was to 9 check to insure that each one of these valves is closed every 10 thirty one days if we don't go into the containment once we 1.1 lock it up and insure that everything is done and close down 12 the containment, is it necessary just to go in every 31 days 13 and check these valves i.f there's not been any entry in the 14 containment since they closed it up. We thought that was 15 probably a viable comment.

- 16 MR. BRINKMAN: I hear your discussion and Cal and I 17 did talk about this one I think yesterday. And we noted a 18 relationship here which I don't know if you noted or not with 19 the cpec on page 6-1. Which there is a footnote saying you 20 don't have to do it for valves that are located inside the 21 containment. The notation that you've added on page 6-13 to 22 the surveillance there, the surveillance on page 6-13 that the 23 notation is on is something that is in the standard but I see a la conflict.

l 25 MR. HALL: We saw that footnote but we were concerned Heritage Reporting Corporation (202) 628-4888 1

. p ,

42 1 over whether or not that was strictly applicable to the 2 containment integrity for the isolation valves or whether that 3 footnote could be applied, and that was the concern that they 4 had.

5 MR. MOON: On page 6-1, it does apply to --?

6 MR. BRINKMAU: Deactivated valves.

7 MR. MOON: Okay, but the surveillance applies to n valves that are capable of automatic isolation, which these 9 purge valves are, I think, right?  :

1 10 MR. SWEENEY: That's correct. I i

11 MR. HALL: No, the 36 inch are closed and locked 1 i

I 12 closed.

13 MR. THOMAS: But they also get a closing signal if 14 you're in like refueling. They do get a signal. They do have 15 the physical capability of sending a signal to those valves.

16 MR. MOON: Is there a question of whether or not 17 entry into the containment is the only factor to be considereo, 10 or are there~other things that affect the integrity of the 19 closure?

20 MR. HALL: You lost me, maybe I missed something 21 here.

22 MR. SWEEMEY: Are we asking them to interpret for us 23 this particular footnote in tech spec 3.4.6 that that includes

'4 the tech spec on 4.6.1.7.17 Is that what we're asking for?

25 MR. BRIUKMAU: No, I do not intend for this on 6-1 to Meritage Reporting Corporation (202) 620-4888

43 1 be applied to page 6-13.

2 MR. HALL: We didn't think so.

3 MR. BRINKMAN: No. But there's a relationship there.

4 MR. HALL: Yes.

5 MR. MOON: I do not recall that other plants that 6 have been recently licensed have had such a footnote as this.

7 I'm trying to recall if there's been some precedent set here, n I don't recall if there has. Is there an undue hardship 9 involved here?

1. 0 MR. HALL: No, we just didn't see the need to go I. .I inside a containment if you didn't have to.

12 MR. THOMAS: I think the question is this. If the 13 only reason that one was going in the containment was to verify 11 the locks on these valves, is it necessary to do it, because if 15 you're concerned about tampering or something like that, again 16 during an operating period, there's no justification. During a 17 shutdown period, it's obvious there's no problem in doing it, 16 and we can understand it. But during an operating period, it 19 just doesn't make sense to go in there simply to look at these l l

20 valves. tiow , if you go in for other reasons, then it makes

'l sense.

MR. HALL: I think that's basically what we said.

'l MR. MOOti: I guess it would be my recommendation that ,

1

'I we attempt to investigate the background of this.

MP. BRIN!: Mall: All right. I'll go along with that.

Heritage Reporting Corporation l (202) 628-4888 l

4 44 1 MR. HALL: Okay, so you're going to take it and look 2 at it and let us know something?

3 MR. MOON: Have you considered alternatives to the i note such as checking each time you do enter the containment?

5 MR. HALL: I think that's basically what we said.

6 MR. MOON: I'm not sure that's what it says.

7 MR. HALL: It says that these valves do not have to 9 be checked until containment entry has been made. So if we

') went back in there again, --

10 MR. MOON: But the note doesn't say you make it, the 11 note doesn't say you do the surveillance if you make an entry

1. 2 in 15 days.

13 MR. HALL: Say that again?

11 MR. BELANGER: He's looking at more frequent because 15 you've gtne in.

L6 MR. HALL: Oh. I don't know. My gut reaction is, 17 no, because if they checked it 15 days ago, and they went in 15 19 days later, they wouldn't check it again, because it wouldn't 19 be up on our repetitive task sheet.

l 20 MR. BRINKMAU: Let us look into it. l

't 7-1 is another generic, as is 7-3, I believe.

P MR. BELANGER: No, 7-3 is not.

) MR. BRIUKMAU: 7-3 is not, okay.

11 MR. BELAUGER: It is the same change as we have looked at previously in that MODES 1, 2 and 3 go into cold 1

1 Heritage Reporting Corporation (202) 628-4888 j i

I J

45 I shutdown. However, there is precedent in this particular.

2 instance.

3 MR. HALL: Yes, I_went back and looked at some of my 4 old paper work in my files and we had this at shutdown MODE 4 5 and several of the copies that we had that went back at 4 and 6 we even went and pulled a couple of other existing --

7 MR. SWEE11EY: Shearon Harris.

8 MR. HALL: -- we pulled Shearon Harris and there's is 9 -- I think that wac *he type, because we corrected this one 10 time.

11 MR. BRIl1KMAll: Cal, can we check this if it's at 12 variance with the standard rule, we'll change it.

(3 MR. HALL: I don't know what the standard is.

11 MR. BRIl1KMA!!: I don't either.

15 MR. HALL: We picked this up this morning and I went 16 over and pulled the Shearon Harris tech spec and all of there's 17 are hot. And I did go and look back at some of our older 18 stuff, the real old files that I had on when we were doing 19 this.

20 MR. BRIl1KMAll: We'll check it.

1 Page 7-23?

27 MR. HALL: These were inadvertently left off when we

'3 did this. We went back and found out that this stuff was all

'l there, all the temperature things there, the computer stuff is

'5 there, it had been monitoring the thing ever since day one, it

~

Heritage Reporting Corporation (202) 628-4888

s 46 1 just did not get picked up and added to the list. And we. felt 2 it should be on the list. Our residents at, re with us that it 3 should be on the list, so --

4 MR. BRINKMAN: Sounds to me like we ought to add it 5 then.

6 MR. BELANGER: Yes, added to the list.

7 MR. BRINKMAN: Page 8-6 I think is the next one thea?

8 MR. BELANGER: Yes, the changes on 3-6 and 8-8 were 9 proposed by the staff, deleting the words, shutdown, emergency to (accident) and then on page 8-8, emergency (accident) twice.

11 MR. BRINKMAN: Who recommended that these come out?

12 Ed Troffier?

13 MR. BELANGER: Yes.

1. 4 MR. SWEENEY: There were several conference calls to 15 discuss this. This was the result of our interpretations of 16 those telecons.

17 MR. HALL: This was not an interpretation. He 18 specifically said, you will take this word out and that word i 19 out. And we said, okay, we will take this word out and that  ;

i 20 word out.

'. 1 MR. THOMAS: To us, it doesn't make any difference.

22 Because of the way we're testing, it doesn't make any

'] differenre. I would guess his concern is legitimate. l m' l MR. BRINKMAN: This surprises me a little bit in that )

i

5 I recall some et the work that went into developing this l 1

Heritage Reporting Corporation I (202) 628-4888 l

c 47 1 surveillance. And the first one on top of page 8-6 there, 2 connected shutdown loads, the intent was there to do a testing 3 to verify that in a shutdown condition, you have different 4 loads than what you did in an operating condition automatically 5 and sequentially loaded onto the diesel. And the surveillance 6 there was to check that sequence and make sure it loads 7 properly.

8 And down a little further on page 8-6 and on page 8-9 9, the intent was there to check the sequencing under the loads 10 of true accident conditions. And I don't know what's happened 11 here.

l? MR. HALL: Well, actually, it does nothing because 13 our sequencer is such that certain loads are loaded on the 14 diesel when you get a less of off site power and certain loads 15 are loaded on the diesel when you get an automatic start, and 16 you don't get a loss of offsite power. So consequently, we 17 went back and looked at what was going to happen under each one 18 of these scenarios and the words don't mean any differences as 19 to what we load on the bus with the loss of off site power test 2.0 and then with an automatic start test with off site power

't available.

22 So the deletion of the words does not change what we 23 sequence or load on the bus.

74 MR. Mooti: You're saying which loads and how they're 25 sequenced is independent of external events?

Heritage Reporting Corporation (202) 628-4888

48 1 MR. HALL: It's independent of the words.

2 MR. THOMAS: 11 0 , it's independent of external events.

3 MR. MOON: For your design?

4 MR. THOMAS: Yes.

5 MR. MOOll: But not necessarily for all designs?

6 MR. THOMAS: When you say, axternal events, are you 7 talking about plant conditions or --

8 MR. MOON: About combinations of LOCA and loss of off 9 site power.

10 MR. THOMAS: Well, loss of off site power is 11 different than a LOCA.

12 MR. MOON: You have a different sequence of loads.

1.1 MR. THOMAS: It's not as much a different sequence 14 but certain loads aren't activated.

15 MR. SWEE11EY: Certain loads aren't required, certain 16 loads are in each scenario.

17 MR. HALL: That also plays a part as to whether you 18 still have off site power available or you don't have off site 19 power.

20 MR. MOOf1 : So in any non-external event, you would 21 get a different loading sequence on the diesel.

22 MR. THOMAS: That's right.

23  !!R . MOOti: Why should we not simulate both of them?

24 MR. HALL: We do.

25 MR. BRI!1KMidi: You didn't?

Heritage Reporting Corporation (202) 628-4888

49 1 MR. HALL: No, we do.

2 MR. BRINKMAN: You do?

3 MR. HALL: Yes, we do.

4 MR. BRINKMAN: That's what we, as I recall this 5 surveillance, originally intended to do.

6 MR. MOON: So that seems to be consistent with 7 leaving the words in instead of taking them out.

8 MR. HALL: We don't care.

o MR. MOOrl: I'm just trying to understand your system.

10 MR. HALL: Yes, we did not requevt this change. For 13 whatever reason we're still not sure of, you all wanted this 12 changed.

13 MR. MOON: Okay, you can live without the change.

14 MR. HALL: Right. We didn't have any problems with 15 it the way it was.

16 MR. BRINKMAN: We will review it.

17 Would anybody like to take break right now before we 10 start the administrative controls?

19 MR. HALL: Yes.

20 MR. BRIllKMAN : Let's take ten minutes.

21 (Whereupon a brief recess was taken.)

2' MR. BRINK!!All: During the break, I made copies of the 71 two items we discussed earlier, and I'll pass those out.

21 Here's a copy for the Reporter.  ;

'S Continuing on then with the package that I passed out j l

Heritage Reporting Corporation' j (202) 628-4888 )

50 t earlier, we are now at page 6-1 of the administrative controls.

2 MR. BELANGER: What we've got here on pages 6-1 and 2 3 and 3 are the changes per generic letter 8806. And deleting 4 specific information. Specifically, incorporating the 5 in f ormatioit in textual form.

6 MR. BRINKMAU: I looked at that earlier this morning, 7 and it appears to me is that you followed the generic letter 0 verbatim.

') MR. THOMAS: We had one question with regard to that to and that is, in the generic letter where it talks about off 11 site and on site organizations, our whole organization is on 12 site, and by on site, I mean on the same place as the station

1. 3 is located. And I don't think that the words on-site and off-14 site in our specs are really applicable.

15 And I wanted to throw out the idea of just changing 16 that to, organization, to say, the organization shall be 17 established, -. And I just wanted to get your feelings out 18 that?

19 MR. BRIUKMAU: Cal, I'm going to defer to you because lo you are far more familiar with this than I am.

11 MR. THOMAS: We could also say, the New Hampshire

'lankee Organization. But we really don't have an off site

'l organization per se. That is in line with responsible for

'l plant operation.

'5 MR. MOON: And it spells out criteria for each?

Heritage Reporting Corporation (202) 628-4888 1

51 1 MR. THOMAS: No, not really.

2 MR. MOON: Well, is there any part of corporate 3 management that is off site?

4 MR. THOMAS: Not of the line management. We do have, 5 for example, the Yankee Atomic Electric folks that supplement 6 our engineering folks that are off site. But they don't have 7 line management responsibility which this is really trying to 8 address.

o MR. MOON: But might they have in the future?

19 MR. THOMAS: I don't think so.

Il MR. SWEENEY: If that ever happens, there'll be other (2 epplication amendments that would have to be submitted, so - .

13 MR. THOMAS: The reason I brought it up is I wondered 11 if you had run into this before and had any thoughts or 13 preconceived ideas about it?

16 MR. MOON: I personally have not been in direct line 17 and generation of the generic letter. I think it's appropriate j 18 for me to make some inquiries. But my offhand impression is it  !

1 1

19 does no harm to say off site and on site that it applies to

'0 whichever you have or both right.

't Is your problem increased confusion, or?

I

': MR. THOMA3: Well, I think the way the first sentence 13 under 6.2.1 is written, it says on site and off site

t organizations shall be established for unit operation and

3 corporate management, respectively. I Heritage Reporting Corporation (202) 620-4888

52 1 MR. MOON: Okay. I understand dhat you're saying 2 now.

3 MR. BRIHKMAN: You'll look into it, Cal.

4 MR. MOON: What would you recommend?

5 MR. THOMAS: Just to say, an organization shall be 6 established for unit operation and corporate management, 7 period. And then the second sentence would say, the 8 organizatior shall include the positions for activities 9 affecting the safety of the nucitar power plant.

19 MR. MOON: Those words aren't in this package?

11 MR. THOMAS: No, they are not. I'll be glad to mark I? this up if you would like.

13 MR. HALL: What we intend to do, we're going to go 14 ahead and make this submittal. We just wanted to give this, 15 because we don't know just exactly when this other thing may 16 . happen with the licensing and so forth, and we thought that

1. 7 this was, there have been changes in the organization.

10 MR. MOON: But you prefer to make the submittal with 19 the changes.

20 MR. HALL: We prefer to make the submittal with the 2t correct things in there so that all you have to do is -- and l' send us back the paper.

) MR. MOON: Right. I'll get word back to Don.

24 MR. HALL: Okay. If you could do that and get it 23 back to us, we would probably go ahead and get this. The Heritage Reporting Corporation (202) 628-4888

53 1 reason we sent this down is so that you could see and we let 2 you know what we're coming in with, and that it will be on its 3 way down. And we'd like to get the right words in, so that -.

4 MR. BRINKMAN: You are intending to submit that then 5 as a proposed revision to the existing fuel license?

6 MR. THOMAS: Yes. In accordance with the generic 7 letter.

8 MR. BRINKMAN: In accordance with the generic letter.

9 ,

Page 6-8.

10 MR. HALL: Yes, page 6-8, what we have done is lt combined the senior vice president and president position and 12 the word should read, in lieu of NHY President and Chief 13 Executive Officer, it just should be, NHY President, and no 14 chief executive officer.

15 MR. BRINKMAN: The words in here on page 6-8, and 16 Chief Executive Officer should be deleted?

. l 17 MR. HALL: Correct.

l 10 MR. BRINKMAN: Ih all these places?

19 MR. HALL: Yes.

20 MR. BRINKMAN: Such that the change would be NHY ll President replacing senior vice president?

?? MR. HALL: Correct.

') MR. BRINKMAN: Throughout all these places.

't MR. HALL: That's correct. l 1

'S MP. BRINKMAN: I understand that.  !

Heritage Reporting Corporation (202) 628-4888 i

i 54 1 MR. HALL: All right. Same way on the bottom of page 2 6-10.

3 MR. BRINKMAM: All right, how about 6-11?

4 MR. HALL: 6-11, yes, same thing, except for one 5 other item. And let's get that one first. There are three 6 places I believe on this page.

7 MR. BRINKMAN: I see three pages up at the top of 0 page 6-11.

9 MR. HALL: Right.

10 MP. BP.INKMAN : And then the other change at the top 11 of page 6-11, 14 days proposed change to 30 days.

12 MR. HALL: Right.

13 MR. BRIl1KMAN : I think you've heard this suggestion 14 before.

15 MR. MOON: Yes. I've heard this many times. It's 16 generic, right?

17 MR. HALL: Why did I know you were going to say that.

18 MR. MOON: Or is it that everybody else can do it and 19 Seabrook can't.

20 MR. HALL: Have other people.done this?

21 MR. MOON: I believe so. Other people had this 14

'2 days spec.

2i MR. HALL: tio , I mean has anybody gotten it changed 21 to 30?

25 MR. MOON: I don't recall that anybody has. I've had Heritage Reporting Corporation (202) 628-4888

55 1 a lot of requests. ,

2 (Laughter) 3 MR. SWEENEY: What was the basis for 14 days? Since 4 we've got some experts here. Just out of curiosity, do you 5 remember?

6 MR. HALL: Yes, I mean, here are two guys that helped 7 write this stuff. I mean, --

8 MR. BRINKMAN: It was to provide a prompt 9 solidification of copies of the report.

10 MR. HALL: You feel that 30 days is prompt enough?

11 These guys haven't been with !!SARC and seen the volume of paper 12 . hat we have to go through. I mean, we had one yesterday, --

13 MR. MOOll: tio , the staff is very conscious of the 14 paper problem you're submitting. And this question's come up 15 many times. I don't think there's any formal request as a lead 16 plant item before the staff at this time, at least none that I 17 know of.

18 MR. HALL: Should we consider this a lead plant 19 request?

20 MR. MOOll: Do you have an endorsement at this point?

21 MR. HALL:  !!o .

22 MR. SWEE!!EY: I think this would be another item --

23 MR. HALL: We can put it under the short term. We

)

24 can take it to the owners group. I don't think that this is US really a high priority item. But it is a real problem to get l 1

i Heritage Reporting Corporation I (202) 628-4888 )

i

a *

,f l

56 i these thi.ngs out within 14 days. I mean, that's a lot of, paper 2 work.'

3 MR. MOON: We appreciate the arguments. And I guess 1 the other question is I think other places in the tech specs 5 are similar reporting times that other people should be making 6 also. I guess at this point, I do not know whether or not the

'7 owners group my have some proposal before the staff or have 9 been considering it.

9 MR. BELANGER: I do not believe that the Westinghouse 10 owners. group has.

11 MR. MOON: Okay. And I'm suggesting these others in I? that maybe you'd want to consider more than just this one item.

Il MR. HALL: Oh, yeah, -e can go back and look at some 11 of these things. This was the only one that's been giving our 15 folks a real hard time. And we went over this ground once 16 before. .

17 MR. MOON: I understand.

19 MR. BRINKMAN: You're not alone going over it, but as 19 I recall years ago, many others asked for longer time and it

'n was not accepted at that time. I don't know what the 21 environment is right now, but I think that Cal's suggestion l

l' here is that you may want to bundle this with other extensions.

't MR. THOMAS: One little word of background just for

t your information, that part of the reason for the request is

'. % that the guys do a very very nice job. They do a ery thorough Heritage Reporting Corporation (202) 628-4888

57 1 job and a typical package would be about the size of this 2 handout. I mean, it's probably 12 to 15 to 20 pages of 3 handwritten material from the meetings, and that's part of the 4 reasons where it's a burden, not at all times, but occasionally 5 to get it out within that time frame. And that's really the 6 basic for the request.

7 I think we hear what you're saying, and if that's the 9 way you feel that it should be treated, then that's the proper 9 way to treat it.

In MR. BRINKMAN: That takes us to the last page of my 11 package.

l' MR. BELANGER: Excuse me. Why don't we fiaish this.

!? MR. BRINKMAN: All right.

1 -1 MR. BELANbER: This should have been part of what as 13 just discussed. This page 6-5 was inadvertently omitted from 16 the other organizational changes that you have received from 17 us. The position of executive assistant has been incorporated 18 into the vice president of engineering, licensing and quality 19 programs and therefore that title change should be made on that l 29 pace. I 11 MR. BRIUKMAU: All right, this is page 6-5. If we 2' want to take a two minute break here, I will go make copies of

.D it and pass them out to everybody.

11 MR. THOMAS: Yes. Well, one other question. Did you 1

'S want for your benefit e mark-up of the proposed 6-2-1 which had l l

Heritage Reporting Corporation (202) 628-4888 l l

58 1 to do with the on site and off site org6nization to just take a 2 look at? That's the item we just discussed.

3 MR. BRINKMAN: We just discussed that. I was under 4 the irpression that you were going to go back and --

5 MR. HALL: Well, Cal was going to talk to his folks 6 about the on site off site thing.

7 MR. BRINKMAll: Right.

8 MR. THOMAS: But I can give you a mark-up just for 9 your benefit as to what we might propose to solve the problem.

I 10 It's fairly simple to do.

11 MR. SWEENEY: I think that's a good idea, so that l' C31, when he has the opportunity to talk to his folks, he at L3 least knows what we intend to propose as the change.

1 -1 MR. BRIllKMAll: That's fine.

15 (Whereupon, a brief recess was taken.)

1. 6 MR. BRIllKMAN : All right, I just passed out copies to 17 every one of page 6-5, Administrative controls, and a licensee 18 proposed change to clarify their organization of on site and 19 off site of their submittal that they gave to me yesterday for j 20 the organization changes in accordance with the generic letter.

1.1 I think that we're ready to proceed onward or have i 22 you got something, Rob?

'l MR. SWEENEY: Are we finished with this package now?

't-MR. HALL: We don't need to go over 6-5, do we?

15 That's fairly clear.

Heritage Reporting Corporation (202) 628-4888 l l

59 1 MR. BRIUKMAN: That's just title chang'es.

3 MR. SWEENEY: And the laat page, the bases of Section 3 3.4.1.2.

4 MR. HALL: That's to do with the charter itself. We 5 will carry on with that when we decide what we're going to do 6 with the other thing.

7 MR. BRINKMAN: All right, fine.

8 Earlier, you gave me two pages which I have made 9 copies of. One is on the remote shutdown system, page S\4 10 3-47, which I'll pass oct now. This has to do with the remote 11 shutdown instrumentation.

8. ? Would you care to explain that one to us?

[3 MR. BELAUGER: '?here was an error which occurred in

!! the development of this table initially for the Seabrook tech 15 specs. The T sub-C and T sub-H were previously listed on one 16 line with the location listed as CP108A and B. They were later 17 split to two lines, one carrying CP108A and one carrying 10 CP108B. Each one is located on CP108A and B. So it's 19 correcting an error in the table.

20 MR. MOON: And that's consistently two channels.

21 MR. BELAUGER: Yes.

22 MR. BRINEMAU: The other page is page 3\4 6-3. And

'3 this has to do with containment leak ray testing.

'l MR. HALL: Yes. And what we're doing here is we're

'5 deleting the words, "using the methods and provisions of Heritage Reporting Corporation (202) 628-4888

l 60 1 ANSI \N45.4-1972," based on the recent issuance of a rule 2 change.

3 MR. SWEEMEY: That's a proposed rule change.

4 MR. HALL: Is it a proposed? It's the proposed rule 5 change to endorse mass point balance analysis. We are 6 proposing that you delete using the methods and provisions of l

7 ANSI \N45 too because if you read Appendix J to 10 CFR 50, it l

0 refers you to ANSI \Section 3 and Section 3 says you have to use

') isNS I'sii4 5 . 4 - 19 7 2- .

l 10 MR. SWEEMEY: In essence, this already as exists is 11 redundant to Appendix J.

1 12 MR. RALL: It's redundant to Appendix J and by I 1 3 deleting it, when and if the new rule is approved, we won't ,

14 have to make any changes then or at that point in time, either.

15 MR. THOMAS: And likewise, if the rule isn't 1 16 approved, it's included. )

i 17 MR. HALL: If the rule is not approved, we still have 18 to do what Appendix J says with regard to section 3.

19 MR. SWEENEY: And N45.4.

20 MR. BRINKMAN: So all you're saying is i'.s redundant.

l

?1 MR. RALL: It's redundant.

22 MR. SWEEMEY: And affords flexibility later on if and 23 when the rule change that's been proposed goes through and the 14 likelihood of that la cretty good from industry indications.

", MR. BRINEMAN: Did you, by any chance, go back and  ;

i l

Heritage Reporting Corporation  ;

(202) 628-4888 l

, 1

61 l examine when ANSI \N45.4 was put into Appendix J?

2 MR. HALL: No. We just went and lcoked.

3 MR. BRINKMAU: I think was originally put in the 4 surveillance here before Appendix J was revised to include 5 that. I think that's why we put it in the tech spec. I don't 6 remember for sure.

7 MR. HALL: I couldn't tell you. All we did was we 8 went and luoked in the Appendix J and then went and looked in 9 the ANSI, and it was there, so we said it's redundant. And if 10 we went ahead and make this change and if the other rule is 11 approved, and we're fat and happy.

1? MR. MOON: Well, if the rule is implemented, will l

1) there be other changes to this section?

14 MR. HALL: I don't think so. Our people that take 15 care of this did not indicate. They indicated that this would 16 satisfy any problems that they might have.  ;

i 17 MR. MOON: I've had indications in other tech spec ,

i 18 reviews that people thought there would be other changes in 19 this section apart from that one. It seems to me like all 20 you're asking for is to take it out now to avoid changing it l

21 later. l

?" MR. SWEENEY: This is better not only to us but also 23 to the MRC administrative changes that would be required, j

?' MR. HALL: Well, it is redundant also.

25 MR. MOON: It's redundent and does no harm being in l

l l

Heritage Reporting Corporation (202) 628-4888 l

l l

62 I there.

2 MR. HALL: Right, but it would save a problem later 3 on.

4 MR. BRINKMAN: Cal, in their defense, you say it 5 would do no harm to have it in there. It does harm if we leave 6 it in there, and Appendix J is subsequently changed to the lead 7 reference to this, then this says you'd have to according to 8 Appendix J using ANSI \N45.4-1972 in that they would be required 9 to do the retesting in accordance with that if Appendix J is 10 subsequently change 1 to give them other options. In that 11 light, it does them harm, and if in fact, Appendix J already I? includes this as they indicated and I suspect it does, I

) .1 haven't looked at it for a long time, taking it out probably 11 does no harm at this point.

15 I don't know. You are the current resident expert on JG tech specs. I'll defer to you.

17 MR. MOON: Let me take this as an item that I'll 10 research.

19 MR. BRINKMAN: Anything else?

20 MR. THOMAS: We thought we might give you heads up on 21 a couple of other areas that we're looking at with regards to

?? tech spec changes. They weren't included in today's packet but

?1 we are looking at them down the road.

'i.

Are you in a position to talk about those?

25 MR. HALL: Let me find my piece of paper. One of l

Heritage Reporting Corporation (202) 628-4888

63 1 them, Cal, is the electrical spec 3.8.1. We don't have any 1 marked up here, but if you'll recall, we had that go around and

~

3 we made the change in there and knocked 72 down to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for 4 one of the allowed outage times and Sandy was the one, Sandy 5 Israel was responsible for thet, if you'll recall.

6 MR. THOMAS: Let me be more specific. The present 7 configuration at Seabrook Station has two off site power lines.

8 And as a result of that, you folks opted to limit the alleved 9 outage time for or.e of those lines going out of service from I 10 believe it was the standard spec of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> down to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

11 And at that point in time, we indicated to you that we'd be 1 ;' back at the point in time we put in the third line, if you 1? recall, the second line was deferred due to financial  ;

q 14 considerations -- excuse me -- let me reclarify that. Due to 15 permitting considerations combined with a need for the line at 16 the time, or at least a perceived need for the line at the 17 time.

18 Subsequent to that, the decision has been made to go 19 ahead with the line about the time frame that we expected. The 20 line is being installed right now. It's expected to be into 21 service in the very early part of the third quarter of this 2; year. And at that point in time, we would propose that the 11 allowed outage time for a single line be that of a standard

'l tech spec, which would be the 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

J

.' 5 MR. MOON: For three lines being operable?

i Heritage Reporting Corporation (202) 628-4888

9 64 1 MR. THOMAS: For the condition with three lines 1 operable, that's correct.

3 MR. M00ti: And then you would want a two-tier thing 4 so that if two of them were out, it would be 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />?

5 MR. HALL: No.

6 MR. THOMAS: I think we'd have to look at the 7 standard spec with regards to that.

9 MR. HALL: I think we'd still like to go back to the 9 argument, and I don't believe that as I stated long ago and far 10 away, we had a real hard spot with Sandy's justification for 11 reducing that from 72 to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> based on what we saw that he 12 wrote. And still feel that he was way off base and don't feel 11 that his technical justification was adequate to justify

~

14 reducing that because outage times with six systems have 15 habitually shown that if you fa'li an SF-6 system, you're out of 16 line for two weeks.

17 And what ehe tech specs is looking for is switch yard 18 failures, things in your switch yards, transformers, breakers, 19 that type of things. And the SF-6 is not something that you're 20 going to repair in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. And for whatever reason, we never l 21 understood, and still like to revisit that is the fact that the 22 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, if you fail a breaker, you may not be able to fix it l l

't in 24, but you can fi:: it in 72 or 36 or 48. And it's severely

t limits us for no real particular reason other than the fact

5 that Sandy had an idea.

Heritage Reporting Corporation (202) 628-4888

65 1 MR. MOON: Okay. I guess I'm confused as to what 2 your proposal is.

3 MR. HALL: Well, what we're going to propose is we've 4 got three lines coming back in. And that was the condition 5 that Sandy put on us. He sajd, well, when you get the third 6 line available, come back and visit us and we'll see about 7 changing it.

O And we're going to come back in based on that, and 9 we'd like to look at some probabilities here since he figured in that that was what he used to reduce the 72 to 24.

11 MR. MOON: Well, is your proposal going to be to have )

C' on LCO that says two must be operaole on a 72-hour outage  ;

sustainment?

11 MR. HALL: Basically, yes. l 15 MR. MOON: Even though you have a third line.

16 MR. HALL: Even though we have a third line. j 17 MR. MOON: So you're really asking to revisit the 19 probabilistic assessment?

19 MR. HALL: Asking to revisit the probabilistic ,

I 20 assessment.

't MR.* MOON: Okay, that probably involves significant i

staff research.

MR. BRINK:!AN : Sure does.

'1 MR. HALL: Well, we reali e this would have to be momething efter --

1 Heritage Reporting Corporation (202) 629-4888 l

e . .

l l

66 t MR. MOON: The reason I suggested the 72 and'the 24 2 as an alternative to revisiting the risk assessment would be go 3 ahead and put a two level action statement in with two 4 different times, depending on whether one or two are out. <

5 MR. THOMAS: That might be an interim step. Let us 6 take a look at that.

7 MR. HALL: Okay. I think that might be 8 entertainable, yes.

9 MR. MOOll: I understand that your feelings are strong [

lo on the risk assessment. My recollection was that the staff was 11 considerably strong in its conclusions. I would see that as a I? significant effort. .

j 11 MR. THOMAS: Okay.

i 11 .

MR. MOOll: It's not that we can't do it, but --

15 MR. HALL: Okay, we appreciate the perspectives here, 16 and that's the reason we brought it up. We could propose  !

I 17 something, or wili look into proposing something once that line la is in and up and it should be, what, June?

4 19 MR. THOMAS: I would expect it will be in full 20 service by July. It might be at the end of June, but certainly i 21 in full service by July.

MR. MOOT!: Then you'd anticipate a submittal in July, i 23 MR. HALL: Well, we'll look at the schedule as we

'l-approach getting this line in, we'll see what the schedule is 2's with o five percent license and so forth. We'll be back in i l

i Heritage Reporting Corporation I (202) 629-4889 I

. , c .

67 1 touch regarding that point.

' MR. MOON: Fine.

3 MR. HALL: One other area that I wanted to touch base 4 with you guys on, and I'm not sure whether you're fully up to 5 speed on it. Maybe you are, but I know we are doing a e, modification to our control room ventilation system. And as 7 part of that, we're going to have to change the tech specs.

I 8 The staff is currently reviewing the proposed modification, and 9 I think we have some questions that we have to provide some 10 answers to the staff on. We're going to make sure that 11 everything is okay, and that all the questions are answered for t .' the staff and they're happy with our design. Then we'll get il some proposed tech specs in here.

11 But I did have a question up front.

15 MR. MOON: Do you have a proposal to amend the FSAR?

10 MR. HALL: When the staff finishes with the review of 17 the proposed design, ue will submit an amendment to the tech 18 specs.

(9 MR. MOON: And also modify the FSAR.

20 MR. HALL: As necessary, yes. They are reviewing the

'l modification now which includes proposed changes to the FSAR.  ;

1 Ali of that's there. l MR. SWEEMEi": We intend to finalize that techni al M cochoge very soon and wa'll follow up with an official tech spec request as a result of staff review.

l l

Heritage Reporting Corporation 1 (202) 328-4088  !

68 1 MR. MOON: I guess somehow or other the tiro ought to 2 be before the staff at the same time, all in one package. The 3 tech spec and the design change.

4 MR. HALL: You can't put out a proper tech spec until 5 you get the designed approved.

6 MR. MOON: Well, you can have the proposed tech spec 7 so that the reviewers are looking at it while they are looking 0 at the design.

9 MR. HALL: That's something I think that we have to 10 decide.

11 MR. SWEENEY: The tech spec always follows the design  !

1 '.' because that's how you implement the limits of the design. And 1.1 we've taken a two prong approach and that's the best approach

1i in my mind.

t 15 MR. HALL: Processing these things through our house l 16 to get them to you is as laborious for us as it is for you to l

17 process them through your house, so that the number of times we in have to process them as you is preferable to keeping them to a 19 minimum, so that's why we're proposing this.

20 But one of the questions that I did want to ask if a

21 you've got yours there, if you look at page 7-16 Excuse me.

22 surveillance Requirement A. Control room area ventilation

?) systems shall be demonstrated operable at least once per 12

/1 beitrs by verifying the control room area ventilation system is

- > maintaining the temperature of equipment instrumentation the 1

Heritage Reporting Corpo'ation (202) 628-4888 2

e i

69 I control room area below its limit equipment qualification, 2 temperature.

3 Since we and most of the new plants and probably the ,

4 old ones too are beginning to get these tech specs that have 5 the area ' temperature requirements in them, we were looking or 6 entertaining something here in this surveillance that would 7 read to the effect, at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of verifying 0 that the control room area ventilation system is maintaining 9 the temperature of equipment and instrumentation in the control 10 room area in accordance with the requirements of Technical 11 Specification 3.7.10, which is the area temperature monitoring 12 tech spec.

11 It would certainly take away some confusion and tie l

4 1I us directly to what you're looking for with regards to what 15 this is supposed to be.

i 16 MR. MOON: I'm not sure that I understand what your 17 change is really saying.

in MR. HALL: What we're saying is that this  ;

19 surveillance would be tied directly to the requirements of 4 20 specification 3 7.10, tech spec 3.7.10.

j 21 MR. MOON: That's where I get lost. ,

, i 22 MR. HALL: Why is that? l 1

1 23 MR. MOON: Because Tech Spec 3.7.10 doesn't tell you

'I anything about the temoerature of the control room -- oh,

/5 areas, okay. Okay. These are the starting temperatures which Heritage Reporting Corporation (202) 628-4888 l

o . ,- r -

70 t would assure.that you do not exceed the equipment qualification-2 temperatures. .' l 3 MR. HALL: Right. Yes. And by so doing, that will 4 ties us to doing what's there if we exceed the 75 degrees, they 5 wouldn't have a lot of --

6 MR. MOON: Now, the control room area ventilation 7 system serves some but not all of the items listed in Table 37-8 3, is that correct?

? MR. HALL: The control room area ventilation system

.t o serves some of the areas but not all of what?

11 12 13

.l 4 13 16 17 18 19 20 21

-) ?

13

'l 23 Heritage Reporting Corporation (202) 628 4888

71

. i 1 MR. MOON: Of the items on Table 37-3 ,

2 MR. HALL: It's kind of difficult to explain without 3 the whole system diagram in here.

4 Excuse me, go ahead.

5 MR. BELANGER: What we're actually trying to do here 6 is make it clear that these two specifications cascar.e.

7 MR. RALL: Right.

8 MR. THOMAS: That's been a source some on site 9 confusion but I think some undue effort on our part and it 10 would just clarify it.

11 MR. MOON: Let me ask you this. If you simply did as 12 the other tech specs do, have a single temperature like 80 1.1 degrees or under 20 for the control room, if you had a l 14 specification 37-6 of 75 degrees, it would be possible that i

(S some other areas served by that ventilation system could exceed I 3 r, a temperature 'in this table, is that you're suggestion?

17 MR. HALL: Say that again. ,

18 MR. MOON: If you followed the pattern for most 19 recent NTOLs, you'd simply put a temperature of 75 degrees in -

20 here. j 21 MR. HALL: Okay.

22 MR. MOON: For the control room area itself, right?

23 MR. HALL: Okay. l l If you did that, then am I to understand 21 MR. MOON:

l 25 that you're saying that would not necessarily insure that you i

j Heritage Reporting Corporation (202) 628-4888

_____________________1_______

V 72 1 might not violate one of these other temperatures?

2 MR. RALL: No. The problem we have here is that the 3 cooling effect in the control room is controlled, is different 4 as it's tied into the control room area, the control room r, habitability system. The control room habitability system and 6 the air conditioning system that keeps that room cool are tied 7 together. They are not in I guess more or less a parallel 0 situation would be more apropos than a series situation, than a 9 series hook-up. Such that you could lose one train of your 10 control room habitability system and maintain control room 11 habitability and still maintain both, maintain appropriate 12 cooling, okay, of the control room equipment.

13 Conversely, we could maintain both trains of our 14 control room habitability system but lose a control room 15 chiller which would force us into a tech spec action statement 16 that is not really applicable.

l' You follow me?

19 MR. MOON: Well, not completely. The purpose of this 19 surveillance in specification 4.7.6 is to assure the 20 operability of each of.the trains.

21 MR. HALL: Of the control room equipment.

22 MR. MOON: Of each of the trains.

1 23 MR. HALLt Ch, yes.

24 t1R . MOON: Each train by itself or --

25 MR. HALL: That's what I'm saying. This is

' Heritage Reporting Corporation (202) 628-4888

73 1 incorrect. It shouldn't be like this. If at least once per 12 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> you have to verify the control room area ventilation 3 system is maintaining the temperature and equipment and .

t 4 instrumentation in the control area below its limiting S qualification temperature, I don't have any problem with doing 6 that 7 MR. MOON: Okay. Well, I'll withdraw what I said.

8 The current tech specs in most p] ants simply say demonstrate 9 that the temperature is below such and such value, which does 10 nothing to tell you about the operability of the equipment.

11 MR. HALL: Okay.

j I? MR. MOON: But now if you try to make it into a -

13 surveillance that does say something about the operability of 14 the equipment, that's what you're trying to do, right?

13 MR. HALL: Yes. No, that's what I'm trying not to 10 do, as far as this.one is concerned. Because I can maintain 17 control room habitability, both trains, I can have both trains

[

18 of my control room habitability operational, operable, whatever 19 you want, and meet these LCOs just fine, I can lose a chiller, 20 if you will, and still maintain my control room habitability or 21 still maintain my control room temperature below 75 degrees

?? without losing two trains of my control room habitability 23 system and I don't want to be forced into an action statement 24 because I lose a chiller and still have both trains of my 25 control room habitebility system available.

Heritage Reporting Corporation (202) 628-4888 i

-. - , _ . . - - -. ......--.i

~ ,

74 1 I would like this to be tied to the control room 2 temperature, you know, the area temperature monitor the way t 3 it's meant to be, what we're actually trying to do here. And 4 my control room habitability system do what it's supposed to do [

5 here.

6 MR. MOON: Am I correct that in part what you're 7 suggesting is making generic correction to the standard tech 8 spec?

9 MR. HALL: No. This is in no way generic. This is 10 plant specific procedure. It is not generic unless UNC decides

-1 .1 ' somebody else is likely to do ours.

!? MR. MOON: Well, the present --

13 MR. HALL: I'm not trying to get out of doing it anything. All I want to do is get the right thing applicable 15 to the right spot.

16 MR. MOON: -- the present technical specifications do 17 not really address the question of air conditioning ,

18 performance.

19 MR. HALL: That's correct.

20 MR. MOON: And yet that is an important function.

I 21 MR. HALL: That's correct.

l 12 MR. MOON: And in your proposal, you're still not 23 going to try to correct that lach in the present tech specs?

24 MF. HALL: Well, no. That's what area temperature i 25 monitoring tells you to do. You have to maintain those areas l

l Heritage Reporting Corporation (202) 628-4888 I

)

a

75

> 1 at temperatures les: than or equal to whatever the equipment .

2 qualification is in those areas.

3 MR. MOON: But that's not the design basis.for your 1 air conditioning system.

5 MR. HALL: No, that's not the design basis for the G air conditioning system.

7 MR. MOON: I thought the design basis for air -

O conditioning systems take care of the heat moisture in the 9 incident.

10 MR. HALL: Depending on the area.

1.1 MR. MOON: Yes.

1? MR. HALL: Depending on the area, that's right.

• 13 MR. MOON: And that also enters into the lei qualification question.

15 MR. HALL: That's right. And that's why ours is I

1. 6 designed to control and maintain the temperature we have over 17 here.

i 18 MR. MOON: During normal steady state operation.

19 MR. THOMAS: Dormal steady state operation and the 20 worst initial conditions. In other words, your highest 21 temperature.

f

2? MR. MOON

But what I'm trying to put together is the j i

l 23 question of whether you succeed in doing what you intend to do l M during the incident is question both the initial temperature l and the performance of the air conditioning, i

i Heritage Reporting Corporation (202) 628-4888

76 1 MR. HALL: If we have to bottle up the control room, 2 the air conditioning is usable and will maintain the equipment 3 at 75 degrees or less.

4 MR. MOON: There's nothing in the current tech specs 5 that covers the performance of the air conditioning.

6 MR. HALL: No.

7 MR. MOON: Were you proposing to put that in?

8 MR. HALL: No.

') MR. MOOll: Do you understand what they're proposing?

10 MR. BRINKMAN: No, not totally.

1.1 MR. HALL: I'm not trying to change anything what

1. 2 you've got here other than to get it to the right spec to what 13 it's supposed to be doing for Seabrook. I'm not trying to 14 ch, ge anything. I'm not trying to short circuit any tech spec 15 or requirement that's there. I'm just merely trying to tie the 16 correct surveillance to the correct spec.

17 MR. MOON: Okay. You essentially are saying you want 19 to make these temperatures the ones that apply to the correct 19 surveillance?

20 MR. HALL: This temperature. This temperature right 21 here.

22 MR. MOOll: Just one temperature?

13 MR. HALL: Yes, that's the only one. This control 11 roon habitability system, we want to tie it to the requirement 25 of this, of this spec, 3.7.10.

Heritage Reporting Corporation (202) 628-4888

+l .

77 1 MR. MOON: Well, why don't you just put 75 degrees in then?

7 3 MR. HALL: Because, this, if I do that, that says 4 that if I lose part of the my habitability system, then I've 5 got to go into an action statement, which is fine. But if I 6 lese an air conditioner and graze about 75 degrees whether I've 7 got both trains' of my habitability system available or not, 1 0 have to enter this action statement. And they are not the 9 same. They are parallel. systems.

10 And the habitability system has nothing to do with 1.1 the HVAC system to that extent that it is necessary to maintain

1. 2 habitability.

13 MR. MOON: The area affected by the control room area 1l4 ventilation system by implication of surveillance A includes 15 equipment and instrumentation.

16  !!R. HALL: Yes, in the control room.

l' MR. MOON: And I thought that was equivalent other 10 than in item i here?

l? MR. HALL: No. This is what --

20 MR. MOON: Doesn't include cable spreading room?

'l MR. HALL: No. Cable spreading room has its own  !

22 number. Hes a separate ventilation. i 13 MR. MOON: Okay. So again, why is it you can't

'l-simply put 75 degrees in here instead of tieing it to a tech 15 spec? i Heritage Reporting Corporation (202) 628-4888

o .  :

9 2

70  :

i 1 MR. HALL: If you read this, this says, if one  !

W j 2 control area ventilation system inoperable, restore the i 3 inoperable system to operable status within seven days or be in 4 hot standby within the next six hours and cold shutdown the l 5 followino 30. There is no action statement for two being i

l 6 inoperable, okay. Which leads me into 3.0.3 which says I have 7 to shut down. This says with one inoperable. -

t 0 But if I lose a chiller here, my other chiller is

? still capable of maintaining my control room temperature at  !

l to less than 75 degrees, I have not lost the capability of having i t .1 two trains of control room habitability, so I'm saying by -

1? changing this, this says the surveillance requirement has to t? comply with the technical specification 3.7.10, I'm tieing the  !

i 14 cooling to the spec that it has to be tied to.

J 4

L5 And the habitability spec still re5ains the same. If l

16 I lose one train of habitabliity, I've got seven days to get it 17 back. If I lose both -- I l

19 MR. MOON: Is what you're proposing any different ,

1

19 than simply eliminating surveillance A in this spec? j i l 20 MR. HALL

No. We could remove it, put it over

21 there.

] e dR. SWEET!EY: Yes it is.

J l 23 MR. IIALL : Yes, it is. You still have to do this, a 14 MR. BELANGER: It's more restrictive than just 25 eliminating surveillance A because if you get into a situation 4

. Heritage Reporting Corporation (202) 629-4888 l

1

79

I where you've exceeded the action statement of specification i

2 3.7.10, now you're in a situation where you have action under 3 3.7.6, also. Because you have not met that surveillance, 4 either, 5 MR. MOON: Are you saying this is more restrictive l l 6 than the other?

l

7 MR. BELANGER: The action for this is more 1

i 8 restrictive than the other.

? MR. HALL: But this action's not applicable with what  !

i a 10 we're trying to do here, for that spec.

J 11 MR. BELANGER: So by referencing this from here, you

1. 2 keep the more restrictive actions as are appropriate for the ,

13 control room ventilations. However, you make clear the

14 temperature requirements for area temperature modules.

j 15 MR. MOON: Maybe Don disagrees with me, but I think l 50 in general we would rather see you keep it within this spec, 1

l J

17 even if you have to rewrite the action statement, rather than l 1 4 10 have them cross connected. l j 19 MR. BRINKMAN: That's generally true, Cal. And ve 29 tried to make these specs more stand alone than willing them

'l together.

1 i

22 MR. MCON: You could do that by modifying your action 1

4 1

23 statement.

't MR. HALL

I don't know. I think what you really

'S want to do here is if you can't keep your control room at 73 i

Heritage Reporting Corporation l (202) 628-4888

80 1 degrees or less, you want to do what's over here. If I can't r

2 maintain the habitability of this control room, then I want to f 3 do what's here.

4 MR. THOMAS: So what you're saying if you can't j 5 maintain the habitability temperature of the control room below G 75 degrees, you want this spec to drive it as compared to your 7 other spec?

n MR. HALL: No, if I can't maintain it below 75

'I degrees, I want the other spec to drive it, because I think the to standard was written assuming you have an intake that intakes 11 air in through a chiller, through a filter, then through the

!? chiller, and then dumps it in. We don't have that. They're i1 independent to the point that we take air out of the inside of l 1

11 the building 'that's pumped inside through this system and tL cooled, and pump it back in and mix it in with the outside-air 16 and dump it into the control room, a

I 17 MR. BELANGER: Making the change to surveillance A, I 19 although it does cross tie to the other specification, is in j 1? our opinion less of a deviation frcm the standard than trying 20 to rewrite these actions to cover all the various situations.

11 It's more in keeping with the standard specification.

'? MR. HALL: There are instances in other surveillances j 't where they do cross reference.

't MR. BRINKMAN: I know that. i I

S MR. HALL: And we had quite a lengthy discussion 1 l

4 Heritage Reporting Corporation

(202) 628-4888 I i

. . i.

81 l yesterday, our technical people and engineering people, and 2 felt that this was probably the best way to approach it without 3 totally rewriting the whole tech spec, that this would be the 1 easiest way to do it.

' MR. BRINKMAN: I guess my thoughts are, I know of the 6 work that's going on to redesigning the control room 7 ventilation system. I think I would suggest to you that when 1

0 that's done, review your specs and come up with something.

') MR. THOMAS: That's what we'd do anyway.

10 MR. HALL: Okay. We just wanted to throw this out to 11 see what kind of feedback we'd get, so we don't have to rehash

.t : this when I come down with the other one.

1. ) MR. THOMAS: And that's fine. I think it isn't 1t something that you've been doing just by your reaction with (T other licensees and --

In MR. HALL: No, I think because the standard tech spec 17 was probably written for a system that takes it off an intake

1. 0 through a chiller or through the filter, then through the i  !? chiller, and then dumps it into the room.

20 MR. BRIUKMAN: Yes, It was written as one system --

at MR. HALL: As one continuous system, that's right.

' And ours is different. We don't do it that way. Especially 21 with this redesign, it's really changing things around here.

'l And this is an ideal time to try and get this thing

'5 straightened out and make it do what it's really supposed to Heritage Reporting Corporation (202) 628-4888

. . ~ .

8?

.~ 1 do. ,

2 MR. MOON

When would this submittal be?

i 3 MR. HALL: We've got one more some answers to some J questions to get down here to the staff and once that is dono 5 and the staff gets their SER completed with regards to the 9 6 design of the system, then we'll_be right after that with the 7 tech specs.

9 MR. BRINKMAN: Anything else?

? MR. HALL: I don't have anything else unless you guys

) 10 do. That's it. l 4

a

, 11 Anybody else?

l .' MR. THOMASt I just wanted to express our  ;

4 13 appreciation to come in here and talk to you folks about this r

14 before we send paper back and forth because of the fact that

, 15 it's saving your resources and saving our resources in sending 16 paper back and forth. And this meeting's been very helpful in l

17 trying to get some of these things straightened out. i i

10 MR. BRINKMAU: Well, thank you, George. I think it i 19 has been worthwhile. ,

i

, ?O I have nothing further. t I i

?! And I think the meeting's adjourned.

': (whereupon, at 3:30 p.m., the meeting was adjourned.)

?J I 'T ,

4 t

?5 l

1  ;

] Heritage Reporting Corporation {

(202) 628-4888 I i

4  !

l 1

- _ _ _ . , . . , . _ _ _ . , . - _ _ _ _ _ , . , _ . - , _ __m. .

1 CERTIFICATE 2

3 This is to certify that the attached proceedings before the J. United States Nuclear Regulatory Commission in the matter of:

5 Name: .!EETING ON TECH!!ICAL SPECIFICATIONS FOR SEABROOK 3

7 Docket Number:

6 Place Rockville, !!aryland 9 Dates  !!ay 4, 1989 10 were held as herein appears, and that this is the original 11 transcript thereof for the file of the United States Nuclear 12 Regulatory Commission taken stenographically by me and, 12 thereafter reduced to typewriting by me or under the direction 14 of the court reporting company, and that the transcript is a W

15 true and accurate record of the foregoing proceedings.

15 /S/ hbbNb$h 17 (Signature typed):

!!akgaret Daly /

18 Official Reporter 19 Heritage Reporting Corporation 20 21 22 23 24 25 Heritage Reporting Corporation (202) 628-4888

53...=:= 4;ds w

.:N!707:4G IN!?iL9!NTA7?CN

!!!!w!: INSitudENTAit:N

...w:..se

. a...sn'7tes.i ;3.- r.4 ; . :. t . . .y I

t 3.3.3.3 -

.r:...... Ihe selsnia :nitsria; instrumentati:n sh:=n in I4: 14 3.3*7 shall te A : : t. .? .* s .: ' '. .' '. < .- A *. a l l '. t.=. e s .

3....q 4.

Vi*h One Or e rt of the a:cve required sef ssi 4

in:: era 1e f:r ?:re than 30 cays, pre:are sn: contt: ring insty;.,3 3 It: swamit a 5:e:ial Ort to the C mcission ;wesuant t: $;ecification 6.3.2 within tne next 30 cays evtlining the cause of the malfunction and the plans f P rest: ring the lastrument(s) t: Of fili (! status.

b.

The ;r:visi:ns of 5:e:1ficattens 3.0.3 and 3.0.4 are act a:;11:atle .

c.';v ?.. t. '.i se. .r : .r.g t : .:w.ryis 4 . 3 . 3 . 3 . '.

Oe :rstrate:f a:5 Of t.'e ateve re:vited seismic :enit: ring instru ents shall te E17!!N. 07!IA!Li by the :erf er?.an:e Of the CMAhME'. CMECX, CAL'- CHAhh!$.

T4:!e 4.3 and 4 A.5At0G CMAh5EL 07!iATI:hAL I!Si at the fre:ven:ies

. s 4.3.3.3.3 curir.; a seisit !ach Of tytnt the;rtateraseveinia Pteuf

e red seis.

equal t: tic :: nit:rit,; instrunents actuated g i %_....'ss

. . with 1 2 g 'ta 't that **t Uit! ;" "0.01 ; shall be_res*:re0 1:

w _, . .. ._.. . . =

. .. 5

AL is.A*!;n

ert:ree: _

n..r:g 4 64 s ;...t

. w ..m. ........ J anc a . LNh*,'-

l within 30 cays f lleving the sels:i: event. 'ata te rett *t.e: ft:- a:tua'e: instetten'.s and analy:e3 t: :eter;.ine the. tagnita:e shall  ;

f tne vi: rat: y grown: metien.

-itte: : ine :.missi n :vesvant t:A 5;tetal Re:cet shall te Ort:ared an: su -

5:ecificati:n 5.3.2 witnin 14 cays ce-5:ri:tr; tr.e cagnituce,

'estares it:Oriant t: saftty. frequency 5:ettrum, and resultant eflect u::n fa llity i

i l(

stit:::( - .s:: ;

3/4 3 41

?:a .. i. r 1. .1. ? ..

c

?. c..w '..

wa.s.-. : 's-u

.?yc. :....w:w : . . s W.? .s '. w'..w.

. w r a.e"w

. .s :.w e .s . t.s Sis,.w

. .. es .:

a

. s e. :". w e. s ; c. a s. e. r s i_ :4.sc:  :::A: :

. c__t ,, 4.. c t ? ?. . s e. .

. 7eiaxtai ?!:e-Mist:ry A : tier:gra:r.s 2

a, '. !M-47 5700 ~ rte Fiel: ast C:nt. ~

1; .'

1 4::s Air Intate ,

. *.-iM-17 57010:ntairment ~ ur. cati:n  : 1; '."

. *.!M-17

. 57*.0 C:nt. C:r. F10:e  : .; '."

J '. Triaxial Peak Ac:eler:q,ra:ns

.'l3% ev.a ti:n (-) 6 ' 0" 4

3. . ...

. w . z .z . i t ,., c, Ac cu.mu.a:or. ."ank. .S.I. .TK-9C

.f

. . s .3 . .

1. ..... . ...- ----- - . .

(

Safe y ja--d-

. '. iM-xR 5703 '....1 Ilei.~'Tii,ing.

0 20 n:, '

Eleva: ion (-)24'0"

. ' !M-tR

. 5704 PCT 4 Pi:ing 0-20 m:.  ;

,i

3. Triarial Seise.i: 5 it:nes ,

4. 1-iM-X$*5700 Frtt Field N.A. l'

. '. !M-X5-5701 C:ntai- ent F:encation N.A. .

1

. 1 iM-X5 i709 Centair.aen F:eneatien 0.025; : 0.25;

O. *.- iM- tS 67'.0 Cent. C:r. F1:ce N.A.  ;*

a. Triaxial Res::nse-i:ectt.m Res:r:ers l 4. '.-i.w-tR-5705 C:ntair. ment ~:uncation 1 10 M:. . i 1

C I w.gs. 3 , . 6 . .# "'.*.*.'i...

- ="~ * ..". *.1 * ""d *

• i * * " .*i .s 4 ..*, .3 ; 'IE' 91 '

Elevati:n (-)26'0" I

. * .iX-XR 5707 Pri.s. Aux. Ele;. 1308:. i l

. .-iM-XR 57CS Service Va ar ?vm: H:use 1-10 M:. 1 1

1 1

i l

I i "wita react:r ::ntrol r::s incication i

SEAARCCK UNIT 1 3/4 3-42 ,

I i

4

.. m

. l

• . : .: . .C 4.14 f Of.*.**fw C. f. *. t. u t. *. w..N . * .* * ' .N C '. N C. ' !'. .w f. % * : ' '. *. N i. :. t 'j f. '. *. *. ; N .* !.

, . ... q .

N4L

G C -a h h i '.

..e AN N :. :. .u. .s ss:1

. v r :. :. A T '. . s : ,.

9571Lu!N75 ANO $!NSCR '.CCA*: NS C:d ! * ( CAL !:AT*:N 7!*?

.. Triaxial Ti:t-Hist:ry A::eler:gra:ns

a. '. !M-XT-5700 Free Field East C:nt. M' R SA i::: Air Intake

. ' !M-xi-6701

. C:ntainment F:uncati:n M" t N. A.

. '. SM-XT-5710 Cent. C:r. F10:e M" i N.A.

C. Tria2ial Feat 'ac:eleregra:ns Accur.ula::: ' Tank SI-TK-9C

a. *. 5M .tR-6702 *: .; .; r !:::: * :::-; . N.A.

Eleva:1:n (-)6'0" s N.A.

. ..:.M- tR 3,03 .Saf

• ety - Inj,ection Elevation (-)2i'try'

. ... . - *t-O' N.A.

s N.A.

. 1 iM-XR-i7CA PCCW Pi Ing N.A. t N.A.

J

3. Triaxial Seismic Swit:nes

a. .-iM-15-5700 Free Fiel: t 1

M SA

. '. !M-x5 5701 Centainment F:uncati n'" M i N.A.

. '.-!M-X5 6709 Centainment F:uncati n'" M 4 N.A.

. '.-!M-XS 5710 Cont C:r. Fie:r

M t N.A. ,

t

a. Triaxial tes::nse-Sce:trum te::r:ers  :

i

a. '. iM-xR-5705 C:ntain. tent F:uncati:n M4 t N.A.

o 5 -rK-iCL

. . .-!M-tR ..Ce ,q:ntai::en:

< .s ... .....

Jeunda:ica nex: 3.1. s N. A.

Elevati:n(-)26'Q"

. . !M-xR-5707 Pria, a ux. 31:;. N.A. t N. A. i

. '.-iM-xR-57CS Se rvice Vate r au -: -cuse N.A. t N. A.  !

i i

1 a

'Exce:: seismic trigger

aita ta ::r ::nte:1 r:cs iact:sti:ns.

8 CHANNEL ChECX :: :nsist :f turning t.'.e test /rese' s it:.5 an: verify al' i lam:s illuminate :n 1 !M-tR-5705.

j 1

SE15RCCK - UNIT 1 3/4 3-43

,1

s? :swis iv! !ws

w::- ::w ::swis?

s ::swis- <!s :' aTION SYST!u i.:w: :s3 ::N  : N *0R OPERA 7:04 3.5.1.7 Esca ::ntainment purge su::1y and exnaust isolation valve small :e OFE D ELE an::

a. Eacn 35-in:n c:ntainment snute:=n : urge su:01y an: exnaust iscia*.1:e valve snall te closec an: lo:ce: 01:sec, anc

t. ine S-inen c:ntainment ; urge su::1y anc exhaust isolati:n valve (s) small te sealec closed exce:t when c:en for purge system :eration for ressure control; for ALAM, res:iracle, ano air cuality ::nsice--

ations to fa:ilitate personnel entr/; anc f:r surveillance tests inat require the valve (s) to be c:en.

A:8t!Cai '.!TY: .M00!3 1(2 3, and A.

ACTION:

a. With a 36-in:n containmert : urge su::1y or exnaust isclati:n valve c:en or not locxec :lesec, close and lecx close 134 valve er isolate tne :enetratien(s) witnin a neurs, einenise :e in at least c:0T STANCEY witnin :ne next 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> anc in C0'0 SHUT:0wN

.itain the felicwing 30 neurs. -

. With cne er more of tne 8 inen c:ntainment : urge su:>1y or exnaus*.

isolation valves coen for reasons other than given in 3:ecifica-tien 3.5.1.7.t a: eve, close tne ::en 8 in:n valve (s) :r isolate tre per.etratien(s) .itnin 4 neurs, :tneraise te in at least :-0T STAh:5Y witnin the next 5 neurs, anc in COLD SHuiDCWN witain t .e foll:.in; 20 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br />.

c. Wita one or more containment purge su::1y or exnaust is:1atien i valves naving a sensurec leakage rate in ex:ess of tne limits of l 5:ecifications 4.6.1.7.2 or 4.6.1.7.3, restere tne ine:eratie valve (s) l to CPERABLE status er isolate the affectec penetratien(s) so that the '

measured leakage rate cces not excesc :ne limits of 5:ecifi:stiens a.6.1.7.2 or 4.5.1.7.3 within 2a nours and close the : urge su::1y if the af fected :enetration is the exnaust penetratien, :tner ise :e in at least HOT STAMOBY within tne next 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />, anc in COLO SHUTOC=N

.itnin the follcwing 30 neurs, i

I Nhe'-in:. :n . i ns

• cu sw -ly e us, so *ien lv maj k

e: ile 'a N  %. u il .. tai *i

. o ne . --:= an, :

q . i ne * :. sur ins . me . enahls -c a ms re . :1  :.

!!sERCC( - UN 7 '. 3/4 6-12

(

,w.s.-

. .  ::-. :...s:.: ...

i 2.2 :s:!:!N:Es? 3::t v Is0:sEE;:NG Ot U: f:!!3)

.s:- :s i.0.2.1 7 e !!!3 s al' f.n:ti:n 10 examine statiel ::erating :na a:teris ti:s ,

s: iss.a cas, i :ws ry a:vis: ries, Licensee !ven: Re: rts, an: ::nea s:ve:es

f statt:r :esi;n an: ::eratir; es:erience inf:r ati:n, inclucing units :?

s*-ilar :esi;r, ni:- sy inc1:ste areas fer it:r:ving station safe y. 7ne l$!; snati mase : eta'le: res:.mencati:ns f r revise: r::ecures, e u1: ment

?::t f t:sti:ns, maintenence activities, c:erations activities, r tner teens

f im:reving stati:n safety :: the ~:::. 's: * ;; ;;e. -  ;;-:^.e Ji- .. ..

2*eP:e-L Vice ?residen: :!Ingineering[andQuali:y?!: grams, v < tx+ ~9

.. ;,c ...q l i.2.3.2 The !!!3 snall :e ::t osec :f at least five, cecicatec, full time engineers locate: :n site. Eacn shal! nave a :acnelor's degree in engineering

- relate: s:1ence anc at least 2 years Or:fessional level ex:erience in nis fiele, at leas: '. yea- Of .ni:n ex:erien:e snall be in tne nuclear fiel .

t ; .ar< c. s =..* r. ?. . . r. 2

6. 2. 3. 3 Ine ISE' sne:' Oe res:ensible f:r maintaining surveillance Of station 4:tivities 10 Oravi:e inci:encent verificati:n' inat 15ese 4:*1vities are

erf:r e: ::r e:tly an: ina; numan err:rs are re:cce: as even as cra::1:al.

• ... ..; .c.

1 i.0.3. Re::r:s Of 4;;ivit'es e-f:rme: Oy tne !!!G small te Ore:are:, 541 -

ta1*e , an: f*F=ar:e: ea*n : ale Oar 2:ntn t:

• n e --Lo i ; . ^. i ,6 :ii ite : " . . . ^i g.... _a_ . 1  ? ..d .i--

..i e President of Engineerin and Quality Programa.

\ i r ers e i

....a  : .:-

. .:..y ,.. . a.vt.e--os i.:.a.'. Tre Snif t Te:snical acviser snall Or:vice 40vis ry te:nnical sa:::rt t: :ne Snif t Su:erintancent in :ne areas of toer. mal nycrawlics, react:r e gi-et-ir;, anc :lant analy'.is ith regar to tne safe ::eration of the stati:n.

l l s.2 T:aININO 1

1

5. 3.1 a retraining anc re:lacement licensec training cr: gram for tne station staff small :e taintainec un:er the cire: tion :f sne Training Gea+e. wara;e-an snall teet r excee: the re:virements anc re::nmencations of Secticn 5.5

f ANSI N12.1-197/ anc A::encix A :/10 CFR Fart 55 anc :ne se: elemental re:viretents s:e:ifie: in Se:ti:ns A and C of Enclosure 1 of the NRC letter )

. ate: w aren 29, 1990 :: all licensees, anc small incluce familiari:aticn =ita 1 elevant it.custry c:erational ex:erience.  !

i l

'S:: res: ens 1:le f:- sign-:d? functi:n.

SEaSt::s LN:71 5-5

I 1 i

CCNTAINw!NT SYSTEMS ,

PRIMARY CCNTAINMENT CCNTAINMENT LEAXAGE i SURVE!LLANCE RE0VIREwENTS 4.6.1.2 The contairaent leakage rates shall be demonstrated at the following -

test senecule and shall te cetermined in conformance with the criteria scoci-  :

fiec in e.- _-

Ac,pencix J of 10 CFR Part 50 3 : k; th: ::theet-eM Vcvi:in; af N / <

l

a. Three Type A tests (Overall Integrated Containment Leakage Rate) shall be conducted at 40 2 10 month intervals during shutcown at j a pressure not less than P,, 49.6 psig, during each 10 year service period. The third test of each set shall be conducted during the ,

i shutcown for the 10 year plant inservice inspection;

b. If any periccic Type A fails to meet 0.75 L,, the test schedule for subsequent Tyce A tests shall be reviewed and approved by the

! Commission. If two consecutive Type A tests fail to meet 0.75 L,, ,

a Type A test shall be performed at least every 18 months until two l j consecutive Type A tests meet 0.75 L, at wnich time the aeove test

> schecule may te resunec;

] c. The accuracy of each Type A test shall be verified by a supplemental ,'

d test which: .

1) Confirms the accuracy of the test by verifying that the sucole-mental test result, Lg, is in accordance with tne following i ecuation:

ll e- (L,,+ L,)I $ 0.25 L, .

where L,3 is the measured Type A test leakage and L, is the sucerimposed leak;

2) Has a duration sufficient to establish accurately the change in l leakage rate between the Type A test anc the supplemental tes.,  ;

and )

3) Requires that the rate at which gas is injected into the contain- )

ment or bloc from the contairment curing the supplemental test is between 0.75 L, and 1.25 L,.

i i

1 4

SEASRCCK - UNIT 1 3/4 6-3

/ /

jfjN  %;P C?

LN S ERT A

/:/( kWY T

/ <

>,~9 6.1.1 m a m. m zr :n.w::ATIONI 4

M

r a::: ef f 7:n organi:stions shall be established for unit operation and corpora:e canagement, re:; w f. The em sars ciouwen. Organi:atier.s shall in:1ude the positions fer ac:ivities affecting the safety of the nuclear pcver plan:.

a.  :.ine s of authority. responsibility, and c::=unication shall be established and defined fe: the highest managenent levels through intermediate levels to and including all operating c gani:stion positions. These re'a:icnships

. shall be documented and updated, as app Opriate, in :he f:: of c gani:ation charts, functional descrip.

icas for depar;: ental responsibilities and relationships, and job descriptions f or key persennel positions, c in equivalent for=s of d:cumentation. These requirements shall be dccumented in the FSAA and updated in a::ctdan:e with the requirements of 10CFR50.71,

b. The Station Manager shall be responsible for overall unit safe operation and shall have control over these onsite ac:ivities necessary for safe operation and maintenance of the plant.

. The '*ic e Presiden: - Nucles: ?:oducti:n saall have cc perate resp:n'sibility f:: everall plant nuclear safe:S and shall take any reasures needed to ensa:e ac:eptable performance of the staff in Operating, maintaining, and providing technical suppor: to the plant to ensure nucles: safe:y.

d. The individuals .ho train the Operating staff and these who carry cu health physics and quality assurance functi:n may report to the appr:priate ensite canager: hcve'er. : hey shall have suffi:ient organi:stional freed:  :: ensure their independence ft: 0;erating pressures.

INSERT B

f. The Operations Manage: and Assistant Operations Manage; shall hold a senic: reacter opera:c li:ense.

___ .____m _ _ _ _ _ _ . - _ _ _ _ _ . _ . _ _ _ _ - - _ _ _ _ _ _ _ . _ _ _ _ _ . . . . _ _ _ _ - . _ _ _ . . __ . __

i

' ilAatf 2.2-1 >

%; 01 AC10R 1 RIP SYSitM INSIRUMINI All0N IRIP SEIPolNIS h

fl 51N50R 9 101 Al. IRROR IllNCll0NAl. UNil

~

l All0WANCE (IA) I (5) IRIP SEIPolNI AllfMARLC VAluf 9 1. Manual Reactor Trip N.A. N.A. N.A. N.A. M.A.

i

, 2. Power Range, Neutron flux l

l a. liigh Setpoint 7.5 4.56 0 $109% of RIP * $111.1% of Rira

b. tow Setpoint 8.3 4.56 0 $25% of RIP * $27.1% of RIP *

3. Power Range, Neutron flux, 1.6 0.5 0 $$% of RIP

• with $6.3% of RIP

• witti liigh Positive Rate a time constant. a time constant t

. 12 seconds 12 seconds

4. Power Range, Heutron flux, 1.6 0.5 n <5% of RIF* with <6.3% of RIP

• with -

n liigli Negative Rate 3 time constant a time constant J, 12 seconds >2 seconds

5. Intermediate Range, 17.0 8.41 0 ~

<25% of RIP" <31.1% of RIP *

~

Neutron Ilux

6. Source Range, Neutron flux 17.0 10.01 0 $105 cp $1.6 x 105 cps

7. Overtemperature AI 6.5 3.31 1.04 *

• See ht e 1 See hte 2 ,

• 0 4/**

8. Overpower AT 4.8 1.43 0.12 See Note 3 , see Note 4 3.12 0.86 0.99 11931

9. Pressuriier Pressure - Low 1- .Gr71- M S. >1945 psig M A E psig 3.12 1.00 0.99 32398 10 Pressuriier Pressure - liigh 44- 4.J1- MS- $2385 psig -$h-396 psig

• RIP = RAllD liifRMAL POWER -

lhe sensor error for I, is 1.04 and the sensor error for Pressurizer Pressure is 0.47. "As ane.asured" scesor errors may be used in lieu of either or both of these values, wisich then must he summed to deter-mine t he overtemper.nlure Al total channel value for 5.

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ _ _ _ . ~ _

~ ,..

r k ..

3/4.1 REACTIVITY CONTROL SYSTEMS

'3/4.1.1) 50 RATION CONTROL SHUTOCWN MARGIN - T, GREATER THAN 200*T LIMITING CON 0! TION FOR OPERATION _

3.1.1.1 The SHUT 00kN MARGIN for four-leep coeration shall be greater than er '

"'" ~ 4 equal to +r85 Ak/k in MODES 1, 2. 4 44 3, a n d ' " '

/, J '4 APDLICABILITY: MODES 1, 2", 3, and 4. .

ACTION:

With the SHUT 00WN MARGIN less than the limiting value, immediately initiate and continue boration at greater than or equal to 30 gpm of a solution containing .

greater than or equal to 7000 ppm boren or equivalent until the required l SHUTCChN MARGIN is restored. ,  ;

SURVEILLANCE RE0VIREMENTS 4.1.1.1.1 The SHUT 00WH MARGIN sna11 be determined to be greater than er equal  ;

to ne limiting value:  ;

r

a. Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after detection of an ine:erable control red (s) anc at least once :er 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> tnereafter while the rec (s) is inoperacle.

If the inopersole control rec is immovable or untrippaele, the above required SHUTOCWN MARGIN shall be verified ac:ectable with an increased allewance for the withdrawn worth of the immova:1e or untrippable centrol red (s);

. When in MODE I or H00E 2 with k,ff greater than or equal to 1 at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by verifying that c:ntrol bank withdrawal is  :

within the limits of Specification 3.1.3.5; .j

c. When in MODE 2 with k,ff less than 1, within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> prior to j achieving reactor criticality by verifying tnat the predicted critical control red positten is within the limits of Specification i 3.1.3.6;  ;

c. Prior to initial cperation ateve 5% RATED THERMAL POWER after each fuel leading, by c:nsideration of the f actors of Scecifica- ,

tien 4.1.1.1.le. belew, with the control banks at the maximum inser- l tien limit of Specification 3.1.3.5; anc  :

l l

l l

l

'See Special Test Exceptions Specification 3.10.1.

SEASROCK - UNIT 1 3/4 1-1 J

L,o ,

i t

l REACTIVITY CONTROL SYSTEMS l  !

l BORAT!0N SYSTEMS FLOW PATHS = OPERATING LIMITING CON 0! TION FOR OPERATION  !

3.1.2.2 At least two of the following three boron inje: tion flow paths shall i be OPERABLE:

a. The flow path from 'the boric acid tanks via a boric acid transfer ,

pumo and a charging pump to the Reactor Coolant System (RCS), and  :

I

b. T.o flow paths from the refueling water stcrage tank via charging pumps to the RCS.

APPLICABILITY: MCOES 1, 2, and 3" ACTION:

t

'a'ith only one of the aeove recuired toren injection flow paths to the RCS l OPERABLE, restore at least two toren injection flow paths to tne RCS to '

f CPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Or ce in at least NOT STANCSY and corated to a SHUTCC'aN MARGIN equivalent to at least 1.3% Ak/k at 200'F within the f next 6 nours; restore at' least two flow paths to CPERASLE status within j the next 7 ca'ys or be in COL 2 IFUTCCE' within the next ,vb hours.

hot SHurbowed G -

i SURVEILLANCE RECUIREWENTS ,

l 4.1.2.2 At least two of the above required flow paths sna11 :e demonstrated i I

CPERAELE:

a. At least once per 31 days by verifying that each valve (manual, i pewer-operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position;

b. At least once per 13 months during shutdown y verifying that each aut:matic valve in the flow path actuates to its correct position on a safety injection test signal; and

c. At least once per 18 months ty verifying that the flow cath required by Specification 3.1.2.0a, celivers at least 30 gpm to the RCS.

'The provisions of Specifications 3.0.4 inc 4.0.4 are not acclica:1e for entry into MCCE 3 f:r the centrifugal charging pump ceclared inoceraole pursuant to 5:ecification 4.1.2.3.2 provicec that tne centrifugal cnarging pumo is restored to CPERABLE status within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or prior to the temperature of one or more of the RCS cole legs exceeding 375'F, .nichever comes first.

SEASRC0K - UNIT 1 3/4 1-3

) *

- l

!' REacTIV!T( CONTROL SYSTEMS i I

i

BORAff0N SYSTEMS

's l CHARGING PUMP - SMUTOC'.N

! +

! t.!MITING CCN0! TION FOR OPERATION ,

(

6en:'rituaaf 3.1.2.Ne7dhlFging pump in the boren injection flew path required by

' Specification 3.1.2.1 shall to CPERABLE and capable of bein; pc*erec fr:m an CPERA8LE emergency power source. l APPLICABILITY: H00ES 4, 5, and 6.

f ACTION g _

Ceencrifuga,1) c f i With ne p a.rsing pump OPERABLE or capable of being powered frca an CPERABl.E -l l emergency power source, suspend all operations involving CORE ALTERATIONS or  ;

j positive reactivity changes. . j SURVEILLANCE REOUIREMENTS i

4.1.2.3.1 The above re f5da# ing pumo shall be comonstrated CPERASLE by f verifying, on recirculation flow, that a differential pressure across the ; ump  !

l of greater tnan or equal to 2480 psid is cevele ed when tested pursuant to Specification 4.O s4 5 ..- %

4 7 centrifugalf j 4.1.2.3.2 All/cFaTQi~ng MPs, excluding the a:ove re;uired CPERABLE pump,  !

J snail be demonstrated inoperacle" by verifying snat the motor circuit treakers  !

1. are secured in the coen position within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> af ter entering MODE 4 from i MODE 3 or prior to the temperature of ene or more of tne RCS cold legs cecreas- t 1 ing :elow 325'F, whicnever c:mes first, and at least once per 31 days there- i af ter, except wnen the react:r vessel neac is removed.  !

i

+

i i

1

' "An iroceracle pumo may be energized for testing provided tne cischarge of  !

j the cumo nas been isolated from tne RCS Oy a closed isolation valve with I j

power removed from the valve eceret:r, or my a manual isolation valve l a securec in tne closec ;csition.

I

! l t

SEABROOK - UNIT,1 3/4 1-9 l i I

- - - ~ -

l  ;

1

• i l

I REACTIVITY CCNTROL SYSTEMS l ECRATICN SYSTEMS l r

i CHARGING PUMPS - OPERATING ,

LIMITING CCNDITION F0k OPERATION 3.1.2.4 At least two charging pumps shall be OPERABLE. ,

APPLICA5 f LIT /: MCCES 1, 2, and 3.*

f l

l ACTION:

l with only one charging pump OPERABLE, restore at least two charging pumps to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANOBY and : orated to a SHUT 00WN MARGIN equivalent to at least 1.3% ak/k at 200*F within the next t 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />; restore at least two charging pu ps to OPERA!LE ' status within :ne next 7 days or :e in 6044 SHUTDOWN witnin tne next &G hours., ,

hot G SURVEILLaN:! RECUIREVENTS _ l i

4.1.2.4 At least t o enarging pumos shall te cemonstrated OPERASLE y ,

4 verifying, :n re:irculation flow, tnat a dif ferential pressure act:ss ea:5 pumo of greater than or equal to 2450 psic is develo e: when teste: ;urswant to Specification 4.0.5.

t i

i l

l "Tne Or: visions of 5:e:ifications 3.3.4 an: 4.0.4 are net a::li:a:1e f:e e .try into MCCE 3 f:r tre :entrifugal :nar;in; ume ce:1are: in:: era:1e :vesuant :

' 5:e:if t:stion 4.1.2.3.2 :revice: na' ine :entri'u;si :nar;ing ;u : is rest:re:

itnin a nours Or Ori r to the te :erature of Ore or more j to CEERa!LE status of the RC5 ::10 legs es:ee:ing 375'F, .nienever :::es first.

l SEASRC0K - UNIT 1 3/4 1-10 l

.- t t

\ >

I AllI L 3. 3-3 (Ceant inued}

u.

l h INGINIE RIO SAf[1Y ((A1UR15 ACIUA110N SY5itM INSIRIMENIAll0N HINIMIM -

l 7 f()lAL NO. CilAN!!I L S CilANNELS APPLICAlllE ,

• IilHCI IONAl t!NI I Of CilANNI15 10 IRIP OPIHAutL HDDL5 ACi10tl i c

c. 5.afety injection See Itaa 1. al>ove for all 5.afety Isijection initiating f unctions h azul requirements.

g I. Incogency feed.44ter

a. Manual Initiation (1) Motor driven pump 1 1 1 1, 2. 3 21 (2) Turtaine driven pump 2 1 2 1, 2, 3 21 la. Automatic Actuation Logic 2 1 2 I, 2, 3 20 ,

and Actuation Relays

c. Sim. Gess. Water level--

• g iow-low Start Motor-Driven Pump 4/sts. gen. 2/sta. gen. 3/sta. gen. 1, 2, 3 18" 3

o and St. art)m ine -

Driven Pt i<

el. Safety injection Start Motor-Driven Pump See Item 1. above for all Safety injection initiating functions and and Turbine-Driven Pump requirements.

c. toss of-Offsite Power Start. Hotor-Driven Pump and furtaine- See item 9 for Loss of-Of(site P(Ner Initiating fu4clions and Dr iver: Pump requirements.

8. Automatic Swit<.I.over to Cont.aisment Susq 2 1, 2, 3, 4 13

a. Automatic Actuation 2 1~ '

logic asul Actuation Helays

_ _ _ _ _ _ _ _ - - _ _ _ _ - - - - _ - - _ - - _ - _ _ _ _ . - - - - - - - _ _ - _ - - . . _ _ _ _ - - , ,u. -

- TABLE 3.3-3 (Continued)

TABLE NOTATIONS

• The provisions of Specification 3.0.4 are not applicable.

1. Trip function may be blocked in this MODE below the F-11 (Pressurizer Pressure Interlock) Setpoint.

"* Trip function automatically blocked above P-11 and may be blocked below P-11 when Safety Injection on low steam line pressure is not blocked.

AFor the steam turbine-driven pump, when the secondary steam supply 47 cressure is greater than 500 psig. ,,)

.d ACTION STATEMENTS ACTION 13 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, be in at least HOT STANOBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUT 00WN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />; however, one channel may be by;assec ior up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing per Specification 4.3.2.1, provided the other channel is OPERABLE.

ACTION 14 - With the number of OPERABLE channels one less than the Total Number of Channels, operation may proceec until performance of the next required ANALOG CHANNEL OPERATIONAL TEST provided the inoperable channel is placed in the tripped condition within  :

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

ACTION 15 - With the number of OPERABLE channels one less than the Total Number of Channels, operation may proceed provided the inoperable

+

channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is met. One additional channel may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing per Speci fication 4.3.2.1.

ACTION 16 '- With less than the Minimum Channels OPERABLE requirement, operation may continue provided the containment purge supply and exhaust valves are maintained closed.

l ACTION 17 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in ac least HOT STANCEY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> anc in COLD SHUT 00WN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

ACTION 18 - With the numcer of OPERABLE channels one less than the Total Humeer of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

4

SEABROOK - UNIT 1 . 3/4 3-22 .

j

,} l  : jil  : i e!ji

' jl l  ; .! f j; ;I .! i ,j; , , , j!

!!  ; ,I-I' f 7 wt. wt E on on re U. re l rm rm A au au V nr nrt a t E g g "a f s f s L i i i on on F H  ;

- s s i i

• A p p p  % 2 W e e 7.7Enag n.

gn 0

1 l A.

A.

. 3 5

8 6

5 3

2 1 A.

N naprs a. 7 8'

ap rs 1

6 5 A.

A N N $ 1 < N 6 1 N I

N e e g

I g O nt nt P g g f an f an l i i i ore ore E s s s m m S p p p %wu %wu F P

I

. . 3 5 8

0 0

. 0. r tor n 6 rsa 0.o 6 rsa 6 rt rn 4 A

R A. A. 4 5 1 A. 8anp 8anp 5 .

I N M 1 1 < N $nis 1nis 1 N S

I N 5 6 R 7 3 8 N

I . . . .

)

O P

0R) s05 A. A.

6 6 A. 5. 7 .

3

. A.

0 N d

e I

L Ni(

[ R t

N N 1 1 0 N 4 4 1 u S SL n

i P -

t I 1 -

n R . . 1 7 . k 46 2 .

o I 7 5 21 1 C A. A. . 0

. A. i. . . A.

( N Z N N 0 1 0 H $ . 22 1 4 1

0 '

4 l

- l )

3 A A *

. I T 3 N (

E E M E t

i t C l

l R l l

A T A l S LW N AO . . 1 .

I 1 l 2 . 0 A 0 0 6 0l A. A. . 3 . . A.

H 1 A N N S 1 3 N 4 4 4 i t

L I

S Y

S

' N ) 2 -

0 m c - c 1 e i g

i w e i 1 t i l o r g ) t A s o - L u o 4 n U y L - - s l r1 r e I S s e - s e- e d C ( ny r e eh n t,a (P t) i A oa u r rg o a4 c n i l s u Pi i i W W1- n p S o t e s s t s i i i n n

l l E i aR e s r- ay rg rP o r o R o t u r e o- ua oi n o( C I i H i a t n P r t e t l t il o t -

gr c t

l t i co P at ce a- i ai A a t Ai t ra AR rle t ri vo e E l i t n e eR eg a e-l at j f o n ca e n n cn ni l nl I c n s I iu m i ee io ei o eI l

a i e

l Y I tt n L Gv i p ti G- s G- S l l ac i i at - I - C R y

[

f l

l e

n a

u mA o t a

a m mt aa T r ma ou ae ml r

ml ae R

h e t

A i lt i n td n e eg t t ev e ev w t f S I L a un o t t e e uc t e t t e o i a M Aa C S Sl f n AA St a SL t w S D l m i w

L A a b i t

R N e r e

[ O t . . . . u . . e . . .

f l S a 1 3.

c d e T a 1 3

f a b c H l l C G N H l l . . .

[ I 4 5 6 l

@ ME e , ~

1' j I w

J',l*,  ; j  ;! l  ;  : $ i 4

I 1 AlllE 3. 3-4 (Continued)  !

m i.

h fHGINffitED SAFEIY ffATURES ACIUA110H SYSlfH INSTRUMENTATION 1 RIP SEIPOINTS l n  ;

p SENSOR 101AL ERROR I

[ filNCT IONAl. LINil Al.t0WANCE (IA) Z (5) IRIP SE1 POINT Att0WAlltE VAlUE  !

= t

-i 9. loss of Power (Start  :

P Leergency feedwater) ,

a. 4.16 kV Dus ES and E6 H.A. N.A. N.A. > 2975 > 2908 volts l Loss of Voltage volts with Uith a $ 1.315 l l

a $ 1.20 second time -

second time delay. j delay. . .

h. 4.16 kV llus ES and E6 N.A. N.A. N.A. > 3933 volts > 3902 volts ['

Degraded Voltage with a < 10 Utth a < 10.96 i second time second Iime i delay. delay. .

I w Coincident with:

D Safety Injection See Item 1. above for all Safety injection Trip Setpoints and l w Allowable Values. l O

10. Engineered Safety features  !'

Actuation System Interlocks

• l 11964 ,

a. Pressurizer Pressure, P-ll N.A. N.A. N.A. $ 1950 psig 1 MSO psig  ;

b. Reactor Trip, P-4 N.A. N.A. N.A. N.A. N.A.  !

I

c. Steam Generator Water Level, See Item S. above for all Steam Generator Water Level Trip i P-14 Setpoints and Allowable Values.  !

. [

l

[

1 I

3

' ' c_, . '

TABtE 4.3-2 (Continued)

%'. ENGINEERED SAFEfY FEATURES ACIllAli0tl SYSTEM INSIRUMENTATI0ll U SLIRVEILLANCE RTiiuiliGiEtliS o TRIP S .

ANALOG ACIllATING MODES .i CllAtitJEL DEVICE HASTER SLAVE FOR WillCH e

OPERATIONAL OPERATIONAL ACTliATION RELAY RELAY SURVEILLANCE 5E CilAHil[L ClfANNEL CilAttilEL TEST TEST LOGIC TEST lEST IS REQUIRED TUllCT10tlAL UNII CilECK CALIBRATION TEST

4. Steau Line Isolation R H.A. H.A. H.A. 1,2,3

a. Hanual Initiation N.A. N.A. 11. A.

(System) M(1) 1, 2, 3 fl. A. 'N.A ti. A H.A. M(1) f)

b. Automatic Actuation Logic and Actuation Relays ti. A. H.A. H.A. fl. A. 1,2,3 R H

c. Containment Pressure- S Ili-2 N.A. N.A. N.A. H.A. 1, 2, 3

d. Steam Line S R H w

) Pressure-Low R H H.A. N.A. N.A. H. A. 3 w e. Steam Line Pressure- S

.', llegative Rate-Itigli .

S. Turb,ne i Trip H.A. H(1) M(1) Q 1, 2

a. Automatic Act.uat. ion N.A. N.A. N.A.

Logic and Actuation -

Relays tl. A. H.A. H.A. fl. A. 1, 2

b. Steam Generator Water 5 R H Level-Iligh-liigh (P-14)

6. feedwater Isolation 3 H tl. A. N.A. N.A. H.A. 1, 2

a. Steani Ger.crator Water . S R ,

Level--liigtt-liigli (P-14) N.A. H.A. H.A. 1, 2 R H ti. A. ,.

h. Low RCS aT.vg Coincident 5 with Reactor Trip

c. Safety injection See Item 1. above for all Safety Inject. ion Surveillance Requiresients.

7. Emergency feedwater .

, .y i a. Manual Initiation H.A. H. A., .1, 2.. ,3.h, ),

N.A. N.A. R N.A.

1) Motor-driven pump fl. A.

4L R 'H.A. H . A.' N.A.- ' 1.- 2 l.:3 3.%

2) Iurbine-driven punip fl. A. N.A. f t. A.

- ~ - h_ _ _ _ - - - -- - - _ _ - _ _ - _ _ _ _

,i .

REACTOR COOLANT SYSTEM 3/4.4.4 RELIEF VALVES LIMITING CONDITION FOR OPERATION 3.4.4 All power-operated relief valves (PORVs) and their associated block valves shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a. With one or more PORV(s) inoperable, because of excessive seat leakage, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> either restore the PORV(s) to OPERABLE status or close the associated block valve (s); otherwise, be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in 60b9 SHUTDOWN within the following se hours. Hor G

b. With one PORV inoperable due to causes other than excessive seat leakage, within I hour either restore the PORV to OPERABLE status or close the associated block valve and remove power from the block valve; restore the PORV to OPERABLE status within the f ollowing 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in 0:;0 Hor SHUTOOWN within the following && hours.

G

c. With both PORV(s) inoperable due to causes other than excessive seat leakage, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> either restore each of the PORV(s) to OPERABLE status or close their associated block valve (s) and remove power from the block valve (s) and be in HOT STANOBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and -GGbG-SHUT 00KN within the following M hours.

Ho7 c

d. With one or more block valve (s) inoperable, within 1 hour:

(1) restore the bicek valve (s) to OPERABLE status, or close the block valve (s) and remove power from the block valve (s), or close the PORV and remove power from its associated solenoid valve; and (2) apply the ACTION b. or c. above, as appropriate, for the isolated PORV(s).

e. The provisions of Specification 3.0.4 are not applicable.

SEABROCK - UNIT 1 3/4 4-11

e 4 'i  ! .

3/4.5 EMERGENCY CORE COOLING SYSTEMS 3/4.5.1 ACCUMULATORS .

HOT STANDBY, STARTUP; AND POWER OPERATION LIMITING CONDITION FOR OPERATION 3.5.1.1 Each Reactor Coolant System (RCS) accumulator shall be OPERABLE with:

a. The isolation valve open and power removed,

b. .A contained borated water volume of between 6121 and 6596 gallons,

c. A boron concentration of between 1900 and 2100 ppm, and

d. A nitr' ogen cover pressure of between 585 and 664 psig.

APPLICABILITY: MODES 1, 2, and 3*.

ACTION:

a. With one accumulator incperable, except as a result of a closed isola-tion valve, restore the inoperable accumulator to OPERABLE status within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or be in at least HOT STANOBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and reduce pressurizer pressure to less than 1000 psig within the following 6 nours.

b. With one accumulator inoperable due to the isolation valve being closed, either immediately open the isolation valve or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and reduce pressurizer pressure to less than 1000 psig within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. -

SURVEILLANCE RE0VIREMENTS 4.5.1.1.1 Each accumult?.or shall be demonstrated OPERABLE:

a. At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by:

1) Verifying, by the absence of alarms, the contained borated water volume and nitrogen cover pressure in the tanks, and

2) '/: 'fyir; th:t ::C :::.-d ;t;r I;ol;ti;.- -51.e is . pen.

b. At least once per 31 days and within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after each solution volume increase of greater than or equal to 1% of tank volume by verifying the boron concentration of the accumulator solution; and Pressurizer pressure above 1000 psig.

I 1

SEABRC0K - UNIT 1 3/4 5-1 l l

1

__-_.w__

[ .

EMERGENCY CORE COOLING SYSTEMS

/

ACCUMULATORS SHUT 00WN LIMITING CONDITION FOR OPERATION

3. 5.1. 2 Each reactor coolant system accumulator isolation valve shall be shut ~ ~-

with power removed from the valve _coerater. _ _ _ _ -

APPLICABILITY: MODES 4* and 5 Asp AccusotAroA. Fs s 550 M 4REAT6/1 rHAd l OO PNG-9 -

_~-n ACTION:

a. With one or more accumulator isolation valve (s) open and/or power available to the valve operator (s), imediately close the accumulator isolation valves and/or remove power from tne valve operator (s).

b. The provisions of Specification 3.0.4 are not applicable for entry into MODE 4 from MODE 3.

l SURVEILLANCE REOUIREMENTS l i 4.5.1.2 Each accumulator isolation valve will be verified shut with power 1 removed from the valve operator at least once per 31 days.

l 1

l l

'Within 12 nours prior to entry into MODE 3 from M005 4 and if pressuri:er i cressure is greater than 1000 psig, each accumulator isolation valve shall bc open as re;uired by Scecification 3.5.1.1.a.

SEA 5 ROOK - UNIT 1 3/4 5-3

I l

, i

. CONTAINMENT SYSTEMS ,

PRIMARY CONTAINMENT INTERNAL PRES 5URE LIMITING CONDITION FOR OPERATION W .4 Primary containment internal pressure shall be maintained between L 14.69nd 16.2 psia.

APPLICABILITY: MODE 5 1, 2, 3, and 4.

ACTION:

With the containment internal pressure outside of the limits above, restore the internal pressure to within the limits within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or be in at least HOT STAND 5Y within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUT 00WH within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

SURVEILLANCE REOUIREMENTS

!. 6.1.4 The ::rimary containment internal pressure shall be determined to be within the limits at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

l I There is no lower limit on centain=ent pressure when the containment on-linepurgesupplyfanisoperatingandthesupplyvalvesare<pgn

\

as allowed by specification 3.6.1.7.

~_

i i

SEABRC0K - UNIT 1 3/4I-9 1

. i .

CONTAINMENT SYSTEMS PRIMARY CONTAINMENT CONTAINMENT VENTILATION SYSTEM SURVEILLANCE REQUIREMENTS 4.6.1.7.1 Each 36-inch containment purge supply and ' exhaust isihrtion valve shallbeverifiedtobelockedclosedatleastonceper31dayD 4.6.1.7.2 At least once per 6 months on a STAGGERED TEST BASIS, the inboard and outboard isolation valves with resilient material seals in each sealed closed 36-inch containment purge supply and exhaust penetration shall be demonstrated OPERABLE by verifying that the measured leakage rate is less than or equal to 0.05 L, when pressurized to P,.

4.6.1.7.3 At least once per 92 days each 8-inch containment purge supply and exhaust isolation valve with resilient material seals shall be demonstrated OPERABLE by verifying that the measured leakage rtte is less than or equal to 0.01 L, when pressurized to P,.

4.6.1.7.4 Each 8-inch containment purge supply and exhaust isolation valve shall be verified to be sealed closed or open in accordance with Specifi-cation 3.6.1.7.b at least once per 31 days.

• If no containment entry has been made since checking the inside contain:::ent 36-inch valves locked closed, these valves do not have to be checked until a containment entry has been made.

SEAERC0K - UNIT 1 3/4 6-13

' \

. o i 3/4.7 . PLANT SYSTEMS 3/4.7.1 TURBINE CYCLE SAFETY VALVES .

LIMITING CONDITION FOR OPERATION 3.7.1.1 All main steam line Code safety valves associated with each steam generator shall be OPERABLE with lif t settings.as specified in Table 3.7-2.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

l

a. With four reactor coolant loops and assoc'iated steam generators in operation and with one or more main steam line Code safety valves l inoperable, operation in H0 DES 1, 2, and 3 may proceed, provided l that within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> either the inoperable valve is restored to l OPERABLE status or the Power Range Neutron Flux High, Trip Setpoint is reduced per Table 3.7-1; otherwise, be in at least HOT STANDBY within ,

the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> a..d in COLO SHUT 00WH within the following 99- hours.

, l bot 6 I

b. The provisions of Specification 3.0.4 are not applicable.

SURVEILLANCE REOUIREMENTS a.7.1.1 No additional requirements other than those required by Speci-fication 4.0. 5.

l l i

l l

l l

l l

l l

l 3/4 7-1 SFABROOK - UNIT 1

. ~

PLANT SYSTEMS TURBINE CYCLE AUXILIARY FEEDWATER SYSTEM LIMITING CONDITION FOR OPERATION

' 7.1. 2 At least three independent steam generator auxiliary feedwater pumps and associated flow paths shall be OPERABLE with:

a. One motor-driven emergency feedwater pump, and one startup feedwater pump capable of being powered froo an emergency bus and capable of being aligned to the dedicated water volume in the condensate storage tank,,and

b. One steam turbine-driven emergency feedwater pump capable of being powered from an OPERABLE steam supply system.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a. With one auxiliary feedwater pump inoperable, restore the recuired auxiliary feedwater pumps to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be  ;

in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUT 00WN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. .

b. With two emergency feedwater pumps inoperable, restore at least one emergency feedwater pump to OPERABLE status within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and restore both emergency feedwater pumps to OPERABLE status within ,

72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, or be in at least HOT STANOBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and '

in CCL': SHUT 00WN within the following -C+ hours.

HOT G

c. With one emergency feedwater pump and the startup feedwater pump inoperable, restore both emergency feedwater pumps to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and all three pumps to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUT 00VN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

d. With three auxiliary feedwater pumps inoperable, immediately initiate corrective action to restore at least one auxiliary feedwater pump to OPERABLE status as soon as possible.

51RVEILLANCE RE0VIREMENTS 4.7.1.2.1 Each auxiliary feedwater pump shall be demonstrated OPERABLE:

a. At least once per 31 days on a STAGGERED TEST BASIS by:

1) Verifying that the motor-driven emergency feecwater pump develops a discharge pressure of greater than or equal to 1460 psig at a flow of greater than or equal to 270 gpm; SEABROOK - UNIT 1 3/4 7-3

TABLE 3.7-3 AREA TEMPERATURE MONITORING .

AREA TEMPERATURE LIMIT (*F) 75

1. Control Room Cable Spreading Room 104 2.

Switchgear Room - Train A 104 3.

4 Switchgear Room - Train B 104 Battery Rooms - Train A 97 5.

Battery Rooms - Train B 97 6.

7. ECCS Equipment Vault - Train A 104

8. ECCS Ecuipment Vault - Train B 104 Centrifugal Charging Pump Room - Train A 104 9.

10. Centrifugal Charging Pump Room - Train B 104

11. ECCS Equipment Vault Stairwell - Train A 104 104

12. ECCS Equipment Vault Stairwell - Train B PCCW Pumo Area 104 13.

14 Cooling Tower Switchgear Room - Train A . 104

15. Cooling Tower Switchgear Room - Train B 104

16. Cooling Tower SW Pump Area 127

17. SW Pumchouse Electrical Room - Train A 104

18. SW Pumphouse Electrical Room - Train B 104

19. SW Pump Area 104

20. Diesel Generator Rocm - Train A 120 l

21. Diesel Generator Room - Train 3 120

22. EFW Pumphouse 104

23. Electrical Penetration Area - Train A 100 l 1

24 Electrical Penetration Area - Train B 85

25. Fuel Storage Building Spent Fuel Pool Cooling 104 Pump Area

25. Main Steam and Feedwater Pipe Chase - East 130 130

,1., Main _ Steam and FeedwatetPjp.e,CAase - West

28. Hydrogen Analyzer Room 104

29. MSFW East Pipe Chase Electrical Room 104 x

1 SEABRC0K - UNIT l' 3/4 7-23

- . - - - - , _ _ c_ _ _

. ~ s,y . .

I  ;

%m.y'*g;iLGy wM:si ,

.g , v;gn

/;: w' .7 j

ELECTRICALPOWER' SYSTEMS ~;.;jS 1

~

N A.C. SOURCES - ).

OPERATING SURVEILLANCE REOUIREMENTS 4.8.1.1.2 (Continued)

I a) Verifying deenergization of the e .ergency busses and load shedding from the er.ergency busses, and b) Verifying the diesel starts on the loss of offsite power signal, energizes the er:ergency busses with permanently connected loads within 12 seconds, energizes the auto-connectedgehmMann loads through the emergency power sequencer and operates for greater than or equal to 5 minutes while its generator is loaded with the shutdown i loads. Af ter energization, the steady-state voltage and l frequency of the er,ergency busses shall be maintained at 4160 : 420 volts and 60 : 1.2 Hz during this test.

5) Verifying that on an 51 actuation test signal, without loss-of-off site power, the diesel generator starts on the auto-start signal and operates on standby for greater than or equal to 5 minutes. The generator voltage and frequency shall be l

4160 1 420 volts and 60 1.2 Hz within 10 seconds after the auto-start signal; the steady-state generator voltage and frequency shall be maintained within these limits during this test;

6) Simulating a loss-of-of fsite power in conjunction with an SI tctuation test signal; and a) Verifying deenergization of the emergency busses and load shedding from the emergency busses; b) Verifying the diesel starts on the auto-start signal, energizes the energency busses with permanently connected loads within 10 seconds, energizes t!.e auto-connected 6 loads through the emergency pcwer l

-sequencer and operates for greater than or equal to '

5 minutes while its generator is leaded with the er.ergency

-loads. Af ter energization, the steady-state voltage and f requency of the energency busses shall be maintained at 4160 : 420 volts and 60 : 1.2 Hz during this test; and c) Verifying that all autoeatic diesel generator trips, except engine overspeed, low lube oil pressure, 4160-volt bus f ault, and generator dif f erential, are automatically bypassed upon loss of voltage on the energency bus c:ncur-rent with a Safety Injection actuation signal.

SEABRCCX - UNIT 1 3/4 8-6

s ELECTRICAL PCWER SYSTEMS A.C. SOURCES OPERATING SURVEILLANCE REOUIREMENTS 4.8.1.1.2 (Continued)

13) Verifying that the following diesel generator lockout features prevent diesel generator starting:

a) Sarring device engaged, or b) Differential lockout relay.

14) Simulating a Tower Actuation (TA) signal while the diesel generator is leaded with the permanently connected leads and auto-connected emensaasommmmmmmmmad loads., and verifying that the service water pump automatically trips, and that the cool-ing tower pump and fan (s) automatically start. Af ter energiza-tien the steady state voltage and frequency of the emergency buses shall be maintained at 4160 2 420 volts and 60 21.2 Hz; and

15) 'a'hile diesel generator 1A is leaded with the permanently connected loads and auto-connected gammyumumungesmusuut loads, manually connect the 1500 hp startup feee.ater pump to 4160-volt bus E5. Af ter energization the steady-state voltage and frequency of the emergency bus shall be caintained at 41601 420 volts and 50 : 1.2 Hz.

g. At least once per 10 years or after any modifications hich could affect diesel generator interdependence by starting both diesel generators simultaneously, during shu::own, and verifying that both diesel generators accelerate to at least 514 rps in less than or equal to 10 seconds; and l

h. At least once per 10 years by: l 1

1) Oraining each fuel oil storage tank, removing the accu:ulated l sediment and cleaning the tank using a sodium hypochlorite solution, or equivalent, and

2) Performing a ;ressure test of those portions of the diesel '7el oil system designed to Section III, subsection N0 of the ASME Code at a test pressure equal to 110% of the system design pressure.

SEASRCOX - UNIT 1 3/4 3-3  ;

1

6.0 ADMINISTRATIVE CCNTROLS 6.1 RES:0NSIBILITY 6.1.1 The Station Manager snail ce responsible for overall station ocera-tion anc snali delegate in writing the succession to this responsibility during his absence.

6.1. 2 The Shif t Superintencent (or during his absence from the control room, a cesignated individual) shall ce resconsible for the control room command function. A management directive to this effect, signed by the Vice President, Nuclear Production shall ce reissued to all station personnel on an annual basis.

6.2 ORGANIZATION

.- ::T: INSERT A ,

5. 2.1 The-cf f:ite-crgentratWoMt-aticNanagement anc teLic51 a., ,,w , 1 sh: 50 0; hown in Figure !.2-1.

STATION STAFF 6.2.2 Th e -i L6 t hic v rg an i-J a i.-i wi s ha 1 Oc as a .h u in F M rc 6.2-2 and.

a. Each on-duty shift shall be composed of at least the minimum shift crew composition snown in Tacle 6.2-1;

c. At least one licensed Operator shall be in the control r0cm when fuel is in the reactor. In addition, while the uni . is in MCDE 1, 2, 3, or 4, at least one licensed Senior Coerator sna11 be in the control room;

c. A Health Physics Technician" shall be on site when fuel is in the reactor; l

All CORE ALTERATIONS shall be observed and directly supervised by ,

l either a licensed Senior Operator or licensed Senior Operator Limited I to Fuel Handling who has no other concurrent responsibilities during l this operation; and  ;

I

e. Administrative procedures shall be developed and implemented to limit I the working hours of station staff who perform safety-related func- I tions, e.g. , licensed Senior Operators, licensed Operators, health physicists, auxiliary operators, and key maintenance personnel. The amount of overtime worked by station staff members cerforming safety-related functions shall be limited in accordance with the NRC Policy Statement on working hours (Generic letter No. 82-12).

INSERT 3 1

"The Health Physics Tecnnician may be less than the minimum re:uirements for a ceriod of time not to exceed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, in order to ac::mmodate unexcetted aosen:e, provided i . mediate action is taken to fill the required ositions.  !

SEAERCOX - UNIT 1 6-1 1

I l

INSERT A ,

6.2.1 OFFSITE AND ONSITE CEGANIZATIONS Cnsite and offsite organi:stions shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting the safety of the nuclear power plant.

a. Lines of authority, responsibility, and cerr.unication shall be established and defined for the highest =anagement levels through intermediate levels to and including all operating organization positicas. These relationships shall be documented and updated, as appropriate, in the for= of organization charts, functional descrip-tions for departmente.1 responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements shall be documented in the FSAR and updated in accordance with the requirements of 10CFR30.71.

b. The Station Manager shall be responsible for overall unit safe operation and shall have centrol over those onsite activities necessary for safe operation and =aintenance of the plant.

c. Th'e Vice President - Nucitar Production shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, =aintaining, and providing technical support to the plant to ensure nuclear safety.

d. The individuals who train the operating staff and those who carry out health physics and quality assurance functions =ay report to the appropriate onsite =anager; hevever, they shall have sufficient organi:stional freedom to ensure their independence frc= operating pressures.

INSERT B

f. The Operations Manager and Assistant Operations Manager shall hold a senior reactor operator license.

o e ,I

~

ADMINISTRATIVE CONTROLS RESPONSIBI'.! TIES 5.4.1.7 (Continued) ,

and the Station Manager nowever, the Staticn Manager shall have responsibility for resolution of such disagreements pursuant to specification 5.1.1.

RECORDS

5. 4.1. 8 The 50RC shall maintain written minutes of eacn 50RC meeting that, at a minimum, document the results of all 50RC activities performed under the responsioility provisions of these Technical Specifications. Copies shall be proviced to the Vice Presicent-Nuclear Production and tne NSARC.

5. 4. 2 NUCLEAR SAFETY AUDIT REVIEW COMMITTEE (NSARC) <

.FU_NCTION E. 4. 2.1 The NSARC shall function to provide indeoendent review and audit of I cesignated activities in the areas of:

a. Nuclear power plant operations,

b. Nuclear engineering, 4

c. Chemistry and raciochemistry, .

J d. Metallurgy, i

e. Instrumentation and control,  ;

f. Radiological safety,

g. Mechanical and electrical engineering, and ,

n. Quality assurance pract i ces.

p# and chief Executive Officer.

Ine NSARC shall recort to and advise the{Presiden

. ri;r '":: ' ::ident on those areas '

of responsibility specified in Specifications 6.4.2.7 and 6.4.2.8.

CCMPOSITION

1. wRresident and Chief Executive Officer 5.4.2.2 The NSARC shall be comcosed of at least five (5) individuals. The Chairman, Vice Chairman and memoers, including designated alternates, shall ce apcointed in writing by the Seni;r ' lice Ir;;i:ent.k'Uollectively, the indivicuals appointed to the NSARC should be c0moetent to conduct revie=5 icentified by Specification 6.4.2.1. Each member shall meet the qualifica-

• ions of ANSI 3.1-1978, Section 4.7.

1 ALTERNATES Alf ?? resident and Chief Executive Of fice-5.4.2.3 All alternate memoers shall be appointed in writing cy the Ceci;r ' " '

":0 " ::id:St to serve on a temcorary basis; however, no more than a minority shall participate as voting memoers in NSARC activities at any one time.

CONSULTANTS 5.4.2.4 Consultants shall be utill:ed as determined by the NSARC to provide expert advice to tne NSARC.

i SEABRCCK - UNIT 1 6-3

ACMINISTRATIVE CONTROLS.

AUDITS 6.4.2.8 (Continued) provided the comeined time interval for any three consecutive intervals shall not exceed 3.25 tines the specified interval. These audits shall encompass:

a. The conformance of station operation to provisions contained within the Technical Specifications and applicable license conditions 4 least once per 12 months;

b. The performance, training, and qualifications of the entire station staff at least once per 12 months;

c. The results of actions taken to correct deficiencies occurring in station equipment, structures, systems, or method of operation that af fect nuclear safety, at least once per 6 months;

d. The performance of activities required by the Operational Quality Assurance Program to meet the criteria of Appendix B,10 CFR Part 50, at least once per 24 months;

e. The fire protection programmatic controls including the implementing procedures at least once per 24 months by qualified licensee QA personnel; The fire protection equipment and program implementation at least i f.

once per 12 months utilizing either a qualified offsite licensee fire protection engineer or an outside independent fire crotection consultant. An outside independent fire protection consultant shall be used at least every third year; I

g. The Radiological Environmental Monitoring Program and the ,results thereof at least once per 12 months;

h. The OFFSITE COSE CALCULATION MANUAL and implementing procedures at least once per 24 months; i.

The PROCESS CONTROL PROGRAM and implementing procedures for processing i and packaging of radioactive wastes at least once per 24 months- \

J. The performance of activities required by the Quality Assurance Program for effluent and environmental monitoring at least once per 12 months;

k. The Emergency Plan and implementing procedures at least once per 12 months;

1. The Security Plan and implementing procedures at least ones per 12 months; and

m. Any other area of station coeration considered a:propriate cy the NSARC or the 5;H;r "i;; 'resicank,?residen: and Chief Executive Officer.

NMy' SEABROOK.- UNIT 1 6-10

_o .

ACMINISTRATIVE CONTROLS RECORDS 6.4.2.9 Records of NSARC activities shall be prepared and distributed as indicated below:

30

a. Minutes of each NSARC meeting hal be prepared and forwarded to the 4'AY pSenior "i:e President within 13t days following each meeting;

\ President and Chief Executive Officer

b. Reports of reviews encompassed by Specification 6.4.2.7 shall be included in the minutes where applicable or forwarded under sepa-rate cover to the See4cr Vicc-Prc:ident-within 14 days following completion of the review; and *esident and Chief Executive Officer H

,gy c. Audit reports encompassed by pecification 6.4.2.8 shall be forwarded

?residenc and Chief},r'fo URF ;nior Vice Presidsnt and to the management positions respons-Ixecutive Officer ) audit ible for the areas audited within 30 days after completion of the by the auditing organization.

6.5 REPORTABLE EVENT ACTION The following actions shall be taken for REPORTABLE EVENTS:

a. The Commission shall be notified and a report submitted pursuant to the requirements of Section 50.73 to 10 CFR Part 50, and I

b. Each REPORTABLE EVENT shall be reviewed by the 50RC and the ~

results of this review shall be submitted to the NSARC and the Vice President-Nuclear Production.

l 6.6 SAFETY LIMIT VIOLATION The f.ollowing actions shall be taken in the event a Safety Limit is i

violated:

a. The NRC Operations Center shall be notified by telephone as soon as l possible and in all cases within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. The Vice President-Nuclear l Production and the NSARC shall be notified within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />; l

b. A Safety Limit Violation Report shall be prepared. The report shall l be reviewed by the 50RC. This report shall describe: (1) apolicable circumstances preceding the violation, (2) effects of the violation uoon f acility components, systems, or structures, and (3) corrective action taken to prevent recurrence; ,

c. The Safety Limit Violation Resort shall be submitted to the Commission, the NSARC, and the Vice President-Nuclear Production within 14 days of the violation; and i

d. Ooeration of the station shall not be resumed until authori:ed by the Commission.

SEABROOK - UNIT 1 6 . . . - - . - - - . _ _ - ~ _ - . _ - - - . . - - . - , - - . - - , - . - . - . - - . . . , .-- - - - - .-

,e .

REACTIVITY CONTROL SYSTEMS

(

BASES BORATION CONTROL 3/4.1.1.3 MODERATOR TEMPERATURE COEFFICIENT (Continued)

The Surveillance Requirements for measurement of the MTC at the beginning and near the end of the fuel cycle are adequate to confirm that the HTC remains within its limits since this coefficient changes slowly due principally to the reduction in RCS baron concentration associated with fuel burnup.

3/4.1.1.4 MINIMUM TEMPERATURE FOR CRITICALITY This specification ensures that the reactor will not be made critical '

with tne Reactor Coolant System average temperature less than 551'F. This ~

limitation is required to ensure: (1) the moderator temperature coef ficient is within its analyzed temperature range, (2) the trip instrumentation is within its normal ocerating range, (3) the pressurizer is capable of being in an OPERABLE status with a steam bubble, and (4) the reactor vessel is above its minimum RT temperature.

HDT 3/4.1.2 BORAT10N SYSTEHf The Boron T.njection -tem ensures that negative reactivity control is available during each moc M f acility operation. The components reouired to perform this function inc~.4de: (1) borated water sources, (2) charging pumps, (3) separate f1: paths, E t toric acid transfer pumps, ano (5) an emergency

ower supply from OPERABLE o nel generators.

With the RCS in KD251, 2, or 3, a minimum of t o boron injection flow paths are required to ensure single functional capability in the event an assumed f ailure renders one of the flow paths inoperable. The boration cacability of either flow path is sufficient to provide a SHUT 00WN i FARGIN frcm expected operating conditions of 1.3% ak/k after xenon decay

} and cooldown to 200*F. The maximum expected beration capability requirement occurs at EOL from full po er equilibrium xenon conditions and requives 22,000 gallons of 7000 ppm borated water from the boric acid storage tanks or a minimum contained volume of 477,000 gallons of 2000 ppm berat g_w p V ^

the refueling water storage tank (RWST). ,

M a/ d$ljMj

' mu- -

The limitation for a maximum of one centrifugal cha mp to be OPERABLEandtheSurveillanceRequirementtoverifyallqnarginppumpsexcept the recuired OPERABLE pu.mo to be inoperable in MODES a, o, and e provices assurance that a mass addition pressure transient can be relieved by operation of a single PORV or an RHR suction relief valve.

As a result of tnis, only one boren injection system is available. This is acceotable on the basis of the stable reactivity condition of the reactor, tne emergency power sucoly repuirement for the OPERABLE charging puro and the accitional restrictions prohibiting CORE ALTERATIONS and positive reactivity enanges in the event the single injection system becomes inopersole, j .

SEABRC0K - UNIT 1 B 3/4 1-2

INDEX 2.0 SAFETY LIMITS AND LIMITING SAFETY SYSTEM SETTINGS SECTION PAGE 2.1 SAFETY LIMITS................................................. 2-1 l

2.1.1 REACTOR C0RE................................................ 2-1 2.1.2 REACTOR COOLANT SYSTEM PRESSURE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-1 FIGURE 2.1-1 REACTOR CORE SAFETY LIMIT - FOUR LOOPS IN OPERATION.. 2-2 2.2 LIMITING SAFETY SYSTEM SETTINGS 2.2.1 REACTOR TRIP SYSTEM INSTRUMENTATION SETP0INTS............... 2-3 TABLE 2.2-1 REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS.... 2-4 2.0 BASES 2.1 SAFETY LIMITS 2.1.1 REACTOR C0RE................................................ B 2-1 2.1.2 REACTOR COOLANT SYSTEM PRESSURE............................. B 2-2 1

. 2.2 LIMITING SAFETY SYSTEM SETTINGS

2.2.1 REACTOR TRIP SYSTEM INSTRUMENTATION SETP0!NTS............... B 2-3 3.0/4.0 LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS 3/4.0 APPLICABILITY............................................... 3/4 0-1 3/4.1 REACTIVITY CONTROL SYSTEMS 3/4.1.1 BORATION CONTROL i

Shutdown Margin - T,yg Greater Than 200*F................ 3/4 1-1 Shutdown Margin - T,yg Less Than or Equal to 200*F....... 3/4 1-3 Moderator Temperature Coefficient........................ 3/4 1-4 Minimum Temperature for Criticality...................... 3/4 1-6 l

I l

l l

SEABROOK - UNIT 1 ii l l

a

INDEX LIMITING CONDITIONS FOR OPERATION AhD SURVEILLANCE REQUIREMENTS SECTION PAGE TABLE 3.3-2 (This table number is not used)

TABLE 4.3-1 REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS............................................. 3/4 3-9 3/4.3.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION.......................................... 3/4 3-14 TABLE 3.3-3 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION.......................................... 3/4 3-16 TABLE 3.3-4 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION TRIP SETP0INTS........................... 3/4 3-24 TABLE 3.3-5 (This table number is not used)

TABLE 4.3-2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS................ 3/4 3-31 3/4.3.3 MONITORING INSTRUMENTATION Radiation Monitoring For Plant Operations................ 3/4 3-36 TABLE 3.3-6 RADIATION MONITORING INSTRUMENTATION l

FOR PLANT OPERATIONS..................................... 3/4 3-37 TABLE 4.3-3 RADIATION MONITORING INSTRUMENTATION FOR PLANT OPERATIONS SURVEILLANCE REQUIREMENTS..................... 3/4 3-39 Movable Incore Detectors................................. 3/4 3-40 Seismic Instrumentation.................................. 3/4 3-41 TABLE 3.3-7 SEISMIC MONITORING INSTRUMENTATION.................... 3/4 3-42 TABLE 4.3-4 SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS............................................. 3/4 3-43 Meteorological Instrumentation........................... 3/4 3-44 TABLE 3.3-8 METEOROLOGICAL MONITORING INSTRUMENTATION............. 3/4 3-45 Remote Shutdown System................................... 3/4 3-46 TABLE 3.3-9 REMOTE SHUTOOWN SYSTEM...... ......................... 3/4 3-47 Accident Monitoring Instrumentation...................... 3/4 3-49 TABLE 3.3-10 ACCIDENT MONITORING INSTRUMENTATION.................. 3/4 3-50 TABLE 3.3-11 (This table number is not used)...................... 3/4 3-53 Radioactive Liquid Effluent Monitoring Instrumentation... 3/4 3-55 TABLE 3.3-12 RADIOACTIVE LIQUID EFFLUENT MONITORING INSTRUMENTATION 3/4 3-56 SEABROOK - UNIT 1 iv

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS SECTION PAGE 3/4.7.2 STEAM GENERATOR PRESSURE / TEMPERATURE LIMITATION.......... 3/4 7-11 3/4.7.3 PRIMARY COMPONENT COOLING WATER SYSTEM................... 3/4 7-12 3/4.7.4 SERVICE WATER SYSTEM..................................... 3/4 7-13 3/4.7.5 ULTIMATE HEAT SINK....................................... 3/4 7-14 3/4.7.6 CONTROL ROOM AREA VENTI LATION SYSTEM. . . . . . . . . . . . . . . . . . . . . 3/4 7-16 3/4.7.7 SNUBBERS................................................. 3/4 7-18 3/4.7.8 SEALE0 SOURCE CONTAMINATION................. ........... 3/4 7-19 3/4.7.9 (This specification number is not used)...... ........... 3/4 7-21 3/4.7.10 AREA TEMPERATURE M0NITORING.............................. 3/4 7-22 TABLE 3.7-3 AREA TEMPERATURE M0NITORING........................... 3/4 7-23 3/4.8 ELECTRICAL POWER SYSTEMS 3/4.8.1 A.C. SOURCES 0perating..... .......................................... 3/4 8-1 TABLE 4.8-1 DIESEL GENERATOR TEST SCHE 0VLE........................ 3/4 8-10 Shutdown................................................. 3/4 8-11 3/4.8.2 0.C. SOURCES -

Operating................................................ 3/4 8-12 TABLE 4.8-2 BATTERY SURVEILLANCE REQUIREMENTS..................... 3/4 8-14 Shutdown................................................. 3/4 8-15 3/4.8.3 ONSITE PCWER DISTRIBUTION 0perating................................................ 3/4 8-16 Shutdown................................................. 3/4 8-18 Trip Ci rcui t f or Inverte r I-2A. . . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 8-19 3/4.8.4 ELECTRICAL EQUIPMENT PROTECTIVE DEVICES A.C. Circuits Inside Primary Containment................. 3/4 8-20 Containment Penetration Conductor Overcurrent Protective Devices and Protective Dev?ces for Class 1E Power Sources Connected to Non-Class 1E Circuits................................. .......... 3/4 8-21 )

Motor-0perated Valves Thermal Overload Protection. . . . . . . . 3/4 8-24 3/4.9 REFUELING OPERATIONS 3/4.9.1 BORON CONCENTRATION...................................... 3/4 9-1 3/4.9.2 INSTRUMENTATION.......................................... 3/4 9-2 3/4.9.3 DECAY TIME............................................... 3/4 9-3 SEABROOK - UNIT 1 viii 1

. 1 .

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.9.4 CONTAINMENT BUILDING PENETRATIONS........................ 3/4 9-4 3/4.9.5 COMMUNICATIONS........................................... 3/4 9-5 3/4.9.6 REFUELING MACHINE........................................ 3/4 9-6 3/4.9.7 CRANE TRAVEL - SPENT FUEL STORAGE AREAS............. .... 3/4 9-7 3/4.9.8 RESIDUAL HEA1 REMOVAL AND COOLANT CIRCULATION High Water Level........ ................................ 3/4 9-8 Low Water Leve1.......................................... 3/4 9-9 3/4.3.9 CONTAINMENT PURGE AND EXHAUST ISOLATION SYSTEM........... 3/4 9-10 3,'4.9.10 WATER LEVEL - REACTOR VESSEL............................. 3/4 9-11 3/4.9.11 WATER LEVEL - STORAGE POOL .............................. 3/4 9-12 3/4.9.12 FUEL STORAGE BUILDING EMERGENCY AIR CLEANING SYSTEM...... 3/4 9-13 3/4.10 SPECIAL TEST EXCEPTIONS 3/4.10.1 SHUTDOWN MARGIN.......................................... 3/4 10-1 3/4.10.2 GROUP HEIGHT, INSERTION, AND POWER DISTRIBUTION LIMITS... 3/4 10-2 3/4.10.3 PHYSICS TESTS........ ................................... 3/4 10-3 3/4.10.4 R E ACTO R COO LANT L00 P S . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 10-4 3/4.10.5 POSITION INDICATION SYSTEM - SHUT 00WN.................... 3/4 10-5 3/4.11 RADIOACTIVE EFFLUENTS 3/4.11.1 LIQUID EFFLUENTS Concentration............................................ 3/4 11-1  :

00se..................................................... 3/4 11-2 '

Liquid Radwaste Treatment System. . . . . . . . . . . . . . . . . . . . . . . . . 3/4 11-3 Liquid Holdup Tanks...................................... 3/4 11-4 3/4.11.2 GASEOUS EFFLUENTS Dose Rate................................................ 3/4 11-5 Dese - Noble Gases....................................... 3/4 11-6 Dose - Iodine-131, Iodine-133, Tritium, and Radioactive Material in Particulate Form............................. 3/4 11-7 Gaseous Radwaste Treatment System........................ 3/4 11-8 Explosive Gas Mixture - System........................... 3/4 11-9 3/4.11.3 SOLIO RADI0 ACTIVE WASTES................................. 3/4 11-10 3/4.11.4 TOTAL 00SE............................................... 3/4 11-12 3/4.12 RADIOLOGICAL ENVIRONMENTAL MONITORING 3/4.12.1 MONITORING PR0 GRAM....................................... 3/4 12-1 SEABROOK - UNIT 1 ix

TABLE 2.2-1 (Continued)

E REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS n;

E SENSOR E TOTAL ERROR e FUNCTIONAL UNIT ALLOWANCE (1A) Z (S) TRIP SETPOINT ALLOWABLE VAlllE E 11. Pressurizer Water Level - liigh 8.0 2.18 1.82 <92% of instrument $93.8% of instrument

-i span span

- 12. Reactor Coolant Flow - Low 2.5 1.87 0.6 >90% of loop >89.4% of loop design flow

• 3esign flow *

13. Steam Generator Water 17.0 15.28 1.76 >21.6% of narrow >20.5% of narrow Level Low - Low range instrument range instrument l span span

14. Undervoltage - Reactor 15.0 1.39 0 >10,200 volts >9,822 volts Coolant Pumps

15. Underfrequency - Reactor 2.9 0 0 >S5.5 !!z >SS.3 Ilz 7 Coolant Pumps ui

16. Turbine Trip

a. Low Fluid Oil Pressure N.A. N.A. N.A. >500 psig >450 psig

b. Turbine Stop Valve N.A. N.A. N.A. >1% open >1% open Closure

17. Safety Injection Input N.A. N.A. N.A. N.A. N.A.

from ESF

• Loop design flow = 95,700 gpm

l -

TABLE 4.3-1 (Continued) -

$ REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS 8

R TRIP

. ANALOG ACTUATING MODES FOR c .

CilANNEL DEVICE WilICil 25 CilANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE CllECK CALIBRATION TEST TEST LOGIC IEST IS REQUIRED

]FUNCIl0NALUNIT Reactor Trip Systesi Interlocks (Continued)

e. Power Range Neutron Flux, P-10 N.A. R(4) R N.A. N.A. 1, 2

f. Turbine Impulse Chamber Pressure, P-13 N.A. R R N.A. N.A. 1 I

t' 19. Reactor Trip Breaker N.A. N.A. N.A. M(7, 11) N.A. 1, 2, 3*,

• 4^, S*

T C 20. Auto:satic Trip and Interlock N.A. N.A. N.A. N.A. M(7) 1, 2, 3*,

Logic 4*, S*

l 21. Reactor Irip Bypass Breaker N.A. N.A. N.A. M(7, 14), N.A. 1, 2, 3^,

l R(IS) 4*, S*~

e

- , . - , . , ,. . . . _ e.,, ,. . -. _ _ . - , .r, -, ,. ,

l TABLE 3.3-4 l ENGINEERED SAFETY FEATURES ACTUATION SYSlEM INSTRUMENTATION TRIP SEIP0lNTS e

o

• SENSOR TOTAL ERROR i

^

FUNCTIONAL UNIT ALLOWANCE (TA) Z (S) TRIP SETPOINT ALLOWABLE VALUE l

i - 1. Safety Injection (Reactor Trip, Feedwater Isolation, Start Diesel Generators, Phase "A" Isolation, Containment Ventilation Isolation, and Emergency Feedwater, Service Water to Secondary Component y Cooling Water Isolation, CBA Emergency Fan / Filter Actuation, and Latching Relay).

{ a. Manual Initiatior. N.A. N.A. N.A. N.A. N.A.

Y b. Automatic Actuation Logic N.A. N.A. N.A. N.A. N.A.

Z t.

c. Containment Pressure--Hi-1 4.2 0.71 1.67 1 4.3 psig $ S.3 psig

d. Pressurizer Pressure--Low 12.1 10.71 1.69 > 1875 psig > 1865 psig l

e. Steam Line Pressure--Low 13.1 10.71 1.63 > 585 psig

> 568 psig*

2. Containment Spray

a. Manual Initiation N.A. N.A. N.A. N.A. N.A.

b. Automatic Actuation Logic N.A. N.A. N.A. N.A. N.A.

and Actuation Relays

c. Containment Pressure--Hi-3 3.0 0.71 1.67 $ 18.0 psig $ 18.7 psig

TABLE 3.3-4 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS I

=

o

• SENSOR TOTAL ERROR

[ FUNCTIONAL UNIT ALLOWANCE (TA) (S) TRIP SETPOINT z Z_ ALLOWABLE VALUE U 7. Emergency Feedwater c>o

a. Manual Initiation (1) Motor driven pump N.A. N.A. N.A. N.A. N.A. i (2) Turbine driven pump N.A. N.A. N.A. N.A. N.A.

b. Automatic Actuation Logic N.A. N.A. N.A. N.A. N.A.

and Actuation Relays l c. Steam Generator Water 17.0 15.28 1.76 w Level--Low-Low 1 21.6% of 3 20.5% of narrow l narrow range range instrument 2 Start Motor-Driven Pump instrument span.

w and Start Turbine-Driven span.

$ Pump

d. Safety Injection See Item 1. above for all Safety Injection Trip Setpoints and Start Motor-Driven Pump Allowable Values.

and Turbine-Driven Pump

e. Loss-of-Otisite Power See Item 9. for Loss-of-Offsite Power Setpoints and Allowable Values.

Start Motor-Driven Pump and Turbine-Driven Pump .

8. Automatic Switchover to Containment Sump

a. Automatic Actuation Logic N.A. N.A. N.A. N.A. N.A.

and Actuation Relays

b. RWST Level--Low-Low 2.75 1.0 1. 8 1122,525 gals. 1121,609 gals.

Coincident With Safety Injection See Item 1. above for all Safety Injection Trip Setpoints and Allowable Values.

+

INSTRUMENTATION MONITORING INSTRUMENTATION' SEISMIC INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.3 The seismic monitoring instrumentation shown in Table 3.3-7 shall be -

OPERABLE.

(

APPLICABILITY: At all times.

ACTION:

a. With one or more of the above required seismic monitoring instruments i' .;a able for more than 30 days, prepare and submit a Special

' to the Commission pursuant to Specification 6.8.2 within the n . ..r 10 days outlining the cause of the malfunction and the plans for restoring the instrument (s) to OPERABLE status,

b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.3.1 Each of the above required seismic monitoring instruments shall be demonstrated OPERA 3LE by the performance of the CHANNEL CHECK, CHANNEL CALI-BRATION, and ANALOG CHANNEL OPERATIONAL TEST at the frequencies shown in Table 4.3-4, 4.3.3.3.2 Each of the above required seismic monitoring instruments actuated

• during a seismic event greater than or equal to 0.01 g sbs11 be restored to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> except that Triaxial Peak Accelerographs 1 1-SM-XR-6702 and 1-SM-XR-6703 shall be restored within 7 days and a CHANNEL  !

CALIBRATION performed within 30 days following the seismic event. Data shall be retrieved from actuated instruments and analyzed to determine the magnitude of the vibratory ground motion. A Special Report shall be prepared and sub-mitted to the Commission pursuant to Specification 6.8.2 within 14 days de-scribing the magnitude, frequency spectrum, and resultant effect upon facility features important to safety, i

l l

1 i

SEABROOK - UNIT 1 3/4 3-41 j

TABLE 3.3-7 l SEISMIC MONITORING INSTRUMENTATION MINIMUM MEASUREMENT INSTRUMENTS IN['RUMENTSANDSENSORLOCATIONS RANGE OPFRABLE

1. Triaxial Time-History Accelerographs*  !

a. 1-SM-XT-6700 Free Field Control t lg 1**

Room East Air Intake, elevation 11' 6" '

b. 1-SM-XT-6701 Containment Foundation, lg 1**

4 elevation -26' 0"

c. 1-SM-XT-6710 Containment Operating 2 Ig 1**

Floor, elevation 25' 0"

2. Triaxial Peak Accelerographs

a. 1-SM-XR-6702 Reactor Vessel Support, 0-20 Hz 1 l Containment Building, elevation -13' 4" ,

i b. 1-SM-XR-6703 Reactor Coolant System 0-20 Hz 1 Piping, Containment Building,  !

, elevation -7' 8" '

c. 1-SM-XR-6704 PCCW Piping, Primary 0-20 Hz 1 1 Auxiliary Building, elevation 47' 0" '

j 3. Triaxial Seismic Switch j i 1-$M-XS-6709 Containment Foundation #, 0.025g to 0.25g 1** l elevation -27' 0" i

4. Triaxial Response-Spectrum Recorders

a. 1-SM-XR-6705 Containment Foundation, 1-30 Hz 1**

elevation -26' 0"

b. 1-SM-XR-6706 SG 11B Support, 1-30 Hz 1 Containment Building, elevation -20' 0"

c. 1-SM-XR-6707 Primary Auxiliary 1-30 Hz 1 Building, elevation 25' 0" l

d. 1-SM-XR-6708 Service Water Pump House, 1-30 Hz 1 l elevation 4' 0"

• Trigger mechanism in accelerograph unit activates recorders in control room 4

when it senses a ground motion cf 0.01g. 1 i **With reactor control room indication i # Switch setpoint is 0.13g for horizontal and vertical axis.

SEABROOK - UNIT 1 3/4 3-42 l

TABLE 4.3-4 SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS ANALOG {

CHANNEL CHANNEL CHANNEL OPERATIONAL INSTRUMENTS AND SENSOR LOCATIONS CHECK CALIBRATION TEST

1. Triaxial Time-History Accelerographs*

a. 1-SM-XT-6700 Free Field Control M R SA Room East Air Intake,.

elevation 11' 6"

b. 1-SM-XT-6701 Containment Foundation, M R N.A.

elevation -26' 0"

c. 1-SM-XT-6710 Containment Operating M R N.A.

Floor, elevation 25' 0"

2. Triaxial Peak Accelerographs .

a.1-SM-XR-6702 Reactor Vessel Support, N.A. R N.A.

Containment Building, l elevation -13' 4" b.1-SM-XR-6703 Reactor Coolant System N.A. R N.A.

Piping, Containment Building, elevation -7' 8"

c. 1-SM-XR-6704 PCCW Piping, Primary N.A. R N.A.

Auxiliary Building, elevation 47' 0"

3. Triaxial Seismic Switch 1-SM-XS-6709 Containment Foundation,** M R N.A.

elevation -26' 0"

4. Triaxial Response-Spectrum Recorders

a. 1-SM-XR-6705 Containment Foundation,** M# R N.A.

elevation -26' 0"

b. 1-SM-XR-6706 SG llB Support, Con- N.A. R N.A.

tainment Building, elevation -20' 0"

c. 1-SM-XR-6707 Primary Auxiliary N.A. R N.A.

Building, elevation 25' 0"

d. 1-SM-XR-6708 Service Water Pump t House, elevation 4' 0" N.A. R N.A.

• Each accelerograph has a triaxial trigger to activate the recorder. ,

i

• • With reactor control rocm indications. 1

1. CHANNEL CHECK to consist of turning the test / reset switen and verify all lamps illuminate on 1-SM-XR-6705.

l SEABROOK - UNIT 1 3/4 3-43

TABLE 4.3-6 (Continued) ,

Q TABLE NOTATIONS

• At all times. l Ouring RADI0 ACTIVE WASTE GA3 SYSTEM operation.

When the gland seal exhauster is in operation.

• • • • The CHANNEL OPERATIONAL TEST for the flow rate monitor shall consist of a verification that the Radiation Data Management System (RDMS) indicated flow is consistent with the operational status of the plant.

1. Noble Gas Monitor for this release point is based on the main condenser air evacuation monitor.  !

(1) The DIGITAL CHANNEL OPERATIONAL TEST shall also demonstrate that automatic isolation of this pathway and control room alarm annunciation occurs if the instrument indicates measured levels above the Alarm / Trip Setpoint.

(2) The DIGITAL CHANNEL OPERATIONAL TEST shall also demonstrate that control [

room alarm annunciation occurs if the instrument indicates measured levels above the Alarm Setpoint.

(3) The initial CHANNEL CALIBRATION shall be performed using one or more of l the reference standards certified by the National Bureau of Standards (NBS) -

,. or using standards that have been obtained from suppliers that pa'rticipate

;.) in measurement assurance activities with NBS. These standards shall per-mit calibrating the system over its intended range of energy and measure-ment range. For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be urad.

(4) The CHANNEL CALIBRATION shall include the use of standard gas samples containing a nominal:

a. One volume percent oxygen, balance nitrogen, and

b. Four volume percent oxygen, balance nitrogen.

(5) The CHANNEL CALIBRATION shall be performed using sources of various activities covering the measurement range of the monitor to verify that the response is linear. Sources shall be used to verify the monitor response only for the intended energy range.

1 l

q ,

l .) I 1

]

SEABROOK - UNIT 1 3/4 3-66 '

a

REACTOR COOLANT SYSTEM

(} REACTOR COOLANT LOOPS AND COOLANT CIRCULATION HOT STANOBY SURVEILLANCE REQUIREMENTS 4.4.1.2.1 At least the above required reactor coolant pumps, if not in operation, shall be determined OPERABLE once per 7 days by verifying correct breaker alignments and indicated power availability.

4.4.1.2.2 The required steam generators shall be determined OPERA 8LE by verify-ing secondary side water level to be greater than or equal to 21.6% at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. l 4.4.1.2.3 The required reactor coolant loops shall be verified in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

< g .' *

,q-

' gg SEA 8 ROOK - UNIT 1 3/4 4-3

REACTOR COOLANT SYSTEM gj]) REACTOR COOLANT LOOPS AND COOLANT CIRCULATION HOT SHUTOOWN SURVEILLANCE REQUIREMENTS 4.4.1.3.1 The raquired reactor coolant pump (s), if not in operation, shall be determined OPERABLE once per 7 days by verifying correct breaker alignments and indicated power availability.

4.4.1.3.2 The required steam generator (s) shall be determined OPERABLE by verifying secondary-side water level to be greater than or equal to 21.6% at l, least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

4.4.1.3.3 At least one reactor coolant or RHR loop shall be verified in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

v l

l l

I i

l l

l l

l SEABROOK - UNIT 1 3/4 4-5

-s

~

REACTOR COOLANT SYSTEM (h REACTOR COOLANT LOOPS AND COOLANT CIRCULATION ,

COLD SHUTDOWN - LOOPS FILLED LIMITING CONDITION FOR OPERATION 3.4.1.4.1 At least one residual heat removal (RHR) loop shall be OPERABLE and in operation *, and either:

a. One additional RHR loop shall be OPERABLE **, or

b. The secondary-side water level of at least two steam generators shall be greater than 21.6%.

l APPLICABILITY: MODE 5 with reactor coolant loops filled ***.

ACTION:

a. With one of the RHR loops inoperable and with less than the required steam generator water level, immediately initiate corrective action to return the inoperable RHR loop to OPERABLE status or restore the required steam generator water level as soon as possible,

b. With no RHR loop in operation, suspend all operations involving a

".' reduction.in boron concentration of the Reactor Coolant System and e

immediately initiate corrective action to return the required RHR loop to operation.

SURVEILLANCE REQUIREMENTS 4.4.1.4.1.1 The secondary side water level of at least two steam generators when required shall be determined to be within limits at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

4.4.1.4.1.2 At least one RHR loop shall be determined to be in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

"The RHR pump may be deenergized for up to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> provided: (1) no operations are permitted that would cause dilution of the Reactor Coolant System boron concentration and (2) core outlet temperature is maintained at least 10*F below saturation temperature.

• • 0ne RHR loop may be inoperable for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing provided the other RHR loop is OPERABLE and in operation.

c. ***A reactor coolant pump shall not be started unless the secondary water b temperature of each steam generator is less than 50*F above each of the Reactor Coolant System cold-leg temperatures.

SEABROOK - UNIT 1 3/4 4-6

y1

~~

REACTOR COOLANT SYSTEM (7p REACTOR COOLANT SYSTEM LEAKAGE OPERATIONAL LEAKAGE .<

LIMITING CONDITION FOR OPERATION 3.4.6.2 Reactor Coolant System leakage shall we limited to:

a. No PRESSURE BOUNDARY LEAKAGE,

b. 1 gpm UNIDENTIFIED LEAKAGE,

c. 1 gpa total reactor-to-secondary leakage through all steam generators and 500 gallons per day through any one steam generator,

d. 10 gpm IDENTIFIED LEAKAGE from,the Reactor Coolant System,

e. 40 gpm CONTROLLED LEAKAGE at a Reactor Coolant System pressure of 2235 psig i 20 psig, and

f. 0.5 gpm leakage per nominal inch of valve size up to a maximum of 5 gpm at a Reactor Coolant System pressure of 2235 t 20 psig from any Reactor Coolant System Pressure Isolation Valve specified in Table 3.4-1.*

l

_J APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

a. With soy PRESSURE BOUNDARY LEAKAGE, be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />,

b. With any Reactor Coolant System leakage greater than any one of the above limits, excluding PRESSURE BOUNDARY LEAKAGE and leakage from Reactor Coolant System Pressure Isolation Valves, reduce the leakage rate to within limits within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

c. With any Reactor Coolant System Pressure Isolation Valve leakage greater than the above limit, isolate the high pressure portion of the affected system from the low pressure portion within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> by use of at least two closed manual or deactivated automatic valves, or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

• Test pressures less than 2235 psig but greater than 150 psig are allowed.

Observed leakage shall be adjusted for the actual test pressure up to O 2235 psig assuming the leakage to be directly proportional to pressure dif-b ferential to the one-half power.

SEABROOK - UNIT 1 3/4 4-21 j

(; h h

~

~

TABLE 4.4-3 REACTOR COOLANT SPECIFIC ACTIVITY SAMPLE AND ANALYSIS PROGRAM 5

o TYPE OF MEASUREMENT SAMPLE AND ANALYSIS MODES IN WHICH SAMPLE AND ANALYSIS FREQUENCY AND ANALYSIS REQUIRED C

5 1. Gross Radioactivity At least once per 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. 1,2,3,4 Determination

] ,

2. Isotopic Analysis for DOSE EQUIVA- 1 per 14 days. 1 LENT I-131 Concentration

3. Radiochemical for 5 Determination

• 1 per 6 months ** . 1

4. Isotopic Analysis for Iodine a) Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, whenever the 1#, 2#, 3#,~4#, 5#

Including I-131, I-133, and I-135 specific activity exceeds 1 pCi/ gram DOSE EQUIVALENT I-131 .

or 100/E pCi/ gram of gross l radioactivity, and w

) b), One sample between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 1, 2, 3

. following a THERMAL POWER change 4 exceeding 15% of the RATED THERMAL

• POWER within a 1-hour period.

) *A radiochemical analysis for 5 shall consist of the quantitative measurement of the specific activity for each radionuclide, except for radionuclides with half-lives less than 10 minutes and all radiciodines, which j is identified in the reactor goolant. The specific activities for these individual radionuclides shall be .

used in the determination of E for the reactor coolant sample. Determination of the contributors to E shall

be based upon i. hose energy peaks identifiable with a 95% confidence level.

• • Sample to be taken after a minimum of 2 EFPD and 20 ' days of POWER OPERATION have elapsed since reactor was -

last subcritical for 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or longer.

! #Until the specific activity of the Reactor Coolant System is restored within its limits.

t

EMERGENCY CORE COOLING SYSTEMS ,

}{} ACCUMULATORS HOT STANOBY, STARTUP, AND POWER OPERATION SURVEILLANCE REQUIREMENTS 4.5.1.1.1(Continued)

c. At least once per 31 days when the RCS pressure is above 1000 psig by l verifying that power to the isolation valve operator is disconnected,

d. At least once per 18 months by verifying that each accumulator isola-tion valve opens automatically under each of the following conditions:

1) When an actual or a simulated RCS pressure signal exceeds the P-11 (Pressurizer Pressure Block of Safety Injection) Setpoint, and

2) Upon receipt of a Safety Injection test signal.

4.5.1.1.2 Each accumulator ^ water level and pressure channel shall be demon-strated OPERABLE:

a. At least once per 31 days by the performance of an ANALOG CHANNEL

, r.,, OPERATIONAL TEST, and x _-

b. At l' east once per 18 months by the performance of a CHANNEL CALIBRATION.

.q O .

SEABROOK - UNIT 1 3/4 5-2

EMERGENCY CORE COOLING SYSTEMS h ECCS SUBSYSTEMS - T,y GREATER THAN OR EQUAL TO 350*F ,

SURVEILLANCE REQUIREMENTS l

4.5.2 (Continued) l

d. At least once per 18 months by:

1) Verifying automatic isolation and interlock action of the RHR system from the Reactor Coolant System to ensure that: l a) With a simulated or actual Reactor Coolant System pressure signal greater than or equal to 365 psig, the interlocks l prevent the valves from being opened, and L

b) With a simulated or actual Reactor Coolant System pressure I signal less than or equal to 660 psig, the interlocks will l cause the valves to automatically close. I

2) A visual inspection of the containment sump and verifying that the subsystem suction inlets are not restricted by debris and i that the sump components (trash racks, screens, etc.) show no I evidence of structural distress or abnormal corrosion.

{ e. At least once per.18 months, during shutdown, by:

1) Verifying that each automatic valve in the flow path actuates to its correct position on (Safety Injection actuation and Automatic Switchover to Containment Sump) test signals, and

~

2) Verifying that each of the following pumps start automatically upon receipt of a Safety Injection actuation test signal:

a) Centrifugal charging pump, b) Safety Injection pump, and c) RHR pump.

f. By verifying that each of the following pumps develops the indicated differential pressure on recirculation flow when tested pursuant to Specification 4.0.5:

1) Centrifugal charging pump, 1 2480 psid;

2) Safety Injection pump, 1 1445 psid; and

3) RHR pump, 1 176 psid.

l SEABROOK - UNIT 1 3/4 5-6

_ . _ _ _ _ _ _ - _ - ~

CONTAINMENT SYSTEN

(} PRIMARY CONTAINMENT CONTAINMENT LEAKAGE SURVEILLANCE REQUIREMENTS 4.6.1.2 The containment leakage rates shall be demonstrated at the following test schedule and shall be determined in conformance with the criteria speci-fled in Appendix J of 10 CFR Part 50 using the methods and provisions of ANSI /

N45.4-1972:

a. Three Type A tests (Overall Integrated Containment Leakage Rate) shall be conducted at 40 t 10 month intervals during shutdown at a pressure not less than P,, 49.6 psig, during each 10 year service period. The third test of each set shall be conducted during the shutdown for the 10 year plant inservice inspection;

b. If any periodic Type A test fails to meet 0.75 L,, the test schedule l for subsequent Type A tests shall be reviewed and approved by the Commission. If two consecutive Type A tests fail to meet 0.75 L,,

a Type A test shall be performed at least every 18 months until two consecutive Type A tests meet 0.75 L, at which time the above test

' schedule may be resumed;

c. The accuracy of each Type A test shall be verified by a supplemental test which:

1) Confirms the accuracy of the test by verifying that the supple-mental test result, L e, is in accordance with the following equation:

lLe - (L,, + L,)l 5 0.25 L, where L , is the measured Type A test leakage and Lo is the superimposed leak;

2) Hss a duration sufficient to establish accurately the change in ,

leakage rate between the Type A test and the supplemental test; l and

3) Requires that the rate at which gas is injected into the contain-  ;

ment or bled from the containment during the supplemental test is between 0.75 L, and 1.25 L,.

D j l

SEABROOK - UNIT 1 3/4 6-3

, CONTAINMENT SYSTEMS

':" b .

PRIMARY CONTAINMENT CONTAINMENT VENTILATION SYSTEM LIMITING CONDITION FOR OPERATION 3.6.1.7 Each containment purge supply and exhaust isolation valve shall be OPERABLE and:

a. Each 36-inch containment shutdown purge supply and exhaust isolation valve shall be closed and locked closed, and

b. The 8-inch containment purge supply and exhaust isolation valve (s) shall be sealed closed except when open for purge system operation for pressure control; for ALARA, respirable, and air quality consider-ations to facilitate personnel entry; and for surveillance tests that require the valve (s) to be open.

APPLICABILITY: H0 DES 1*, 2*, 3, and 4.

ACTION:

~

a. With a 36-inch containment purge supply or exhaust isolation

+

valve open or not locked closed, close and lock closed that valve l ;

or isolate the penetration (s) within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, otherwise be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTOOWN  ;

within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />. j

b. With one or more of the 8-inch containment purge supply or exhaust

isolation valves open for reasons other than given in Specifica-tion 3.6.1.7.b above, close the open 8-inch valve (s) or isolate the penetration (s) within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, otherwise be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />,

c. With one or more containment purge supply or exhaust isolation valves having a measured leakage rate in excess of the limits of .

Specifications 4.6.1.7.2 or 4.6.1.7.3, restore the inoperable valve (s) l to OPERABLE status or isolata the affected penetration (s) so that the '

measured leakage rate does not excud the limits of Specifications 4.6.1.7.2 or 4.6.1.7.3 within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and close the purge supply if the affected penetration is the exhaust penetration, otherwise be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

• The 8-inch containment purge supply and exhaust isolation valves may not be

< J. opened while in MODE 1 or MODE 2 until installations of the narrow-range con-tainment pressure instrument channels and alarms are completed. -

SEABROOK - UNIT 1 3/4 6-12

CONTAINMENT SYSTEMS m

(a? 3/4.6.2 OEPRESSURIZATION AND COOLING SYSTEMS CONTAINMENT SPRAY SYSTEM LIMITING CONDITION FOR OPERATION 3.6.2.1 Two independent Containment Spray Systems shall be OPERABLE with each Spray System capable of taking suction from the RWST* and automatically trans- l ferring suction to the containment sump.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With one Containment Spray System inoperable, restore the inoperable Spray System to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />; restore the inoperable Spray System to OPERABLE status within the next 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in COLD SHUT 00WN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

SURVEILLANCE REQUIREMENTS 4.6.2.1 Each Containment Spray System shall be demonstrated OPERABLE:

i

• a.

At least once per 31 days by verifying that each valve (manual, power-operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position is in its correct position;

b. By verifying, that on recirculation flow, each pump develops a.

differential pressure of greater than or equal to 262 psi when tested pursuant to Specification 4.0.5;

c. At least once per 18 months during shutdown, by: l l'

1) Verifying that each automatic valve in the flow path actuates to its correct position on a Containment Pressure-H1-3 test signal, and

2) Verifying that each spray pump starts automatically on a Containment Pressure-Hi-3 test signal,

d. At least once per 5 years by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.

• In MODE 4, when the Residual Heat Removal System is in operation, an OPERABLE flow path is one that is capable of taking suction from the refueling water g, storage tank upon being manually realigned.

SEABROOK - UNIT 1 3/4 6-14 I

CONTAINMENT SYSTEMS 12 CCM8USTIBLE GAS CONTROL

• ELECTRIC HYOROGEN RECOM8!NERS LIMITING CONDITION FOR OPERATION 3.6.4.2 Two independent Hydrogen Recombiner Systems shall be OPERA 8LE.

APPLICABILITY: MODES 1 and 2.

ACTION:

With one Hydrogen Recombiner System inoperable, restore the inoperable system to OPERABLE status within 30 days or be in at least HOT STAN08Y within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.6.4.2 Each Hydrogen Recombiner System shall be demonstrated OPERABLE:

a. At least once per 6 months by verifying during a Hydrogen Recombiner ,

, System functional test that the minimum heater sheath temperature i increasestogreaterthanorequalto850*Fwithin90 minutes.

~" l Upon reaching 850'F, increase the power setting to maximum power for 2 minutes and verify that the power meter reads greater than or equal to 65 kW; and

b. At least once per 18 months by:

1) Performing a CHANNEL CALIBRATION of all recombiner instrumentation and control circuits,

2) Vetifying through a visual examination that there is no evidence of abnormal conditions within the recombiner enclosure (i.e., loose wiring or structural connections, deposits of foreign materials, etc.), and

3) Verifying the integrity of all heater electrical circuits by performing a resistance to ground test following the above required functional test. The resistance to ground for any heater phase shall be greater than or equal to 10,000 ohns.

l l

l

. j SEABROOK - UNIT 1 3/4 6-19

, i

- j

\

_. CONTAINMENT SYSTEMS r,A .

O 3/4.6.5 CONTAINMENT ENCLOSURE BUILDING CONTAINMENT ENCLOSURE EMERGENCY AIR CLEANUP SYSTEM LIMITING CONDITION FOR OPERATION 3.6.5.1 Two independent Containment Enclosure Emergency Air Cleanup Systems shall tse OPERABLE.

APPLICA8ILITY: MODES 1, 2, 3, and 4.

ACTION:

With one Containment Enclosure Emergency Air Cleanup System inoperable, re-store the inoperable system to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

SURVEILLANCE REQUIREMENTS 4.6.5.1 Each Containment Enclosure Emergency Air Cleanup System shall be demonstrated OPERABLE:

o

a. At least once per 31 days on a STAGGERED TEST BASIS by initiating, from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that the system cperates for at least 15 minutes;

b. At least once per 18 months or (1) after any structural maintenance l on the HEPA filter or charcoal adsorber housings, or (2) following paintingIththesystemby:

cating w fire, or chemical release in any ventilation zone l 1

1) Verifying that the cleanup system satisfies the in place pene-tration leakage testing acceptance criteria of less than 0.05%

and uses the test procedure guidance in Regulatory Post-tions C.S.a. C.5.c, and C.S.d of Regulatory Guide 1.52, Revision 2, March 1978*, and the system flow rate is 2100 cfm I i 10%;

2) Verifying, within 31 days after removal, that a laboratory analysis of a representative carbon sample obtained in accord-ance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978*, meets the labort.tds testing criteria

(,

• ANSI N510-1980 shall be used in place of ANSI H510-1975 referenced in Regulatory a Guide 1.52, Rev. 2, March 1978. i l

SEABROOK - UNIT 1 3/4 6-21

0. .

CONTAINMENT SYSTEMS 7

(& CONTAINMENT ENCLOSURE BUILDING -

CONTAINMENT ENCLOSURE EMERGENCY AIR CLEANUP SYSTEM SURVEILLANCE REQUIREMENTS 4.6.5.lb.2 (Continued) of Regulatory Position C.6.a of Regulatory Guide 1.52, Revi-sion 2, March 1978*, by showing a methyl iodide penetration of l less than 2.14% when tested at a temperature of 30'C and at a relative ~numidity of 95% in accordance with ASTM-D3803; and

3) Verifying a system flow rate of 2100 cfm i 10% during system operation when tested in accordance with ANSI N510-1980.

c. After every 720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> of charcoal adsorber operation, by verifying, within 31 days after removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978*, l meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978*, by showing a l methyl iodide penetration of less than 2.14% when tested at a tem-perature of 30*C and at a relative humidity of 95% in accordance 9

with ASTM-03803,

d. At least once per 18 months by: ,

1) Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 6 inches Water Gauge while operating the system at a flow rate of 2100 cfm 10%, '

2) Verifying that the system starts on a Safety Injection test '

signal,

3) Verifying that the filter cross connect valves can be manually opened, and l

4) Verifying that each system produces a negative pressure of greater than or equal to 0.25 inch Water Gauge in the annulus

{ within 4 minutes after a start signal. I

e. After each complete or partial replacement of a high efficiency particulate air (HEPA) filter bank, by verifying that the cleanup system satisfies the in place penetration leakage testing acceptance criteria of less than 0.05% in accordance with ANSI N510-1980 for a dioctyl phthalate (DOP) test aerosol while operating the system at a flow rate of 2100 cfm 2 10%; and I. ",

• ANSI N510-1980 shall be used in place of ANSI N510-1975 referenced in Regulatory Guide 1.52, Revision 2, March 1978.

] SEABROOK - UNIT 1 3/4 6-22 J

. . x' PLANT SYSTEMS h . TURBINE CYCLE ,

AUXILIARY FEE 0 WATER SYSTEM '

SURVEILLANCE REQUIREMENTS 4.7.1.2.la. (Continued)

2) Verifying that the steam turbine-driven pump develops a discharge pressure of greater than or equal to 1460 psig at a flow of greater than or equal to 270 gpm when the secondary steam supply pressure is greater than 500 psig. The' provisions of Specification 4.0.4 are not applicable for entry into MODE 3;

3) Verifying that the startup feedwater pump develops a discharge pressure of greater than or equal to 1375 psig at a flow of ..

greater than or equal to 425 gpm; l

4) Verifying that each non-automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in its correct position;

5) Verifying that each automatic valve in the flow path is in the fully open position whenever the Auxiliary Feedwater System is

( placed in automatic control or when above 10% RATED THERMAL L POWER; and

6) Verifying that valves FW-156 and FW-163 are OPERABLE for l alignment of the startup feedwater pump to the emergency feedwater heater,

b. At least once per 18 months during shutdown by:

1) Verifying that each automatic valve in the flow path actuates to its correct position upon receipt of an Emergency Feedwater System Actuation test signal;

2) Verifying that each emergency feedwater pump starts

• as designed I automatically upon receipt of an Emergency Feedwater Actuation System test signal; I l

3) Verifying that with all manual actions, including power source  ;

and valve alignment, the startup feedwater pump starts within '

the required elapsed time; and '

4) Verifying that each emergency feedwater control valve closes on receipt of a high flow test signal. l l

~'

• For the steam turbine-driven pump, when the secondary steam supply pressure is greater than 500 psig.

SEABROOK - UNIT 1 3/4 7-4

PLANT SYSTEMS h 3/4.7.6 CONTROL ROOM AREA VENTILATION SYSTEM LIMITING CONDITION FOR OPERATION 3.7.6 Two Control Room Area Ventildtion Systems shall be OPERA 8LE.

APPLICABILITY: All MODES.

ACTION:

MODES 1, 2, 3, and 4:

With one Control Room Area ventilation System inoperable, restore the inoperable system to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

MODES 5 and 6:

a. With one Control Room Area Ventilation System inoperable, restore the inoperable system to OPERABLE status within 7 days or initiate l and maintain operation of the remaining OPERABLE Control Roon Area Ventilation System in the recirculation mode.

,. b. With both Control Room Area Ventilation Systems inoperable, suspend ,

d all operations involving CORE ALTERATIONS or positive reactivity changes. ,

SURVEILLANCE REQUIREMENTS 4.7.6 Each Control Room Area Ventilation Systen shall be demonstrated OPERABLE:

l a. At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by verifying that the Control Room Area i

Ventilation System is maintaining the temperature of equipment and

, instrumentation in the control room area below its limiting equipment 1

qualification temperature.

b. At least once per 18 months or after any significant modification to the Control Room Area Ventilation Systems by verifying a system flow rate of 25,700 cfm t 10% through the air conditioner unit (3A and 38) and a flow rate of 1200 cfm i 10% makeup from each intake to the emergency filtration unit with a discharge of 2000 cfm t 10% from j the filtration unit.

i SEABROOK - UNIT 1 3/4 7-16 j

,e ,

i* ELECTRICAL POWER SYSTEMS ,

Q A2 C SOURCES OPERATING SURVEILLANCE REQUIREMENTS 4.8.1.1.1 Each of the above required independent circuits between the offsite transmission network and the Onsite Class 1E Distribution System shall be:

a. Determined OPERABLE at least once per 7 days by verifying correct breaker alignments, indicated power availability, and

b. Demonstrated OPERABLE at least once per 18 months during shutdown by transferring (manually and automatically) unit power supply from the normal circuit to the alternate circuit.

4.8.1.1.2 Each diesel generator shall be demonstrated OPERABLE:

a. In accordance with the frequency specified in Table 4.8-1 on a STAGGERED TEST BASIS by:

1) Verifying the fuel level'in the day fuel tank;

2) Verifying the fuel level in the fuel storage tank;

3) Verifying the fuel transfer pump starts and transfers fuel from the storage system to the day' tank;

4) Verifying the lubricating oil inventory in storage;

5) Verifying the diesel starts from ambient condition and acceler-ates to at least 514 rpm in less than or equal to 10 seconds."

The generator voltage and frequency shall be 4160 ! 420 volts and 60 t 1.2 Hz within 10 seconds

• after the start signal. The diesel oenerator shall be started for this test by using one of the following signals:

]

i a) & nual, or l b) Simulated loss-of-offsite power by itself, or .

I l *All diesel generatur starts for the purpose of this surveillance test may be .

preceded by an engine prelube period. Further, all surveillance tests and l all other engine starts for the purpose of this surveillance testing, with the l I

r;ceptia of once per 184 days, may also be preceded by warmup procedures (e.g.,

gracut.) acceleration and/or gradual loading greater than 60 seconds) as

recommes aa by the manufacturer so that the mechanical stress and wear on the diesel  % is minimized.

b-i SEASECK tJNIT 1 3/4 8-3 l

I I  ;

4 ELECTRICAL POWER SYSTEMS p/ A.C. SOURCES 4 . l OPERATING -

SURVEILLANCE REQUIREMENTS l l

4.8.1.1.2 (Continued) c) Simulated loss-of-offsite power in conjunction with an SI Actuation test signal, or d) An SI Actuation test signal by itself.

6) Verifying the generator is synchronized, loaded to greater than or equal to 6083 kW in less than or equal to 120 seconds *, l and operates with a load greater than or equal to 6083 kW for at least 60 minutes; and

7) Verifying the diesel generator is aligned to provide standby power to the associated emergency busses.

! b. At least once per 31 days and after each operation of the diesel  ;

where the period of operation was greater than or equal to I hour by '

checking for and removing accumulated water from the day fuel tank;

'j c. At least once per 31 days by checking for and removing accumulated i

water from the fuel oil storage tanks; l

d. By sampling new fuel oil in accordance with ASTM-04057-81 prior to 1

addition to storage tanks and: '

~

i l

1) By verifying in accordance with the tests specified in ASTM-0975-81 ,

] prior to addition to the storage tanks that the sample has: I

' a) An API Gravity of within 0.3 degree at 60*F, or a specific ,

gravity of within 0.0016 at 60/60*F, when compared to the 1 supplier's certificate, or an absolute specific gravity at I i 60/60'F of greater than or equal to 0.81 but less than or l l equal to 0.89, or an API gravity of greater than or equal to '

28 degrees but less than or equal to 42 degrees;

• All diesel generator starts for the purpose of this surveillance test may be 3 preceded by an engine prelube period. Further, all surveillance tests and all other engine starts for the purpose of this surveillance testing, with the i

J exception of once per 184 days, may also be preceded by warmup procedures (e.g.,

gradual acceleration and/or gradual loading greater than 60 seconds) as i reconstended by the manufacturer so that the mechanical stress and wear on the diesel engine is minimized.

d

! SEABROOK - UNIT 1 3/4 8-4 J

ELECTRICAL POWER SYSTEMS i

g A.C. SOURCE _S.

OPERATING SURVEILLANCE REQUIREMENTS 1

4,8.1.1.2 (Continued) b) A kinematic viscosity at 40*C of greater than or equal to 1.9 centistokes, but less than or equal to 4.1 centistokes,

if gravit i supplier'ys was not determined by comparison with the certification; c) A flash point greater than or equal to 125'F; and d) A clear and bright appearance with proper color when tested in accordance with ASTM-04176-82.

2) By verifying within 30 days of obtaining the sample that the other properties specified in Table 1 of ASTM-0975-81 are met when tested in accordance with ASTM-0975-81 except that the analysis for sulfur may be performed in accordance with ASTM-01552-79 or ASTM-02622-82.

,c3 e. At least once every 31 days: l

1) By obtaining a sample of fuel oil in accordance with ASTM-02276-78, and verifying that total particulate contamination is less than 10 mg/ liter when checked in accordance with ASTM-02276-78, l Method A, and i

j 2) By visually inspecting the lagging in the area of the flanged  !

joints on the silencer outlet of the diesel exhaust system for i leakage (also after an extended operation of greater than 24 '

hours).

I l f. At least once per 18 months, during shutdown, by:

1) Subjecting the diesel to an inspection in accordance with procedures prepared in conjunction with its manufacturer's recommendations for this class of standby service; l

2) Verifying the generator capability to reject a load of greater j

! than or equal to 671 kW while maintaining voltage at l 4160 i 420 volts and frequency at 60 t 4.0 Hz; L

1

3) Verifying the generator capability to reject a load of 6083 kW {

l without tripping. The generator voltage shall not exceed j 4784 volts during and following the load rejection;

(), 4) Simulating a loss-of-offsite power by itself, and:

4

', SEABROOK - UNIT 1 3/4 8-5

^

ELECTRICAL POWER SYSTEMS (g ELECTRICAL EQUIPMENT P40TECTIVE DEVICES T PENETRATION CON 00CTOR OVERCURRENT PROTECTIVE DEVICES AND PROTECitVJ  :

R CLA55 lE POWER SOURCES CONNEGILD TO NON-CLA55 lE CIRCUIT 5 l

LINITING CON 0!T!0N FOR OPERATION I e

3.8.4.2 Each containment penetration conductor overcurrent protective device  !

and each protective device for Class 1E power sources connected to non-Class 1E l circuits shall be OPERA 8LE.

APPLICA8ILITY: MODES 1, 2, 3, 4, 5,* and 6.* ,

ACTION:

a. With one or more of the containment penetration conductor overcurrent pro- l tective device (s) inoperable:

1) Restore the protective device (s) to OPERA 8LE status or deenergize the circuit (s) by tripping the associated circuit breaker or racking i out or removing the inoperable protective device within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, declare the affected system or component inoperable, and verify the ,

circuit breaker to be tripped or the inoperable protective device to '

be racked out or re'oved m at least once per 7 days thereafter; the provisions of Specification 3.0.4 are not applicable to overcurrent devices in circuits which have their circuit breakers tripped, or

(,.,[ their inoperable protective devices racked out, or removed; or l

2) Se in at least HOT STAN08Y within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />. l

b. With one or more of the Class 1E power source protective device (s) inoper- l l

able, restore the protective device (s) to OPERA 8LE status or deenergize the circuit (s) by tripping the circuit breaker or racking out or removing the inoperable protective device within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, declare the affected com- l ponent inoperable, and verify the circuit breaker to be tripped or the inoperable protective device to be racked out or removed at least once per 7to days thereafter; overcurrent dev ices in circuits which have their circuit breakersthe provisio tripped, or their inoperable protective devices racked out, or removed.

SURVEILLANCE REQUIREMENTS 4.8.4.2 Each containment penetration conductor overcurrent and Class IE power l source protective device shall be demonstrated OPERA 8LE:

a. At least once per 18 months:

1) By verifying that the medium voltage 13.8-kV and 4.16-kV circuit breakers are OPERABLE by selecting, on a rotating basis, at least one of the circuit breakers, and performing the following:

h[t *0nly for Class 1E power source protective devices.

(

SEA 8R00K - UNIT 1 3/4 8-21

i I

ELECTRICAL POWER SYSTEMS ELECTRICAL EQUIPMENT PROTECTIVE DEVICES fh CONTAINMENT PENETRATION CONOUCTOR OVERCURRENT PROTECTIVE DEVICES AND PROTECTIVE DEVICE 5 FOR CLA55 lE POWER SOURCES CONNECTED TO NON-CLA55 1E CIRCUIT 5 l SURVEILLANCE REQUIREMENTS 4.8.4.2.a.1) (Continued) a) A CHANNEL CALIBRATION of the associated protective relays  !

(because of the large currents involved, it is imprtetical to inject primary side signals to current transformers;  ;

therefore, the channel calibration will be performed by

, injecting a signal on the secondary side of those trans-formers at their test plug),

b) An integrated system functional test which includes simulated I automatic actuation of the system and verifying that each relay and associated circuit breakers and control circuits i function as designed, and c) For each circuit breaker found inoperable during these func-tional tests, one additional circuit breaker of the inoper-  :

able type shall also be functionally tested until no more failures are found or all circuit breakers of that type have been functionally tested.

2) By selecting and functionally testing a representative sample of at least 10% of each type of lower voltage circuit breakers and

~, overload devices. Circuit breakers and overload devices selected i V for functional testing shall be selected on a rotating basis.

i Testing of air circuit breakers shall consist of injecting a cur-3 rent with a value equal to 300% of the pickup of the long-time j delay trip element and 150% of the pickup of the short-time delay l trip element. The instantaneous element shall be tested by inject- t j ing a current equal to 220% of the pickup value of the element.

Testing of thermal magnetic molded-case circuit breakers shall

! consist of injecting a current with a value equal to 300% of the circuit breaker trip rating and -25% to +40% of the circuit

breaker instantaneous trip range or setpoint.

l Testing of combination starters (a magnetic only molded-case

! circuit breaker in series with a motor starter and integral overload device) shall consist of injecting a current with a i value equal to -25% to +40% of the circuit breaker instantaneous l trip setpoint, and 200% and 300% of the thermal overload device j trip rating to the respective devices.

Circuit breakers and/or overload devices found inoperable during -

functional testing shall be restored to OPERA 8LE status prior to resuming operation. For each circuit breaker and or overload de=

vices found inoperable during these functional tests, an additional i

representative sample of at least 10% of all the circuit breakers

and or overload devices of the inoperable type shall also be func-i , tionally tested until no more failures are found or all circuit

@'1 breakers and or overload devices of that type have been func-tionally tested. -

)

j SEABROOK - UNIT 1 3/4 8-22

(i ELECTRICAL POWER SYSTEMS (j]) ELECTRICAL EQUIPMENT PROTECTIVE DEVICES ,

CONTAINMENT PENETRATION CONOUCTOR OVERCURRENT PROTECTIVE DEVICES AND PROTECTIVE .' l OEVICE5 FOR CLASS lE POWER SOURCES CONNECTED TO NON-CLASS lE CIRCUIT 5 SURVEILLANCE REQUIREMENTS 4.8.4.2.a (Continued)

3) Corrective actions for any generic degradation of overcurrent protective devices, such as setpoint drift, manufacturing deficiencies, material defects, etc., shall be applicable ~to all (Class IE and non-Class 1E) protective devires of identical design.

b. At least once per 60 months by subjecting each circuit breaker to an .-

inspection and preventive maintenance in accordance with procedures prepared in conjunction with its manufacturer's recommendations. .

c. k  :

.s '

i

.' 2 SEABROOK - UNIT 1 3/4 8-23

~

e .

RADIOACTIVE EFFLUENTS

<g, GASE0US EFFLUENTS EXPLOSIVE GAS MIXTURE - SYSTEM LIMITING CON 0! TION FOR OPERATION 3.11.2.5 The concentration of oxygen in the GASEOUS RADWASTE TREATMENT SYSTEM shall be limited to less than or equal to 2% by volume.

APPLICABILITY: At all times.

ACTION:

a. With the concentration of oxygen in the GASEOUS RA0 WASTE TREATMENT SYSTEM greater than 2% by volume, reduce the oxygen concentration to

. the above limit within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> unless the hydrogen concentration is verified to be less than 4% by volume.

b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS

_ 4.11.2.5 The concentration of hydrogen or oxygen in the GASEQUS RADWASTE TREAT-

, MENT SYSTEM shall be determined to be within the above limit by continuously monitoring the waste gases in the GASEOUS RA0 WASTE TREATMENT SYSTEM with the hydrogen or oxygen monitors required OPERA 8LE by Table 3.3-13 of Specification 3.3.3.10. l

]

'J SEA 8 ROOK - UNIT 1 3/4 11-9

)

l PSNH PRESIDENT tr CHIEF EXECUTIVE OFFICER I

NH YANKEE PRESIDENT fr CEO SENIOR VICE PRESIDENT I I VICE PRESIDENT VICE PRESIDENT NUCLEAR ENGINEERING AND PRODUCTION QUALITY PROGRAMS i

STATION I A AGER NUCLEAR QUALITY MANAGER I l

I I DIRECTOR OF CORPORATE DIRECTOR OF I SERVICES MGMT. CONTROL

~

FIGURE 6.2-1

( '

0FFSITE ORGANIZATION ,

l 52ABR00K - UNIT 1 6-2

1T O e o

O .

I li '

• i a I i l 3" .

"1 m j~g as

-!3 I I m Si I b5 Il -

3!E

!*I e a3-tils

,a i 3

5l

. 1 =

l 3 u . _ __.----- .----] N xy

• C

c. ,

ri 3

ij

.- =s llj 8x

~

3) =

• s CSw M M

l 5 I

ii *

. ,i-t6 -

g i

=

is

-

should combine those sections that are comon to all units at the station.

• • This tabulation supplements the requirements of $20.407 of 10 CFR Part 20.

SEABROOK - UNIT 1 6-15

ADMINISTRATIVE CONTROLS g 6.8.1.2 (Continued) -

duration of the specific activity above the steady-state level; and (5) The time duration when the specific activity of the primary coolant exceeded the radioiodine limit.

c. Documentation of all challenges to the pressurizer power-operated relief valves (PORVs) and safety valves.

ANNUAL RADIOLOGICAL ENVIRONMENTAL OPERATING REPORT

• 6.8.1.3 Routine Annual Radiological Environmental Operating Reports covering the operation of the station during the previous calendar year shall be submitted prior to May 1 of each year. The initial report shall be submitted prior to May 1 of the year following initial criticality and shall fr)clude copies of the preoperational Radiological Environmental Program of the unit for at least 2 years prior to criticality.

The Annual Radiological Environmental Operating Reports shall include summaries, interpretations, and an analysis of trends of the results of the radiological environmental surveillance activities for the report period, l including a comparison with preoperational studies, with operational controls, as appropriate, and with previous environmental surveillance reports, and an assessment of the observed impacts of the plant operation on the environment. 1 j

The reports shall also include the results of the Land Use Census required by Specification 3.12.2. ,

1 The Annual Radiological Environmental Operating Reports shall include the results of analysis of all radiological environmental samples and of all l 1

@~ environmental radiation measurements taken during the period pursuant to the l locations specified in the table and figures in the Offsite Dose Calculation Manual, as well as summarized and tabulated results of these analyses and measurements in the format of the table in the Radiological Assessment Branch Technical Position, Revision 1, November 1979. In the event tnat some indi-vidual results are not available for inclusion with the report, the report l shall be submitted noting and explaining the reasons for the missing results.

The missing data shall be submitted as soon as possible in a supplementary j report.

The reports shall also include the following: a summary description of the Radiological Environmental Monitoring Program; at least two legible maps **

covering all sampling locations keyed to a table giving distances and directions from the centerline of one reactor; the results of licensee participation in the Interlaboratory Comparison Program and the corrective action taken if the specified program is not being performed as required by Specification 3.12.3; reason for not conducting the Radiological Environmental Monitoring Program as required by specification 3.12.1, and discussion of all deviations from the sampling schedule; discussion of environmental sample measurements that exceed the reporting levels but are not the result of plant effluents, pursuant to ACTION b. of Specification 3.12.1; and discussion of all analyses in which the LLD required was not achievable.

• A single submittal may be made for a multiple unit station, h **0ne map shall cover locations near the SITE BOUNDARY; the more distant locations shall be covered by one or more additional maps.

SEABROOK - UNIT 1 6-16

~

i l

0 ADMINISTRATIVE CONTROLS -

SEMIANNUAL RADIOACTIVE EFFLUENT RELEASE REPORT * .

6.8.1.4 Routine Semiannual Radioactive Effluent Release Reports covering the operation of the station during the previous 6 months of operation shall be submitted within 60 days after January 1 and July 1 of each year. ine period of the first report shall begin with the date of initial criticality. '

The Semiannual Radioactive Effluent Release Reports shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the station as outlined in Regulatory Guide 1.21, "Measuring, Evaluating, and Reporting Radioactivity in Solid Wastes and Releases of Radioactive Materials in Liquid and Gaseous Effluents from Light-Water-Cooled Nuclear Power Plants," Revision 1, June 1974, with data summarized on a quarterly basis following the format of Appendix B thereof.

For solid wastes, the format for Table 3 in Appendix B shall be supplemented with three additional categories: class of solid wastes (as defined by 10 CFR Part 61), type of container (e.g., LSA, Type A, Type B, large Quantity) and SOLIDIFICATION agent or absorbent (e.g. , cement).

The Semiannual Radioactive Effluent Release Report to be submitted within 60 days after January 1 of each year shall include an annual summary of hourly meteorological data collected over the previous year **.' This annual summary may be either in the form of an hour-by-hour listing on magnetic tape of wind speed, wind direction, atmospheric stability, and precipitation (if measured),  ;

or in the form of joint frequency distributions of wind speed, wind direction, '

and atmospheric stability.*** This same report shall include an assessment of J;3 the radiation doses due to the radioactive liquid and gaseous effluents released J from the unit or station during the previous calendar year. This same report '

shall also include an assessment of the radiation doses from radioactive liquid and gaseous effluents to MEMBERS OF THE PUBLIC due to their activities inside the SITE BOUNDARY (Figure 5.1-3) during the report period. All  :

assumptions used in making these assessments, i.e., specific activity, exposure time, and location, shall be included in these reports. The meteorological conditions concurrent with the time of release of radioactive materials in gaseous effluents, as determined by sampling frequency and measurement, shall be used for determining the gaseous pathway doses. The assessment of radiation doses shall be performed in accordance with the methodology and parameters in the OFFSITE DOSE CALCULATION MANUAL (00CM).

The Sealannual Radioactive Effluent Release Report to be submitted within I 60 days after January 1 of each year shall also include an assessment of radiation doses to the likely most exposed MEMBER OF THE PUBLIC from reactor releases and other nearby uranium fuel cycle sources, including doses from primary effluent pathways and direct radiation, for the previous calendar year

• A single submittal may be made for a multiple unit station. The submittal I

should combine those sections that are common to all units at the station; however, for units with separate radwaste systems, the submittal shall specify the releases of radioactive material from each unit.

• • The dose calculations may be reported in a supplement submitted 30 days later.

• • • In lieu of submission with the Semiannual Radioactive Effluent Release

@% . Report, the licensee has the option of retaining this summary of required meteorological data on site in a file that shall be provided to the NRC upon request.

SEA 8 ROOK - UNIT 1 6-17

aP g O -

ADMINISTRATIVE CONTROLS h SEMIANNUAL RADI0 ACTIVE EFFLUENT RELEASE REPORT .

6.8.1.4 (Continued) to show conformance with 40 CFR Part 190, "Environmental Radiation Protection Standards for Nuclear Power Operation." Acceptable methods for calculating the dose contribution from liquid and gaseous effluents are given in Regulatory Guide 1.109, Rev. 1, October 1977.

The Semiannual Radioactive Effluent Release Reports shall include a list and description of unplanned releases from the site to UNRESTRICTED AREAS of radioactive materials in gaseous and liquid effluents made during the reporting period.

The Semiannual Radioactive Effluent Release Reports shall include any changes made during the reporting period to the PROCESS CONTROL PROGRAM and the 00CM, pursuant to Specifications 6.12 and 6.13, respectively, as well as any major change to Liquid, Gaseous, or Solid Radwaste Treatment Systems pursuant to Specification 6.14. It shall also include a listing of new locations for dose calculations and/or environmental monitoring identified by the Land Use Census I pursuant to Specification 3.12.2.

The Semiannual Radioactive Effluent Release Reports shall also include the following: an explanation as to why the inoperability of liquid or gaseous i l

effluent monitoring instrumentation was not corrected within the time specified l m in Specification 3.3.3.10 or 3.3.3.11, respectively; and description of the j (fg

~

events leading to liauid holdup tanks or gas storage tanks oxceeding the limits of Specification 3.11.1.4 or 3.11.2.6, respectively.

MONTHLY OPERATING REPORTS i 6.8.1.5 Routine reports of operating statistics and shutdown experience shall l be submitted on a monthly basis to the Director, Office of Resource Management, U.S. Nuclear Regulatory Commission, Washington, D.C. 20555, with a copy tn the Regional Administrator of the Regional Office of the NRC, no later than the 15th of each month following the calendar month covered by the report.

RADIAL PEAKING FACTOR LIMIT REPORT 6.8.1.6 The F xy limits for RATED THERMAL POWER (FRTP) shall be provided to x

the NRC Regional Administrator with a copy to Director of Nuclear Reactor Regulation, U.S. Nuclear Regulatory Commission, Washington, D. C. 20555, for all core planes containing Bank "0" control rods and all unrodded core planes and the plot of predicted (F PRel) vs Axial Core Height with the limit en-velope at least 60 days prior to each cycle initial criticality unless other-wise approved by the Commission by letter. In addition, in the event that the limit should change requiring a new substantial or an amended submittal to the Radial Peaking Factor Limit Report, it will be submitted 60 days prior to the date the limit would become effective unless otherwise approved by the Commis-sion by letter. Any information needed to support F P will be by request from the NRC and need not be included in this report.

SEABROOK - UNIT 1 6-18