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| O UN11ED STATES NUCLEAR REGULATORY COMMISSION IN THE MATTER OF: . DOCKET NO: 60 - Y/2 ADVISORY COMMITTEE ON REACTOR SAFEGUARDS SUBCOMMITTEE ON BEAVER VALLEY POWER STATION, UNIT 2
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| LOCATION: PITTSBURGH, PENNSY'JANIA PAGES: 1- 240 DATE: FRIDAY, NOVEMBER 1, 1985 n es n n y.; v . -,., ,. a
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| ACE-FEDERAL REPORTERS, INC.
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| OfficialReporters 444 North CapitolStreet Washington, D.C. 20001 (202)347-3700 St gy 8511150003 851101 NATIONWIDE COVERACE PDR ACRS T-1462 PDR
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| 9220'01 01 ,
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| .( )rysimons 1 UNITED STATES OF AMERICA 2 NUCLEAR REGULATORY COMMISSION 3 ADVISORY COMMITTEE ON REACTOR SAFEGUARDS 4 SUBCOMMITTEE ON BEAVER VALLEY UNIT NO. 2 5 Holiday Inn Airport Hotel 6 1406 Beers School Road
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| -7 Coraopolis, Pennsylvania 8 Friday, November 1, 1985 9 The subcommittee convened, pursuant to notice, at 10 8:30 a.m., Charles J. Wylie, Chairman 11 12 0 13 14 15 ,
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| 16 ,
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| 17 18 19 20 21 22 23 24 25 ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800.336-6646 L
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| i PUBLIC NOTICE BY THE UNITED STATES NUCLEAR REGULATORY COMMISSIONERS' ADVISO'AY COMMITTEE ON REACTOR SAFEGUARDS FRIDAY, NOVEMBER 1, 1985 The contents of this stenographic transcript.of the proceedings of the United States Nuclear Regulatory Commission's Advisory Committee on Reactor Safeguards 1
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| (ACRS), as reported herein, is an uncorrected record of 4
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| the discussions recorded at the meeting held on the above date.
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| No member of the ACRS Staff and no participant at' this meeting accepts any responsibility for errors or inaccuracies of statement or data contained in this-transcript.
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| O e
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| O
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| '9220 01 01 2-3 l ;rysimons 1- NRC STAFF AND PRESENTERS PRESENT:
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| 2 J. ARTHUR 3 J. CAREY 4 J. SIEBER 5 G. KURTZ 6 R. MARTIN 7 R. SWIDERSKI 8 T. JONES 9 G. EWING 10 T. BURNS i
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| 11 K. GRADA-12 F. SCHUSTER 13 E. EILMANN J
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| 14 R. FEDIN 15 R. DRUGA 16 K. TROXLER 17 G. KNIGHTON 18 B. SINGH 19 E. WENZINGER 20 R. WALTON 21 .
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| 22 23 4 24 25 1
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| i ACE-FEDERAL REPORTERS, INC.
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| 3)2 347-3700 Nationwide Coverage 800-336-6646
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| _ . . _ ~ , . - _ __ ___ _ _ _ . , . . _ ~
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| 4
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| ( 30 01 01 4 mnrysimons 1 PROCEEDINGS 2 MR. WYLIE: The committee will now come to order.
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| 3 'This is a meeting of the ACRS Subcommittee on Beaver Valley 4 Unit 2.
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| 5 I'm Charles Wylie, subcommittee chairman. The 6 other ACRS members in attendance are Mr. Ebersole, Mr.
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| 7 Kerr, and Mr. Remick.
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| 8 The purpose of this meeting is to review the 9 application by Duquesne Light Company for an operating 10 license for Beaver Valley Power Station Unit No. 2.
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| 11- Herman Alderman is the ACRS staff member for this O
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| (/ 12 meeting.
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| 13 The rules for participation in today's meeting 14 have been announced as part of the notice of this meeting 15 that was published in the Federal Register on October 22, 16 1985.
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| 17 We have a very tight schedule today and I'd like 18 to request that we adhere to the schedule and try to finish 19 ahead of time.
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| 20 (Laughter) 21 MR. WYLIE: It's requested that each speaker first 22 identify himself or herself and speak with sufficient 23 clarity and volume so that he or she can be readily heard.
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| 24 We have received no written comments from members 25 of the public. We have received no requests for time to ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| 9220 01 5 (v''?rysimons 1 make oral statements from members of the public.
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| 2 Do any of the subcommittee members have any 3 comments at this time?
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| 4 (No response) 5 MR. WYLIE: We will now proceed, then, with the 6 meeting in accordance with the schedule and I call on Mr.
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| 7 Jack Carey for the first presentation. Mr. Carey?
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| 8 MR. CAREY: Thank you. My name is Jack Carey, I 9 am vice president of the Nuclear Group of the Duquesne 1G Light Company and responsible for the construction, 11 engineering-construction start-up and operation of the No.
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| 12 2 unit which we are attempting to license.
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| () 13 (Slide presentation) 14 'The Duquesne Light Company is a member of the ECAR 15 -- the East Central Area Reliability power pull. This map 16 displays the major power pulls in the United States. The 17 Duquesne Light Company specifically is a member of CAPCO, 18 the entire CAPCO group which is a part of this ECAR -- East 19 Central Area Reliability coordinating group.
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| 20 The CAPCO power pool is composed of the Cleveland 21 Electric Illuminating Company, Duquesne Light Company, Ohio 22 Edison Company, Pennsylvania Power Company, and the Toledo 23 Edison Company.
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| 24 (Slide) l
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| () 25 This depicts the area that is served by the ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800-33M646
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| 9220 01 01 6
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| .[v;rysimons1 members of the CAPCO group.
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| 2 Duquesne Light Company provides service to 3 Allegheny and Beaver Counties within essentially all of 4 Allegheny and Beaver Counties although there are slight 5 areas that are not covered in these counties that are 6 covered bv other power companies.
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| 7 The Beaver Valley Power Station is located about 8 25 air miles roughly west-northwest of the City of 9 Pittsburgh.
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| 10 (Slide) 11 This is a view of the site on which we are 12 constructing the Beaver Valley No. 2 unit. The two cooling O
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| 4,,/ 13 towers in the foreground are the Beaver Valley site. The 14 one on the left, closest to the river, serves the No. 1 15 unit which is presently in operation, and the one on the 16 right is the cooling tower that has been built to serve the 17 Beaver Valley No. 2 unit.
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| 18 In the background, there are three cooling towers 19 which serve the Bruce Mansfield Power Station. The Bruce 20 Mansfield is a coal-fired plant that is comprised of three 21 800-odd megawatt coal-fired units equipped with wet 22 scrubbers for sulfur-dioxide control. These units are also 23 CAPCO units.
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| 24 (Slide)
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| (m
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| _) 25 This is yet another view of the Beaver Valley ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800-336 6646
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| 9220 01 01 7
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| (')rysimons 1 -site. As you can see probably not too well on this x>
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| 2 picture, on the far left is the Shipping Port Atomic Power 3 Station which was contracted for in 1954 and completed and 4 went into service in December of 1957. It-was owned by the 5 Naval Reactors Branch of the Department of Energy, the 6 reactor, and Duquesne Light Company owned the turbine 7 generator portion of the plant and operated the entire 8 plant, the reactor portion of the plant under contract to 9 the Naval Reactors.
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| 10 Beaver Valley No. 1 unit, the contract was signed I
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| 11 in about 1968. We applied for a construction permit and 12 were granted a construction permit in June of 1970. The
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| () 13 plant went into commercial operation in October of 1976.
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| 14 Beaver Valley No. 2 unit was contracted for in 15 1971. We received a construction permit in January of 16 1974, and we hope to placo the plant into commercial 17 operation August 31, 1987. The plant is presently about 18 89.5 percent complete. The fuel loading should perform a 19 hydrostatic test of the reactor coolant system March 15, 20 1986, October 15, 1986 hot functional testing of the plant, 21 with fuel loading scheduled to follow in April of 1987.
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| 22 We are presently on schedule to meet all the major 23 milestones to accomplish the commercial operation date of 24 August 31, 1987.
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| O 25 (S11de)
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 800-33MM6
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| s 9220.01 01 8 ;
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| .hrysimons1 Just another v'iew of.the' Beaver Valley site.
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| '2 (Slide)-
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| 3 The ownership shares of Beaver Valley Unit No. 2 4 are_as follows: The Ohio Edison Company owns 41.8 percent; 5~ Cleveland Electric Illuminating Company, 24.4 percent; 6 Toledo Ed33on, 19.91, and Duquesne Light, 13.74 percent. .
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| r 7 'Duquesne. Light Company, even though a minority 8 owner, is responsible for the engineering, construction, 9 and will be. responsible for-the operation of the facility.
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| 10 (Slide) 11 The plan of the plant lay-out is shown, displayed, 12- here. ~No. 2 unit is essentially a duplicate of No. 1 D'v 13 unit. Over the many years between the units, there have 14 been several changes but the plant lay-out is roughly the 15 same.
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| 16 We have made numerous changes to accomodate the i
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| 17 design improvements required to respond to the NUREG 737 18 which was issued subsequent to the Three Mile-Island event, 19 and we have also attempted, to the best of our ability, to 20 incorporate other reliability improvements based upon our 21 experience on No. 1 unit, having installed these similar 22 types of design improvements.
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| '23 The philosophy of the Duquesne Light Company with 24 respect to the operation of our nuclear facilities is, we 25 have a published policy that is displayed throughout the ACE FEDERAL REPORTERS, INC.
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| Nationwide Coverage 800
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| -._._..____._.__.--_,,._____._._._-.____._.._._____._...._,_-3366646.,
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| 202 347 3700 _ _ _ _.,_..-, _._._ _.
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| 7 9220 01 01 9 (ojrysimons 1 plant that all of our employees and other workers on the i 2 site should understand.
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| 3 We believe that our job is to protect the health 4 and safety of the public; protect our employees and other
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| -5 workers on the site; to protect the plant and the equipment 6 installed in it; to provide continuous and reliable 7 electric service to our customers, and to operate and 8 maintain our facilities at the lowest cost consistent with 9 achieving the above priorities.
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| 10 In order to accomplish these goals, we have 11 established a comprehensive training program for our 12 workers. We conduct an effective preventive and corrective (s
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| (._) 13 maintenance program. We have established an ALARA program
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| [
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| 14 to ensure that all workers receive the lowest reasonably 15 achievable amount of radiation dose in the performance of 16 their job duties.
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| 17 We attempt to minimi7e the discharge of effluents 18 and to carefully monitor those that are emitted.
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| 19 We have established an effective emergency plan 20 and we operate the plant in accordance with established 21 operating procedures. Our workers attempt to maintain an 22 integrity and openness to the issues associated with the 23 operation of the plant.
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| 24 We deal honestly and openly with the Nuclear O(_) 25 Regulatory Commission, the local people in the area -- be ACE FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 336-6646
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| 9220 01 Ol' 10 G
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| :!s,,;rysimons 1 they political' groups or other members of the general 2 public.
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| 3 We attempt to establish the highest quality job 4 performance on the part of our workers. We expec't them to 5 adhere to the established procedures, including the 6 administrative controls under which they must perform their
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| .7 duties. To do this with an attention to detail required to 8 ensure that all work is performed in a quality manner.
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| i 9 Most of all, we attempt to instill-team work on 10 the part of our people to ensure that each individual is 11 fully aware of the condition of the plant and the other 12 work activities that are being conducted. .
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| ) 13 We believe that upon being granted an operating i-14 license, we will continue to operate the. Beaver Valley No.
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| 15 2 unit in accordance with the high standards that we have 16 established for the operation of No. 1 unit.
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| 17 With that, I'd like to turn this over to Roger 18 Martin, the manager of engineering, who will describe the 19 design differences between Beaver Valley No. 1 unit and 20 Beaver Valley No. 2.
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| 21 MR. REMICK: Mr. Carey, I'd like to ask a question 22 if I may, please.
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| ! 23 MR. CAREY: Yes, sir.
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| l 24 MR. REMICK: Do you have any plant indicators that <
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| /~T you use to help you know whether you feel that the plant is
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| \_/ 25 e
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| i
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| ; ACE FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 336 6646
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| 9220 01 01 11
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| ( jrysimons 1 being -- I'm referring to Unit I now -- that you have a way 2 of determining whether you are satisfied that the plant is 3 operating properly?
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| 4 And then the second part of that question, with 5 any of those plant indicators, have you established any 6 corporate goals reducing man-rem occupational exposure or 7 reduction of waste, or any item like that?
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| 8 MR. CAREY: Yes, we have. Among the many' goals 9 that we have is to maintain our solid waste shipments at 10 the lowest-possible amount 11 We ship about 650 cubic feet of solid waste every 12 month, and we believe that that is among the lowest in the r) is_ 13 industry.
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| 14 We established overall man-rem exposure goals.
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| 15 These goals are established annually depending upon whether 16 or not there is a refueling since, certainly, the large 17 amount of radiation exposure is accrued during the 18 performance of the many inspections and testing, and 19 maintenance activities, that are conducted during the 20 annual refueling.
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| 21 But we believe that our radiation exposure ranks 22 in the median of the industry and we are continually 23 striving to attempt to improve our radiation exposure.
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| 24 We have also established a goal for the year 1985
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| () 25 of 80 percent availability for the unit. We presently are ALE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800-336 6646
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| i 9220 01 01 12 (1rysimons1- operating at 90 percent overall availability for the unit, 2 since January 1, and we believe that we will exceed our 3 established 80 percent availability goal for the year.
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| 4 We have also instituted a trip reduction program 5 under which we fully evaluate every reactor trip, attempt 6 to identify the root causes, and will take actions.to 7 attempt as best we can to reduce the rate of reactor trips 8 to three per year or less. We are presently operating at 9- slightly over-that.
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| 10 MR. REMICK: The four goals you mentioned are 11 quantified. In other words, you mentioned the 85 percent
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| . 12 and the three trips and the waste. Have you set a goal, a
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| '( 13 certain number of cubic feet in the same way the man-rems?
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| , 14 Do you set those yearly or is it just as low as reasonably-15 achievable?
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| 16 MR. .CAREY: Well, our solid waste goals, we have 17 established at 650 and we believe that right now, based 18- upon our experience, that is about as low as we can 19 achieve. We can think of nothing we can do, truly, to 20 reduce it much beyond that.
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| 21 MR. REMICK: And I assume your employees know of 22 those goals, hopefully everyone realizes what the corporate 23 goals are for the year?
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| 24 MR. CAREY: Yes, they do.
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| 25 MR. REMICK: Thank you.
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| ACE-FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800-336 6646
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| i 9220a01 01 13
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| ' ~s
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| . jrysimons 1 MR. KERR: Mr. Carey, what has been the average 2 availability of Beaver 1 since you went commercial; do you 3 know?
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| 4 MR. CAREY: The average availability for No. 1 5 unit is 50-odd percent. We experienced in our early years i
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| 6 of operation a main transformer failure. We experienced 7 some problems with the design, the seismic design of the 8' piping systems, and we experienced an extended outage 9 during which time we inspected the pipe support system and 10 re-analyzed the pipe support system. That has kept the 11 plant off for over nine months.
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| 12 At the end of that effort, we modified r~T '
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| (_) 13 approximately four supports out of the 4,000-odd that are 14 installed in the No. 1 unit, and we also did a significant 15 amount of shimming of other supports to ensure that the 16 installed gaps met the gaps that had been utilized in the 17 computer code under which the design was established.
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| 18 MR. KERR: You mentioned your availability since 19 the first of the year. What was the availability in 20 calendar year '847 21 MR. CAREY: In the year of '84 our availability 22 was 73 percent, I believe. Just a minute here 00 71.8 23 percent.
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| 24 MR. KERR: And what was the number of unplanned (O
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| (,) 25 trips that occurred in '84? If you don't have this and can ACE-FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 33(H5646
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| 9220'01 01 14 fT
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| .( ,2rysimons 1 get it --
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| 2 MR. CAREY: I can get it.
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| 3 MR. ARTHUR: We can get that for you, sir.
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| i 4 MR. KERR: On what basis did you select three as a i 5 goal, was it based no experience?
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| 6- MR. CAREY: No, sir. Three was selected on the !
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| 7 basis that the NUMARC -- the Nuclear Utility Management and 8 Resources Committee -- of which I am a member of the 9 Executive Group, we met and discussed the experience of the 10 reactor trip rate of all of the plants in the country and 11 after considerable discussion, the goal of three per year 12 was established for all nuclear utilities in the United 13 States.
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| . 14 We believe that with some extra effort and 15 attention to detail, that we should be able to operate 16 Beaver Valley at that rate. We are not experiencing that 17 rate right now, I'm sorry to say. But we are going to make 18 every effort possible to reduce our rate of trips.
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| .9 We are running at about twice that, but we will do 29 everything possible to meet the goal that has been 21 established by NUMARC.
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| ! 22 MR. KERR Thank you.
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| 23 MR. WYLIE: The next speaker then, I guess.
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| 24 MR. MARTIN: My name is Roger Martin, and I'm i 25 engineering manager for Duquesne Light. I have had over 30 ACE. FEDERAL REPORTERS, INC.
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| . . _ _ _ . . _ _ _ . . _ 202 347 3700 . __ _ _ Nationwide Coversge
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| . , , _ _ _ _ _ _ 800 33M_ __ _ _ _ _ .
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| 9220 01 Ol' 15
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| ( jrysimons 1 years of nuclear utility experience in operations, fuel 2 management, and design.
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| 3 I was the operations supervisor on duty-at 4 Shipping Port at the time of initial criticality.
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| 5 (Slide presentation) 6 As usually is the case when we have a tour before 7 the formal presentation, some of the unique features of the 8 plant have been previously discussed and, in keeping with 9 Chairman Wylie's suggestion, I will keep my comments very 10 brief.
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| 11 Beaver Valley 2 was designed to duplicate Beaver 12 Valley 1 whenever possible. However, certain modifications
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| () 13 were made in order to optimize safety and reliability 14 considering information that was gained from the continuing 1
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| 15 study of the Beaver Valley 1 operating characteristics. I 16 And since there will be an approximately eleven-17 l year time span between the Unit 1 initial operation, its 18 design has incorporated -- the Beaver Valley 2 design has 19 incorporated many lessons learned in the nuclear industry 20 during the intervening period.
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| 21 I would like to first call your attention to the 22 start-up feed pump. As you recall, last evening we 23 discussed this pump. It's a 900,000 gallon, 400 horsepower 24 motor-driven pump. It takes its suction from the
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| ) 25 condensate system. It can be used for a hot stand-by ACE-FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 336-6646
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| F 9220 01 01 16 i j
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| ,rysimons 1 operation or light load conditions up to 30 megawatts.
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| 2 It can be used in place of one of the two motor-3 driven main feed pumps which are 15,000 gallon per minute 4 units. If one of these main feed pumps is unavailable, the 5 discharge characteristic of the start-up feed pump and the 6 main feed pumps are similar, so that the start-up feed pump 7 can be operated in parallel with one of the main feed pumps 8 and the plant capacity should be approximately 80 percent, 9 whereas,without the start-up feed pump, using one single 10 main feed pump, the capacity would be approximately 60 11 percent.
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| 19 There has been quite a bit of interest in the O
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| 's / 13 alternate shut down panel. This will be discussed in more 14 detail in this afternoon's session. However, its purpose 15 is to bring the plant to cold shutdown within 72 hours 16 following a single exposure fire that is postulated to 17 occur in one of four areas -- the cable spreading area, the 18 relay room area, cable tunnel or the west communications 19 area.
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| 20 An operator at this panel can transfer control 21 without change in the equipment status from the control 22 room to the alternate shutdown panel. This is accomplished 23 at the alternate shutdown panel.
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| 24 The panel room is in a controlled environment. It O
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| (J 25 is near the control room in the auxiliary building, and it ACE FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800-336-6646
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| 1 I9220 01 01 17 l[');rysimons 1 provides ability to. remove heat from the reactor coolant s_-
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| 2 system by steam generator bleed and feed, control 3 reactivity, control the reactor coolant system volume and 4 pressure, and remove the residual heat, and to control off-5 site emergency power.
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| 6 Beaver Valley 2 also has an approach to cold 7 shutdown. While the safe shutdown basis for Beaver Valley 8 2 was originally hot standby, the cold shutdown capability 9 of the plant has been evaluated in order to demonstrata how 10 the plant can achieve cold shutdown conditions following a 11 < safe shutdown earthquake, assuming loss of off-site power 12 as the most limiting single failure.
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| _(/ 13 Under such conditions, the plant is capable of 14 achieving residual heat removal syst'em operation -- that's 15 350 degrees Fahrenheit, 400 psig, within 36 hours.
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| 16 Actually, this can be accomplished in approximately four 17 hours, or we have designed it to accomplish this in four 18 hours.
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| 19 MR. EBERSOLE: Mr. Carey, may I ask you a 20 question?
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| 21 You mentioned that this panel could cope with an 22 exposure fire in four areas, I believe. Are there any 23 other areas in the plant where the conversion of circuitry 24 and so forth merely follows the guidelines of Reg 175 and I )' 25 thus is susceptible to a similar exposure fire for which ACE. FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 800 336 4646
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| .9220 01 01 18 l
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| ()rysimons1 this panel cannot provide a shutdown?
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| 2 MR. MARTIN: These four areas were selected as the 3 areas that were most subject to a fire condition.
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| 4 MR. EBERSOLE: ,
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| Yes.
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| 5 MR. MARTIN: And individual control cables were 6 taken from this panel to the vital equipment, so that they 7 would not go through the areas that were selected.
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| 8 MR. EBERSOLE: I understand. Let's suppose that I 9 at least postulato a manhole or tunnel some place where I 10 have the typical convergence of circuitry to the separated 11 standards required by Reg Guide 175 and thus I have another 12 incipient potential for fire to take place.
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| () 13 This panel won't account for the shutdown in that 14 case?
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| 15 MR. MARTIN: May we request that we defer this to 16 the detailed speaker in the afternoon --
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| 17 MR. EBERSOLE: Okay, thank you.
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| 18 MR. MARTIN: --
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| to give us a chance to make sure 19 that your answer is prepared.
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| 20 This shutdown panel can vent from the reactor 21 pressure vessel and vent from the pressurizer and the main 22 steam system, pressure-operated valves. You can borate, 23 should be able to use coolant let-down and bring the plant 24 to a safe cold shutdown condition.
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| () 25 Full flow condensate demineralizers are provided.
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| * ACE. FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 336 4 646
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| i l
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| 1
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| :9220'01 19 This condensate policy insisting that you remove the ionic (V:'irysimons1 2 and particulate contaminates utilizing powdered resin-3 placed on pre-cold filters.
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| 4- There are five units required. One is a spare.
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| 5 The flow is 17,000 gallons per minute. These units remove 6 copper, silica, dissolve solids. Our objective is ten part 7 per million dissolved solids.
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| 8 These contaminates might result from possible 9 steam generator or condenser tube leakage. This condenser 10 domineralizer system has its own air supply system, and the 11 flow of condensate would automatically be diverted around 12 all of these units on a high differential pressure. The
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| () 13 valve fails open so that there would be no loss of flow to t' 14 the main heat pumps.
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| 15 The main steam line break size limitation to 1.4 16 square feet by the installation of flow limiters in the 17 steam generator discharge nozzles allows for a lower 18 concentration of boron.
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| 19 The boron injection tank which in previous designs 20 had a concentration of approximately 20,000 parts per 21 million is not required since the refueling water storage 22 tank, or.the boric acid tanks, would have a 2,000 part per 23 million boric acid solution.
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| 24 So that shutdown and the reactivity control could
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| () 25 be accomplished by charging pumps feeding borated water ACE-FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 336 6646
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| 9220 01 01 20 m rysimons 1 into the system, taking suction either from the 820,000 t
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| f 2 gallon refueling water storage tank or boric acid tanks.
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| 3 To reduce the potential for radioact.ive 4 contaminated air being released to the atmosphere during 5 normal conditions, there are two redundant exhaust fans 6 that draw air through HEPA filters and charcoal delay beds 7 and discharge through the duct work to the release point 8 150 feet above grade or on top of the reactor containment.
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| 9 This continuous auxiliary building exhaust 10 filtration system does or should process the exhaust air 11 from the main steam valve house, the fuel building, the 12 charging pump area, the component cooling area, solid waste O(_/ 13 area, as well as the auxiliary building.
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| 14 I'll mention several lesser dif'erences. The 15 first item would be the main steam isolation valves are 16 ball-type valves, Crosby valves, versus the intercept or 17 reverse flow check valves, the double check valve that is 18 installed in Unit No. 1.
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| 19 It is our hope that those will be of simpler 20 operation and the testing will be simply because the check 21 valve flapper will not be held up .in the steam flow path in 22 normal operation.
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| 23 Digital versus analog radiation monitoring has 24 been installed. Also, the control rod position indication A
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| () 25 is a digital system. The ability to store more information ACE FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 336-6646
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| 9220 01 01 21
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| ( ):rysimons 1 to receive and process this historical data more 2 effectively was the reason that we chose the digital 3 system.
| |
| 4 Unit No. 2, the containment air compressors are 5' outside the containment. They have motor-operated back-up 6 valves that would provide air from the instrument air 7 system being in the outside of the containment.
| |
| 8L Maintenance on these compressors would be more convenient.
| |
| 1 9 The four recirculation spray pumps are outside the 10 containment. Here again, easy maintenance and mild 11 environment was the reason for this selection.
| |
| 12 The final item would be the automatic update of
| |
| '( ) 13 the system by-pass and inoperable status information in the 14 control room is updated by the computer automatically.
| |
| 15 One question was asked yesterday about the turbine l 16 generator alignment, about the missile question.
| |
| 17 The turbine generator low pressure spindles on 18 Unit No. 2, the original spindles were replaced with 19 partial integral rotor-type spindles.
| |
| 20 This design eliminates the key way in the first 21 six stages of the blades. The bore of the integral part of 22 the rotor is not exposed.' The exposed parts have lower 23 stress and this permits the use of material less 24 susceptible to cracking.
| |
| () 25 In-service inspection is the approach that is used ACE. FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 3364646
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| 9220 01 01 22
| |
| ()rysimons1 to determining the condition of these rotors and a not to 2 be exceeded ultrasonic inspection interval and in-service
| |
| . 3 inspection program will be developed based on the results 4 of the worst-case deterministic inspection interval report.
| |
| 5 The inspection interval we calculated as the time 6 of a hypothetical crack to reach one-half of the critical 7 crack size. This analysis has been described in the 8 Westinghouse report that was issued in June '81. An update 9 of that report specific to the Beaver Valley 2 spindles 10 will be provided by mid-86.
| |
| 11 The worst-case deterministic inspection interval 12 report will employ the most conservative yield strength and p)
| |
| (_- 13 fracture toughness values permissible by material .
| |
| 14 specifications. And the worst-case deterministic 15 inspection interval report will provide a high degree' of 16 assurance that the turbines will be ultrasonically 17 inspected well before stress corrosion could lead to 18 failure.
| |
| 19 That completes my comments.
| |
| 20 MR. WYLIE: Any questions?
| |
| 21 MR. REMICK: Yes. I assume that your start-up 22 feed pump is fully operable from the control room?
| |
| 23 MR. HARTIN: Yes.
| |
| 24 MR. REMICK: And on your full flow condensate
| |
| ( 25 demineralizers, do you regenerate those resins or are they -
| |
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| E 347 3700 Nationwide Coverage 800 336-6646
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| 9220 01 01 23
| |
| ([;rysimons1 -
| |
| 2 MR. MARTIN: They are discharged. Tney are 3 powdered resin, y, ,
| |
| 4 MR. REMICK: And I assume they are a potential low-t 5 level waste.
| |
| 6 MR. MARTIN: Yes. We provided for the discharge 7 of the low-level waste, recognizing that if there is a 8 major tube failure, that this would be a consideration.
| |
| 9 Under normal operation and the experience we have 10 had with flow-down demineralizers in Unit No. 2 on the 11 steam generators, the activity level has not necessitated 12 shielding under normal conditions.
| |
| rm n'
| |
| (,) 13 MR. REMICK: But you do have to handle it --
| |
| 14 MR. MARTIN: Yes.
| |
| 15 MR. REMICK: What percentage of your annual low-16 level waste volume will come from those demineralizer
| |
| , 17 resins; do you have a feeling for that?
| |
| 18 MR. MARTIN: Not on the top of my head. But we 19 anticipate from experience that has been gained in other 20 plants that if the two failure leakage -- it's based upon 21 the two-failure leakage. Of course, if the two-failure 22 ' leakage is very low which we have experienced very low tube-23 failure leakage in Unit No. 1 steam generators, this should 24 not be a problem.
| |
| 3 ,
| |
| s,) '
| |
| 25 We can try to get that answer for you.
| |
| I ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverase 800-33H646 1
| |
| | |
| 9220 01 01 24 (3jrysimons 1 MR. REMICK: Do you anticipate the waste from Unit 2 2 will be equal to Unit 1, or less, or more? Any 3 anticipation of whether --
| |
| 4 MR. MARTIN: We anticipate, we have reason to 5 believe that the use of the powder demineralizers will not 6 increase significantly the amount of radioactive waste that i
| |
| 7 needs to be discharged. And that is based upon our close !
| |
| 8 chemistry control on'our steam generators and the 9 experience we have had on similar steam generators on Unit 10 No. I where, I believe, only one tube failure which was not 11 attributed to corrosion occurred in the operating history 12 of the plant to date.
| |
| '() 13 MR. REMICK: All right, thank you.
| |
| 14 MR. EBERSOLE: May I ask just a brief question
| |
| , 15 about the sub-atmospheric containment?
| |
| l 16 MR. MARTIN: Yes.
| |
| 17 MR. EBERSOLE: You maintain a pretty substantial l 18 vacuum in that thing.
| |
| 19 MR. MARTIN: Yes.
| |
| 20 MR. EBERSOLE: So each entry into it becomes 21 somewhat of a dynamic event.
| |
| 22 MR. MARTIN: That is true. We try to keep our 23 entries as few as possible.
| |
| 24 MR. EBERSOLE: Right. What limits the ultimate
| |
| () 25 depressurization that you can get with your exhausting ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| 9220 01 01- 25
| |
| .(])rysimons1 system and what is the actual margin of safety?
| |
| 2 MR. MARTIN: Actually, under normal conditions the 3 small evacuation pump would, I believe, take --
| |
| 4 MR. EBERSOLE: A long time.
| |
| 5 MR. MARTIN: -- a number of hours to get to that 6 low pressure.
| |
| 7 MR. EBERSOLE: Yes. Is there any potential for
| |
| ~8 suddenly getting a step decrease in pressure due to the 9 introduction of cold spray?
| |
| 10 MR. MARTIN: Excuse me?
| |
| ~
| |
| 11 MR. EBERSOLE: Cold spray water?
| |
| 12 MR. MARTIN: The recirculation spray?
| |
| -( ) '13 MR. EBERSOLE:- Yes. If you suddenly inadvertently 14 introduce that, do you then get a st5p change'in the 15 negative direction which, would be unfortunate?
| |
| 16 MR. CAREY: Excuse me, I'd like to answer that.
| |
| 17 We have analyzed that. We operate at about nine and-a-half 18 to ten-pound absolute pressure, and we have calculated, I 19 believe, that with the introduction of spray we would get 20~ down to something like 8.4. If we get below that, there is 21 a possibility that the containment minor could buckle.
| |
| 22 I believe that's the question you asked.
| |
| 23 MR. EBERSOLE: Well, when it pops off, should it 24 pop off? What happens to the operating equipment in the
| |
| () 25 aftermath of shedding the liner?
| |
| ACE FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverase 800 33(Hi646
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| | |
| ~
| |
| 9220 01 01 26 (a';rysimons 1 MR. CAREY: There is no problem with the operating 2 equipment. The real problem was the possibility that we 3 may get a slight b ckling of'the containment liner if we 4 get -- but we have analyzed, as I say, that as long as we 5 maintain our pressures within our tech spec limits, that 6 there is no problem even should the pray be introduced.
| |
| 7 We operate the containment at about 95 degrees 8 maximum and our WST operates at about 43 degrees, so that 9 the amount of chilling is not so significant that it would 10 affect our pressure.
| |
| 11 MR. EBERSOLE: So you could go down to eight 12 pounds absolute.
| |
| () 13 MR. CAREY: That's correct.
| |
| 14 MR. EBERSOLE: Or about seven pounds 15 differential. And you say the liner would begin to depart 16 when?
| |
| 17 MR. CAREY: If we get below about eight pounds, 18 the liner could possibly buckle.
| |
| 19 MR. EBERSOLE: Buckle.
| |
| 20 MR. CAREY: Right. .
| |
| 21 MR. EBERSOLE: Does it just buckle or isn't that 22 an unstable condition and the buckling progresses in the 23 negative pressure mode?
| |
| 24 It's secured to the concrete, isn't it?
| |
| O)
| |
| (, 25 MR. CAREY: That's correct.
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800-336-6646
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| .9220 01 01 27
| |
| ("')rysimons 1 MR. EBERSOLE: All right. Thank you.
| |
| .s_/
| |
| 2 MR. WYLIE: Any further questions?
| |
| 3 If not, the next speaker.
| |
| 4 MR. KURTZ: The next speaker will be Rich 5 Swiderski.
| |
| 6 MR. SWIDERSKI: Good morning. I'm Richard 7 Swiderski, manager of start-up for Duquesne Light Company.
| |
| 8 My subject this morning is the construction status of 9 Beaver Valley Unit 2 as well as the start-up schedule for 10 Unit 2.
| |
| 11 (Slide presentation) 12 Through the end of September 1985, Beaver Valley
| |
| /*g is) 13 -Unit No. 2 is 89.3 percent physical completion. Beaver 14 Valley Unit No. 2 is on schedule at this time towards our 15 fuel load date of April 1987.
| |
| 16 (Slide) 17 The next slide here illustrates the status of the 18 various major buildings associated with Beaver Valley Unit 19 No. 2 and their respective physical completion. A 20 composite of these percentages make up our 89.3 percent 21 physica'. completion.
| |
| l 22 (Slide) j l
| |
| 23 The next slide illustrates the status of our major 24 mechanical commodities associated with Beaver Valley Unit
| |
| ( )) 25 2. We have the small bore piping hangers, large bore pipe ACE-FEDERAL REPORTERS, INC.
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| 3)2-347-3700 Nationwide Coverage 800-336-6646
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| | |
| ; 9220 01 01 28 f()rysimons1 hangers, instruments, the seismic instrument supports, 2 stainless steel tubing and copper tubing respectively.
| |
| 3 Their estimated completion in linear feet or by 4 commodity, the actual installed to date and the percentage 5 complete overall.
| |
| 6 (Slide) 7 The next slide here illustrates the status of our 8 major electrical commodities associated with the plant. As j 9 we can see again in this slide here, the physical l 10 completion of the plant is moving well along to support our 11 testing schedule.
| |
| 12 (Slide) i
| |
| '( ) 13 The last slide we have here illustrates the l
| |
| 14 critical path to fuel load for Unit No. 2. The status to l I
| |
| 15 date of the critical path is that we have completed the I 16 energization of the station service transformers in the l
| |
| l 17 upper left-hand corner.
| |
| 18 We have also achieved turbine on turning year. We 19 have been able to demonstrate the ability to pull vacuum on 20 the condenser, and we are in the process now of starting 21 the testing of our emergency diesel generators.
| |
| 22 Our next major milestone for Unit No. 2 is to 23 accomplish steam generator hydro on December 10, 1985.
| |
| 24 This will be followed by reactor coolant system hydro in
| |
| ) 25 March of 1986, odd functional testing, October 20 of 1986, ACE-FEDERAL REPORTERS, INC.
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| EM3# Nationwide Coverage 800-336 6646
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| l 9220 01 01 29
| |
| ({}rysimons1 followed by our structural integrity tests and IORT test in 2 February of '87, followed by fuel load in April of 1987.
| |
| 3 Our plans this year are also to demonstrate the 4 ability for a fuel load test on our emergency diesels by ,
| |
| 5 year end.
| |
| 6 Do we have any questions?
| |
| 7 MR. KURTZ: The next speaker will be Jack Sieber.
| |
| 8 (Slide presentation) 9 MR. SIEBER: Good morning. My name is Jack 10 Sieber. I hold two positions in the Duquesne Light 11 organization. The first is senior manager of Beaver Valley 12 1, which is an interim position until Beaver Valley 2 is
| |
| (_j 13 ready for commercial operation.
| |
| 14 And secondly, as general manager of the Nuclear 15 Services unit which combines some technical support 16 activities and administrative activities associated with 17 both Beaver Valley Unit 1 and Unit 2.
| |
| 18 1985 marks Duquesne Light Company's 28th 19 continuous year as the operator of a commercial nuclear 20 power station. Our operating history began in 1957 with 21 the initial operation of the Shipping Port Atomic Power 22 Station which was a four-loop pressurized water reactor.
| |
| 23 Beaver Valley Unit 1 was licensed to operate in 24 1975 and is now in its fifth cycle of operation. Beaver (j 25 Valley 2 is being constructed on the same site as the l
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646 l
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| | |
| 9220 01 01 30
| |
| ({])rysimons 1 Beaver Valley No. 1 unit and the Shipping Port Atomic Power 2 Station.
| |
| 3 Because of our long history and the significant 4 portion of the company's resources which are involved in 5 our nuclear projects, we are dedicated as a team to the 6' safe and reliable operation of these plants.
| |
| 7 (Slide) 8 My subject this morning is the organization of the 9 Duquesne Light Company Nuclear Group. Some of the special 10 features of the Nuclear Group, of course, are 28 years of 11 experience in operating nuclear power plants.
| |
| 12 The second one is that we have virtually 8 all of
| |
| () 13 our operating, maintenance, engineering-construction and 14- our corporate staff for the nuclear group located on site.
| |
| 15- Because all three of our nuclear projects are on the same 16 site, this becomes a very valuable tool for us.
| |
| 17 The third is that we have both in quantity and 18 quality ample human resources to operate these plants.
| |
| 19 And lastly, we try to achieve a minimal reliance 20 on consultants and contractors in permanent operating 21 positions.
| |
| 22 (Slide) 23 The organization now in effect at Duquesne Light's 24 Nuclear Group is transitional in nature, in that we intend n
| |
| (_) - 25 to operate both of the Beaver Valley units - , Unit 1 and ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 80 4 336-6646
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| 9220 01 01 31
| |
| (~ ';rys~imons 'l Unit 2 -- as though it were a single facility with one v
| |
| 2 staff and one operating, maintenance, engineering, and 3 construction organization.
| |
| 4 The individual on the Beaver Valley Unit 2 project
| |
| .5 team therefore will assume posicions after commercial 6 operation in the Beaver Valley Unit 1 organization.
| |
| 7 (Slide 8 All nuclear activities at Duquesne Light Company 9- report to a single group vice president, Mr. John Carey, 10 who spoke earlier, who in turn reports to the Chairman of 11 the Board and chief executive officer, Mr. Arthur, who is 12 sitting right hear at the head table.
| |
| (3
| |
| (,) 13 l Responsibility for Unit 1 operations, maintenance, 14 engineering-construction, and support activities are 15 assigned to a senior manager which is a sunset position, so 16 to speak. That position would be eliminated upon 17 commercial operation of Unit 2.
| |
| 18 Unit 2 licensing, engineering-construction, pre-19 operational activities, are directly managed by the group 20 vice president.
| |
| 21 One of the interesting features of our 22 organization is that even at the Board of Directors level 23 we have a Nuclear Review Committee whose interest lies in 24 the operation of Unit 1, the construction of Unit 2, and
| |
| () 25 the other nuclear projects which are being operated by ACE-FEDERAL REPORTERS, INC.
| |
| 202-347-3700 Nationwide Coverage 800-336-6646
| |
| | |
| 9220'01 01 32
| |
| (,,)rysimons1 ~ other companies in the CAPCO group as far as their 2 operation and construction progress is concerned.
| |
| 3 Since our nuclear investment is a significant 4 portion of our company's overall capitalization, the Board 5 of Directors keeps a keen eye on the activities that we 6 perform on these sites.
| |
| ?
| |
| 7 MR. REMICK: Would you elaborate on the 8 composition of that Nuclear Review Committee?
| |
| 9 MR. SIEBER: It consists of the Chairman of the 10 Board and three additional directors of the company, one of 11 which is an inside director, the other two are outside 12 directors, and they meet about twice a year with the
| |
| ( 13 officials from the Nuclear Group to go over such things as 14 the operating performance of Beaver Valley Unit 1, 15 particularly in accordance with the performance indicators 16 that were discussed earlier and the construction progress 17 and difficulties in the licensing progress for Beaver 18 Valley Unit 2.
| |
| 19 MR. REMICK: When you say outside directors, you 20 mean from the other companies?
| |
| 21 MR. SIEBER: No, these are directors that are not 22 officers of Duquesne Light Company.
| |
| 23 MR. REMICK: I see.
| |
| 24 (Slide)
| |
| O s_/ 25 MR. SIEBER: Reporting to the senior manager of ACE-FEDERAL REPORTERS, INC.
| |
| ll02-347-3700 Nationwide Coverage 800-336-6646
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| | |
| -9220 01 01 33
| |
| ( jrysimons 1 Beaver Vallay Unit 1 are three units, and these units and 2 these units will also serve Beaver Valley Unit 2 at the 3 operating stage of that unit.
| |
| 4 The first one is the Nuclear Operations Unit which 5 is responsible for operations, maintenance, and testing of 6- the operating units.
| |
| ~
| |
| 7 Secondly, the Nuclear Services Unit which performs 8 technical and administrative functions for the entire 9 Nuclear Group.
| |
| 10 Thirdly, the Nuclear Engineering and Construction 11 Unit.
| |
| 12 Not shown on this slide is the Quality Assurance
| |
| .(b ~13 Unit and it's not shown because it reports directly to the 14 group vice presidents for quality activities.
| |
| 15- I'd like to discuss these three operating units 16 and the Quality Assurance Unit in more detail. The Nuclear
| |
| . l'7 Operations Unit, of course, as we said before,-is 18 responsible for plant operations, plant maintenance, plant 19 testing, chemistry, outage planning, procurement in our 20 . storeroom operation.
| |
| 21 This particular unit is headed by Mr. T. D. Jones 22 who has 25 years of experience in operation of nuclear 23 power plants.
| |
| 24 (Slide) m k 25 Nuclear Operations Unit currently consists of ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-33(H5646
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| 9220 01 01 34
| |
| ('rysimons1
| |
| ; about 470 employees of which 67 have NRC operating 2 licenses, and 183 of these individuals have college 3 degrees.
| |
| 4 MR. REMICK: Are these all active operating 5 licenses?
| |
| 6 MR. SIEBER: Yes, sir.
| |
| 7 MR. REMICK: They are.
| |
| 8 MR. KERR: Is there any significant number of 9 those who have operating licenses who also have degrees?
| |
| 10 MR. SIEBER: I think there are some number. I 11 don't have the exact numbers.
| |
| 12 ' MR. KERR: I mean, is it like two or 20? I'm just
| |
| ,j 3 13 trying to get some feel, not an exact number.
| |
| 14 MR. KURTZ: That will be handled in Mr. Jones' 15 speech which will be coming up.
| |
| 16 (Slide) 17 MR. SIEBER: Next is the Nuclear Engineering and 18 Construction Unit which currently consists of 81 employees, 19 but we have an authorized strength of about 140 employees.
| |
| 20 Within this unit, there are 66 college degrees, and this 21 unit is responsible for plant design modifications, 22 engineering support to operation and maintenance of the 23 plant, and construction activities on site.
| |
| 24 (Slide)
| |
| () 25 The third operating unit is the Nuclear Services ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| 9220 01 01 35
| |
| (])rysimonsl Unit headed by the general manager, and it has five 2 departments reporting to it.
| |
| 3 The Administrative Services Department headed by 4 Mr. Bill Roy. This department is responsible for all the 5 clerical and records support of the site; labor relations,
| |
| -6 and security.
| |
| 7 The Nuclear Safety Department headed by Mr. Ken 8 Grada. Mr. Grada has a senior operator's license. This 9 deparbment is responsible for the licensing activities at 10 Unit 1 and shortly will take over licensing activities for 11 Unit 2; compliance with regulations, independent safety 12 engineering, and fire protection.
| |
| () 13 Third, the Radiological Control Department, headed 14 by Mr. Joseph Kosmal.
| |
| 15 Fourth, the Budget and Fuel Contracts Department 16 headed by Mr. Arthur Dougherty.
| |
| 17 And lastly, the Nuclear Training Department headed 18 .by Mr. Al Morabito.
| |
| 19 (Slide) 20 We passed over very briefly the Radiological 21 Control Department and yesterday on the tour you saw some 22 of the activities that these individuals perform.
| |
| 23 Basically, it's organized into these sections and 24 currently consists of about 70 individuals.
| |
| D)
| |
| (_ 25 The Radiological Operations Sections does the ACE-FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800-336-6646
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| | |
| 9220 01-01 36 (rysimons1 routine day-to-day surveys; discharge permits; issues 2 radiation work permits;.does instrument calibration and 3 supports basically plant operation and maintenance. -
| |
| 4 Second, yesterday you saw our Dosimetry and 5 Bioassay Lab where we do process our own dosimetry and we 6 are accredited by the National Bureau of Standards.
| |
| 7 . Third, we have an Ef fluent Control Department that 8 basically performs the calculations to show compliance with 9 Appendix "I."
| |
| 10 Fourth, the Environmental Monitoring program, and 11 while this program is performed by an independent 12 contractor, this section controls the activities of the 13
| |
| _ ( )- contractor.
| |
| ~ 14 ' Yesterday, there was a question during our 15 discussion which basically related to the Environmental 16 Monitoring program, and the question was, do we see in our 17 program any radiation above background due to the operation 18 of our plant.
| |
| 19 The answer to that is, no, we have not seen 20 radiation in any part of the Environmental Monitoring 21 program that is different from the background.
| |
| 22 We have a Radiological Engineering Section which 23 takes care of such things as ALARA.
| |
| 24 MR. KERR: I should have asked you in addition if
| |
| () 25 you think you could measure within the limits specified in ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 33(Hi646
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| | |
| -9220 01 01 37
| |
| (^i
| |
| \_/rysimons 1 Appendix "I," but I didn't. So, I guess I shouldn't try to 2 pursue that since you really answered the question I asked.
| |
| 3 MR. SIEBER: All right. Thank you.
| |
| 4 (Laughter) 5 MR. SIEBER: The Radiological Engineering Section 6 takes care of such things as the ALARA program and special 7 engineering studies for shielding not only in support of 8 normal operations but shielding for postulated accident 9 conditions and also.the analysis and calibration of 10 instrumentation and things of this nature.
| |
| 11 And lastly, we have assigned, responsibility for 12 industrial safety to the Radiological Control Department n
| |
| () 13 mainly because of the size of this department and the 14 relationship between radiological safety and industrial 15 safety.
| |
| 16 We want organizationally to put a lot of interest 17 in industrial safety and therefore we want to assign it to 18- an area where there is a large number of human resources to 19 carry out this function.
| |
| 20 MR. REMICK: I have two questions on that slide.
| |
| 21 Do you utilize any indicators on industrial safety, and 22 have you established any corporate goals on industrial 23 safety?
| |
| 24 MR. SIEBER: Yes, we do. Actually, in reference
| |
| () 25 to your earlier question on the same subject, we publish ACE-FEDERAL REPORTERS, INC.
| |
| 202-347 3700 Nationwide Coverage 800-336 4646
| |
| | |
| 9220.01 01 38 lirysimons 1 monthly between the Nuclear Operations Unit and Nuclear 2 Services Unit, trends of about 375 indicators. This is 3 probably the largest number of indicators that any plant 4- uses, and they get into quite a lot of detail not only in .
| |
| 5 the major goals which Mr. Carey mentioned but in such other 6 things as condenser air-in leakage, conductivity 7 measurements, and so forth.
| |
| 8 These publications are distributed to our 9 management personnel every month so that each of us has an 10 opportunity to review in great amount of detail the overall 11 , operation of the plant.
| |
| 12 Now, as Zcr as industrial safety is concerned, we
| |
| () 13 believe, of course, that any accident is one accident too 14 many because it involves human beta;s, it affects families 15 of workers and is a discredit to che industry if large 16 numbers of industrial accidents are concerned.
| |
| 17 We have a major goal which we would like to 18 achieve, which is lower, substantially lower than th2 19 industry goals established through INPO and NUMARC, which 20 is one lost-time accident, less than one lost-time accident
| |
| -21 for every 750,000 man-hours work.
| |
| 22 We hope to achieve that and we have come close in 23 a couple of units. But we are in the process of 24 intensifying our industrial safety program so that we
| |
| () 25 actually achieve that goal. It has been achieved in some ACE-FEDERAL REPORTERS, INC.
| |
| E347-3700 Nationwide Coverage 800 336-6646
| |
| | |
| I l
| |
| 9220~01 01 39 I (a~'irysimons 1 portions of the chemical industry and I see no reason why 2 we can't achieve it in the nuclear industry.
| |
| 3 MR. REMICK: One other questions. We cut our 4 visit short at the Training Center. But do the i 5 radiological control people have a training laboratory I 6 where they.can demonstrate proper use of step-off pad, 7 proper use of respirators, the proper tagging, that type of 8 thing? Is that part of your' training for radiation 9 workers?
| |
| 10 MR. SIEBER: Okay, let's address workers first.
| |
| ,. 11 Each radiation worker in the plant has to undergo -- if you 4
| |
| 12 are a regular worker and you have worked there for more 13 than a year, you go through a general employee refresher
| |
| '(]) .
| |
| 14 training which basically consists of about a day's worth of
| |
| , 15 classroom instruction which is a review of the radiation 16 principles, and also a review of industrial safety, 17 security issues and so forth.
| |
| 18 And then each radiation worker must demonstrate 19 his use of respiratory protection equipment; donning and 20 removing anti-contamination clothing; the use of step-off 21 pads; frisking techniques and so forth.
| |
| j 22 So that is performed by every radiation worker
| |
| ; 23 every year. For a new employee, that program is expanded 24 to a two and-a-half day program.
| |
| j '( ) 25 Now, for radiation technicians whose prime 6-ACE-FEDERAL REPORTERS, INC.
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| ll02-347-3700 Nationwide Coverage 800 336 4646
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| | |
| 9220.01 01 40
| |
| -()]rysimons'l responsibility is the protection of the work force, the 2 training program to which they are subjected takes 3 approximately one year of classroom and on-the-job 4 training. We have a very extensive program which is now in 5 for INPO accreditation for the training of radiation 6' technicians.
| |
| 7 MR. REMICK: But do you have space in the training 8' center where these things can be demonstrated, or is it 9 done in.a locker room?
| |
| 10 MR. .SIEBER: No. In the training building -- the 11 building to the right of the simulator building where we 12 were last night, there is a special classroom set-up and it-
| |
| ) 13 is just a classroom. But it has all the step-off pads, 14 garments, respirators. It is' taped off and marked off the 15- same as you wccid find a contaminated area in the plant.
| |
| 16 MR. REMICK: Thank you.
| |
| 17 (Slide) 18 MR. SIEBER: Next, I'd like to address the Nuclear 19 Safety Department. It performs the functions of the 20 interface between Duquesne Light Company and the Nuclear 21 Regulatory Commission'for formal document transmittals such 22 as applications for change of the tech specs and responses 23 to bulletins and so forth.
| |
| 24 Secondly, it will contain an independent Safety
| |
| '( 25- Engineering Group which is specified in NUREG-0741. It ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336 6 46
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| .9220 01 01 41
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| -(~'irysimons 1 performs the function of an off-site review committee which V
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| 2 is the Management Safety Review Committee organization.
| |
| 3 Our Safety Review Committee is composed of ,
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| 4 management personnel to cover all the disciplines of the 5 plant that are necessary for operation, and the work of 6 that committee is coordinated through the Nuclear Safety 7 Department by providing them with documentation, doing 1
| |
| 8 research and so forth, to address the questions that are 9 brought up there.
| |
| 10 And lastly, the Fire Protection Program is placed 1
| |
| 11 in the Nuclear Safety Department, and it was placed there 12 basically because Appendix "R" elevated the fire protection
| |
| () 13 issues to those of a relatively technical and complex 14 nature.
| |
| 15 MR. REMICK: Do any of these safety review groups -
| |
| 16 - or what you called them by various names -- have any 17 truly external members that are, you know, completely 18 independent of the operations group or the corporate 19 groups?
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| 20 MR. SIEBER: Well, the Off-Site Review Committee 21 has three members that are not within the Duquesne Light 22 Company organization. One of them is the Westinghouse site 23 project manager. He represents Westinghouse and can draw 24 upon the resources of the Westinghouse Electric Corporation
| |
| () 25 for questions involving equipment that we bought from ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| 9220 01.01 42
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| ()rysimons1 Westinghouse, or an analysis that they performed in support 2 of our plant.
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| 3- We have a second person from the NUS Corporation 4 who is an expert in chemistry and radio-chemistry, and we 5 have a third indiv!. dual who is from the MAC Corporation who 6 is an expert in plant operations.
| |
| 7 MR. REMICK: Thank you.
| |
| 8 (Slide) 9 MR. SIEBER: Next, I'd like to talk a little bit 10 about the Nuclear Training Department. As far as 11 organization is concerned, it's composed of basically five 12 sections: The Operations Training Program; secondly,
| |
| ..(_j n 13 Technical and Craft Training Program; Third, the Program l
| |
| 14 l Development Section which is really an out-growth of the 15 INPO accreditation program.
| |
| 16 These people assure that all the learning 17 objectives are completely specified and the lesson plans 18 and so forth reflect the learning objectives. They prepare 19 accreditation documents and they also prepare the training 20 aids necessary for the conduct of courses.
| |
| 21 We also include our Emergency Planning Section in 22 the Training Department. And the reason for that is that 23 we find emergency planning basically involves a large 24 amount of training.
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| () 25 We train in addition to a couple of hundred people ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800 336-6646
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| '9220 01-01 43 within the Duquesne Light organization for on-site
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| {;rysimons1 2 activities, we are also training fire departments, polico 3 departments, elected of ficials, hospitals, nursing homes, 4 ambulance services. That leads to about 3,000 trained 5 individuals that are basically local government and local 6 agencies surrounding our plant.
| |
| 7 And lastly, last night you saw our plant reference 8 ' simulator. There is a separate section that operates that 9 simulator.
| |
| 10 (Slide) 1 11 The Nuclear Services Unit consists of 12 approximately 483 individuals with 138 college degre,es and
| |
| ()' 13 six current NRC operating licenses 14 j (Slide) i 15 Last, I'd like to discuss briefly the Quality 16 Assurance Unit. Now, this unit does not report to the 17 operating organization but reports directly to the group 18 vice president.
| |
| 19 It consists of four major sections, the QA 20 Operations Group which has the the quality assurance 21 auditing function for operations; QA Engineering and 22 Procurement; the In-Service Inspection Section, and the 23 Operations Quality Control Department.
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| 24 (Slide)
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| () 25 Quality Assurance Unit has 61 permanent employees, ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| -9220 01 01 44
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| (~lrysimons 1 with 100 authorized. There is a mistake on this slide, V
| |
| 2 they have about 350 contract personnel, basically quality 3 control inspectors. with 58 college degrees and two senior 4 reactor operator licenses.
| |
| 5 MR. REMICK: Are those active SRO licenses?
| |
| 6- MR. SIEBER: Yes, sir.
| |
| 7 MR. REMICK: Now, this is for Units 1 and 2, I 8 assume, the slide?
| |
| 9 MR. SIEBER: The Quality Assurance Unit is for 10 Units 1 and 2.
| |
| 11 MR. REMICK: One and two. Do you use your RSOs 12 for control room operations QA? What is the purpose of I'')
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| Iy/
| |
| 13 having SROs in the QA?
| |
| 14 MR. SIEBER: Basically, the Quality Assurance 15 Program should cover all aspects of plant operation. These 16 individuals were recently assigned. Their purpose is to be 17 able_to audit and surveil, and understand plant operations.
| |
| 18 MR. REMICK: Good. How do you assure that your 19 employees in operations or construction, or engineering, 20 since that quality is part of their job than it's not a 21 separate organization that reports up somewhere, that 22 quality is their responsibility and quality assurance is 23 their responsibility? That's not mine. Mine is to operate 24 the plant. Mine is to design, mine is to construct.
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| 25 How do you get around that?
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| .( )
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| ACE-FEDERAL REPORTERS, INC.
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| 3)2 347-3700 Nationwide Coverage 800-33M646
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| | |
| 9220 01 01 45 llharysimons1 MR. SIEBER: Well, I think that we perform that 2 function in a number of different ways. You know, tha t 's 3 really a matter of communications. One way that we can 4 touch every employee is to have as part of our general 5 employee refresher training every year, part of that 6 training is what the quality assurance program is; how it's 7 conducted; what it means, and why we have it. That is one 8 way that we do it.
| |
| 9 We are also beginning publication of a plant 10 newspaper -- of which there is a copy here -- we intend to 11 cover quality assurance activities in each issue of one 12 -
| |
| sort of another. For example, this issue has one that Ii sJ 13 describes the quality concern " Hotline" where employees can i
| |
| .14I call a telephone number and if they feel that there is a 15 quality defect that's not being properly addressed or needs 16 to be identified, they have a direct line into the Quality 17 Assurance Department where they can have that quality 18 concern investigated.
| |
| 19 I think there are other ways that one does it, and 20 that's basically through the management philosophy. The 21 people that work at Beaver Valley know what our philosophy 22 is -- safety of the public, safety of our workers, quality 23 work. Various things that we will post on the bulletin 24 boards -- investigation of incidents and so forth -- will g~
| |
| (_) 25 stress that the quality aspects of operating these plants ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 33(H5646
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| 9220 01 01 46 I
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| 3rysimons 1 is an important function.
| |
| 2 There are other types of communications that we 3 use with employees, where these matters are discussed. I 4 hold a monthly meeting with a random sample of employees 5 that cover basically all the way from laborers on up to mid-6 level personnel, just to be able to discuss things like 7 quality assurance, what our goals are, what we are trying 8 to achieve, and then to use the network that the work force
| |
| -9 has to try to spread the story.
| |
| 10 So, we have attacked this in a number of different 11 ways and I think given it a pretty broad focus , so that 12 quality does become an important function of each and every F')
| |
| k' 13 - j ob tha t's performed .
| |
| 14 MR. KERR: You apparently give the Quality 15 Assurance organization some prominence in your nuclear 16 organization. Do you have one for your fossil unit or for 17 your fossil operation?
| |
| 18 MR. SIEBER: Not directly as such. I think that 19 there is quality in the operations of fossil plants because 20 I have worked in them. But you rely more on the first-line 21 and second-line supervision to perform that quality 22 function.
| |
| 23 We do not have a formal program in the coal-fired 24 station.
| |
| r~
| |
| ( 'xl 25 MR. KERR: Suppose the NRC didn' t require such a ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336 6646
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| 9220 01 01 47
| |
| (,hrysimons1 OA ' organization, would you have one in your nuclear i
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| 2 operation anyway?
| |
| 3 MR. SI"BER: I think that the Quality Assurance 4 Unit and all the things that they perform serve a very 5 useful and helpful function.
| |
| 6 I chink that you can treat quality assurance as 7 performing the requirements of Appendix B, and I think 8 that's a mistake. I rely, for example, on the Quality 9 Assurance Unit to perform special audits for me which I 10 request in addition to their normal auditing program. They 11 can become the eyes and ears of the kind of quality that is 12 in the product that we provide, which is operation,
| |
| \ 13 maintenance, and so forth.
| |
| 14 These contributions, I think, f ully justify that 15 department, aside from the regulations.
| |
| 16 MR. KERR: I'm surprised that you have not sold 17 your colleagues in the fossil units on the value of such an
| |
| ! 18 operation, then.
| |
| l l
| |
| 19 MR. SIEBER: Yes , sir .
| |
| 20 (Slide) 21 Overall, the Nuclear Group consists of 22 approximately 1,050 Duquesne Light employees at this time, 23 of whom 76 are currently active PWR licensed -- either 24 senior license or operating license.
| |
| g-(- 25 Our plant staff level for operation of both units
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| . ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 336 6646 s .
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| 9220 01'01-48
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| .k 2rysimons 1 -at Beaver Valley is approximately 1,100 individuals, 2 excluding the security force. And we will have a goal of 3 about 105 licensed individuals for the operation of both 4 units.- .
| |
| 5* Our corporate policy embraces promotion from 6 'within whenever practical. And this policy provides 7 continuity to the operational policy and enhances 8 operational experience.
| |
| 1 9 The effectiveness of this type of operation or 10 organization is illustrated by marked improvements in the 11 NRC SALP ratings for Unit 1 following the initial i
| |
| 12 implementation of these organizational plans in 1981.
| |
| -() 13 1
| |
| Thank you very much.
| |
| 14 MR. WYLIE: Any further questions?
| |
| 15 MR. KERR: Who is t,here in your organization, if 16 anyone -- two or three, or so -- who are familiar with PRA 17 techniques, probabilistic risk assessment who, for example, 18 are f amiliar with WASH-1400 or succeeding studies of this
| |
| '19 kind?
| |
| 20 MR. SIEBER: I have provided training and we have
| |
| '21 do.ne some very small PRA-type calculations through the Of f-22 Site Review Committee coordinator, particularly to analyze 23 either specific configurations or specific events that 24 occurred in our plant, so that we can have an understanding i o 25 of that event with respect to WASH-1400 and some of the 1,
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 800 336-6646
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| , , _ _ . _ . . . - _~ _ _ _ _ . _ _. _ _ _ _ . _ , . . - . _ . _ _, _ . . _ , _ . . _
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| r 9220 01-01 49
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| . ,y
| |
| (__brysimons 1 later studies that have been done.
| |
| 2 So we do have one individual that follows that 3 technique and keeps up to speed on it. I think that 4 another' example of the user PRA at Beaver Valley was the 5 analysis of control room habitability where we used PRA 6 techniques to analyze all the shipping that's conducted by
| |
| -7 Conrail and the barge shippers, and truck traffic in our 8 area to determine the probability that a hazardous 9 substance would, affect the habitability of the control 10 room.
| |
| 11 That became an involved study that was cuite 12 effective in identifying the risks posed by that type of a r
| |
| L 13 risk off-site.
| |
| 14 MR. KERR: Do you have any plans to carry out 15 either a full scope or limited PRA for your two plants?
| |
| 16 MR. SIEBER: Not at this uime we do not.
| |
| 17 MR. CAREY: Dr. Kerr, I'would like to mention that 18 WASH-1400 was the PRA that was the basis for the study with 19 the Surry plant which is a sister of Beaver Valley No. 1 20 unit.
| |
| 21 So we feel chat almost all of the results of that 22 section of WASH-1400 are directly applicable to No. 1 23 unit. But at this time we are not planning to perform a 24 full PRA for Beaver Valley No. 2. Should we do so, since
| |
| > 25 they are very similar plants, we still believe that WASH-ACE FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverase 800 336-6646
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| 9220 01 01 50 llharyeimons1 1400 would apply very directly to both units.
| |
| 2 MR. KERR: Well, I agree with you almost whole-3 heartedly. I would be more whole-hearted if you had 4 someone, or some group, that was responsible for being 5 rather familiar with the results and the techniques.
| |
| 6 As you know, a certain amount of progress and 7 change in approach has been developed since WASH-1400. So 8 that some of the results that would apply to Surry or would 9 have applied at the time, I think, now have been revised.
| |
| 10 Also, I think it has been generally the case if 11 people'who did do rather detailed PRAs in some cases found 12 some things that they wanted to fix without even any
| |
| (~'T .
| |
| \_/ 13 encouragement from the NRC.
| |
| 14 What I would hope is that one would be using these 15 approaches to try to anticipate problems. It's a good idea 16 to analyze a problem after it has occurred and see maybe 17 why it did occur -- and I'm not just talking about safety.
| |
| 18 I'm convinced that you probably are likely to keep 19 your plant on line a bigger fraction of the time if you 20 look carefully at the whole system for weak spots.
| |
| 21 That doesn't necessarily mean to me that you try 22 to put numbers on everything. Also, it seems to me in your 23 emergency training, in order to talk about emergencies 24 which at least go beyond the design basis accident -- and 25 it seems to me that one ought to go beyond the design basis ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 800-33H646
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| l
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| -9220 01 01 51
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| ()2rysimons1 accidents to some extent -- that you need some f amiliarity
| |
| ;y 2 in your organization 'with that approach in order to 3 understand what's important for your, plant..
| |
| 4 Generic approaches are very good, provided your 5 plant is a generic plant. But even one and two you have -
| |
| 6 dold me, and I believe you, dif fer somewhat.
| |
| 7 Well, that's enough of a sermon. But I would
| |
| '8 think from an economic point of view, forgetting safety, 9 you would want some one or two people who would be fairly 10 familiar with this sort of thing.
| |
| 11 ,
| |
| MR. KURTZ: Mr. Kerr, we do have two people on the 12 Unit 2 project who have been trained in ?RA techniques.
| |
| 13 They were involved specifically in the Class 9 accident 14 analysis that' was done in the environmental report.
| |
| 15 MR. CAREY: I think what's happened is, after Sol 16 Levine passed away, that we sort?of fell off the track.
| |
| 17 But Sol, he and I have discussed this application of PRA 18 techniques on many occasions.
| |
| 19 MR. WYLIE: Any other questions?
| |
| 20 MR. KERR: In connection with your staffing of 21 Units 1 and 2, my impression is that you are going to use a 22 maintenance group that will operate on both units.
| |
| 23 MR. SIEBER: That's correct.
| |
| 24 MR. KERR: Other organizations, perhaps with less 25 experience 'than yours , have on occasion had a situation 4
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-33(HS&6
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| 9?20 01J01 52
| |
| !x C;rysimons-'l occur in which a maintenance person was told to go into
| |
| :2 Unit ' 2 .and work ' on Valve No. 2185, and instead he went.in 3 Unit 1 and worked on Valve No. 2185.
| |
| 4 Have you given some thought to how you can make 5 -that less likely to-occur than might be the case in less 6 experienced organizations than yours?
| |
| 7 MR. SIEBER: I don' t think experience would 8 ' prevent that kind of incident. You know, those kinds of 9 mistakes do occur. I think there are some advantages, 10 however, to the way the plant is laid out. I 11 As you noted on the tour last night, the plants
| |
| :12 are laid out basically as separate plants, there is a I
| |
| 13 roadway between.them.
| |
| 14 The instances that I'm aware of, or some of the
| |
| > 15 instances, where the kind of incident that you described 16 took place were plants where, for example, you had a 17 turbine hall with one turbine after another and the lines l l-- 18 of' demarcation from Unit 1 to Unit 2 were not as clear as l'
| |
| I 19 they are at Beaver Valley.
| |
| L f 20 It would have to be a gross mistake to go to the L
| |
| 21 wrong plant since they are two separate structures. I 22 think in addition to that, there are differences in the 23 ~ initial marking of the numbers for the equipment. You can 24 tell what unit you are on by the mark number.
| |
| 25 We intend to use things such as color-coded ACE-FEDERAL REPORTERS, INC.
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| 202-347-370G Nationwide Coverage 800 336-6646
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| | |
| 9220 01 01 53 3rysimons 1 procedures, you know, the procedures for one plant will be 2 printed on a different color paper than for the other in an 3 effort to minimize the use of a wrong procedure in the 4 opposite unit.
| |
| 5 So we have considered this and we believe that the 6 potential is there for these kinds of mistakes if we don't 7 adopt some of these administrative controls to prevent them 8 from occurring.
| |
| 9 MR. KERR: One other cuestion, and it isn't, 10 maybe, directly related to your presentation. But one of 11 the differences pointed out between 1 and 2 is the full 12 flow demineralizer that you have in Unit 2, I believe.
| |
| (q
| |
| _ ,/ 13 MR. SIEBER: That is correct. Ir Unit 1, we took 14 a different tack. We installed additional blow-down 15 capacity to achieve the same goal. But demineralizers are 16 certainly more efficient from the conservation of heat 17 standpoint.
| |
| 18 MR. KERR: Well, you have, answered my question.
| |
| 19 It seems to me this accomplished purpose is important both 20 f rom a safety and an economic point of view.
| |
| 21 MR, SIEBER: Correct.
| |
| 22 MR. KERR: And you are telling me, then, that you 23 have accomplished the same purpose in one but have used a 24 different approach. )
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| 1
| |
| /~,
| |
| k) 25 MR. SIEBER: Tha t's correct .
| |
| 1 ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 336-6646
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| < l
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| -9220 01 01 54
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| /
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| . ;(
| |
| '__crysimons 1 MR. .KERR: Thank you. ,
| |
| 2 MR. KURTZ: Okay, the next speaker will be Mr.
| |
| 3 Jones.
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| 4 5
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| 6 3
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| 7 7 8
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| 9 10 11 12
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| ~ rs U 13 14 15 16 17
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| '18 ,
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| 19 20 21 ,
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| 22 23 24 O 25 ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide coverage 800 336-6646
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| . . . . _ _ , , . _ _ . _ _ _ . _ _ _ . _ _ . ~ . __ . _ . __ . _ , _ .__ -..
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| 9220 02 02 55
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| <x
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| (
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| v rysimons 1 MR. J0NES: Good morning.
| |
| 2 My name is Tim Jones. I am the General Manager of 3 . the Nuclear Operations Unit.
| |
| 4 1 will discuss the nuclear operations 5 organization, the responsibility of the different sections 6 and the experience of the people in these sections.
| |
| 7 (Slide.)
| |
| 8 As previously explained by Mr. Sieber, the Nuclear 9 Operations Unit is assigned, three general functions, 10 production, technical services and, third, planning and-11 outage management.
| |
| 12 (Slide.)
| |
| (Q_/ 13 The production responsibility is assigned to the 14 plant manager, who is responsible for operations, 15 maintenance, instrumentation and control and testing.
| |
| 16 The first of these functions is operations. The 17 Director of Site Operations is the Senior Operations 18 Manager. His organization consists of a shift complement 19 as well as day-shift support personnel.
| |
| 20 The support personnel are responsible for the 21 preparation of shift schedules, review of shift activities, 22 the follow-up of incident investigation, coordination with 23 other functional groups and for representing operations on 24 the on-site safety committee.
| |
| (, 25 The shift complement consists of licensed ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 8(vk336-6646
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| -9220 02 02 56
| |
| .(O^3rysimons_1 supervisors as well as operators and auxiliary or nuclear 2 operators. Each of.the five operating shifts is headed by 3 a nuclear-head supervisor who is responsible to.the 4 Director of Site Operations for-the operation of the 5 station and is a senior company representative in the U
| |
| 6 absence of-the Plant Manager and the Director of Site 7 Operations.
| |
| 8' Each shift supervisor will have two nuclear 9 station operating foremen, four nuclear control operators, 10 seven auxiliary operators and an administrative assistant 11 assigned as a shif t complement.
| |
| 12 It is expected.that the shift supervisor will be
| |
| () 13 licensed on both units with the auxiliary operators 14 maintaining qualification for watch stations at both units 15 through a rotating schedule.
| |
| 16 (Slide.) I
| |
| ~
| |
| l 17 In concluding my discussion of operations, let me 18 emphasize the experience in this group. Presently there 1
| |
| , 19 are 39 licensed operators at Beaver Valley, with a total of 20 268 years of nuclear experience, including 75 years 21 experience in control room operations.
| |
| 22 Twelve of these operators have completed, or are
| |
| ~23 presently undergoing training on Unit 2 components and 24 systems, with an additional eight operators scheduled to
| |
| .( ) 25 start training in April of next year.
| |
| ACE-FEDERAL RrPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 2 336-6646
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| | |
| 9220 02 02 57 (prysimons1 'There'are 11 supervisors who have been assigned at 2 this time to Unit 2. The total nuclear experience of this 3 group is 114 years with 44 years experience in control room 4 operations. Eight of these supervisors have more than one 5 year of hot operating experience at Beaver Valley.
| |
| 6 MR. KERR: Mr. Jones, you have mentioned safety 7 and some of the earlier people also mentioned safety. And 8 in especially organization I could have gotten the 9 impression, and I hope it wasn't the right one, that the 10 organization maybe feels that if it complies with all the 11 NRC regulations, then safety will have been take care ot.
| |
| 12 What is your approach towards safety? Is it just
| |
| () 13 a matter of satisfying all the regulations or ---
| |
| 14 MR. JONES: No, sir. It is the confidence that we 15 have that we can operate and maintain the plant safely.
| |
| 16 MR. KERR: I would hope that is true. I also 17 would comment parenthetically, and it has nothing to do 18 with that, I think it was Andrew Jackson who said it was an 19 uneducated individual who could only spell a word one way, 20 and I want to compliment on your spelling of complement.
| |
| 21 (Laughter.)
| |
| 22 MR. JONES: Noted.
| |
| 23 MR. SIEBER: Perhaps I could address your question 24 a little bit. I think that that was one of the lessons l
| |
| () 25 learned from TMI, was that if you just obey the regulations l
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| i ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 80 4 336-6646
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| 1 9220 02 02. 58 L({]'rysimons~1 that you.really haven't covered the ground. That is why 2 'INPO came about because~we are trying to achieve through 3- our active participation in INPO and in our own work a 4 level of safety that exceeds the regulations.
| |
| 5 If you just meet regulations and show up with the 6 right papers at the right time, I think you have missed the 7 boat. You have to really strive for a degree of excellence 8 in both operations and maintenance that goes well beyond 9 the regulations in order to get the true kind of safety.
| |
| 10 that is really required to keep this industry on the right 11 track.
| |
| 12 MR. KERR: Well, I certainly agree that that n(,) _ 13 should have been learned from TMI-2. I think what some 14 . people learned from TMI-2 was that once should avoid at all 15 costs another TMI-2. Of course, the thing that will bite
| |
| . 16 is something other than TMI-2 if we have another serious 17 accident.
| |
| 18 MR. EBERSOLE: Let me ask a question, Mr. Sieber.
| |
| 19 Do you think that the current requirements for Appendix R 20 are excessive?
| |
| 21 MR. SIEBER: I think they have resulted in a lot 22 of work, but I do not think they are excessive.
| |
| 23 MR. EBERSOLE: The reason I mention is of course I 24 ran into that intermediate switchboard that you had down
| |
| () 25 there,.which came about as an expression of your agreement ACE. FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| '9220 02 02 59
| |
| ) )rysimons 1 to~putsin provisions to shut down from'a point outside the [
| |
| '2 control room, and yet that did not provide for any damage 3 therein at all.
| |
| r 4 I really regard that board as a superfluous part "
| |
| 5 'of your plant and it probably should be cut out. It is an f
| |
| 6 unnecessary dragon in your plant that probably is going to 7; cause you more trouble than it is ever worth. But it does 8 reflect the fact that you rather passively accepted the i
| |
| 9 staff's pressure to put it in, which I think is t 10 unfortunate, when you could have put in the simpler one 11 which is now partially in place, but not yet finished, f
| |
| ~12 which in fact does execute a safety function of much more
| |
| () 13~ substantial character.
| |
| 14 MR. SIEBER: That is correct.
| |
| 15 MR. REMICK: Mr. Jones, before you leave that 16 slide, I have a couple of questions.
| |
| 17 Could'you tell me if any of your shift supervisors 18' or perhaps your foremen are degreed?
| |
| 19 MR. JONES: Yes, they are.
| |
| 20 MR. REMICK: How many?
| |
| 21 MR. JONES: There are -- I didn't break it down 22 that way from your earlier question -- there are 15 people 23 that are licensed in the Nuclear Operations Unit that have i
| |
| 24 degrees. Six of those people are in management positions. l I) -25 A number of those people are on shift as either operating 1
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 . Nationwide Coverage 800-336 6646 J
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| 9220 02 02 60
| |
| ~7rysimons 1 foremen or shift supervisors that have either chemistry or 2 engineering degrees.
| |
| 3 MR. REMICK: Do you license your STA's?
| |
| 4 MR. JONES: No, we do not.
| |
| 5 MR. REMICK: Have you give any thought to whether 6 you would combine the STA as the second SRO on shift, or 7 will you maintain STA's as a separate position?
| |
| 8 MR. JONES: We have, and at this time we are 9 maintaining the STA's as a separate position.
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| 10 MR. REMICK: Are those people, the STA's assigned 11 a shift or are they at the plant on ---
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| 12 MR. JONES: They are assigned a shift. Their desk
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| ') 13 is within the control room.
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| 14 MR. REMICK: I see. And they rotate with the 15 shift in a 24-hour ---
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| 16 MR. JONES: Yes, they do, right.
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| 17 MR. REMICK: How about your nuclear operators, do 18 you license them? Is the goal to get all of those people 19 licensed? You have permanent I guess auxiliary operators, 20 you call them nuclear operators, people who are 21 professionally long-term nuclear operators, and is your 22 goal to get all of those people licensed?
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| 23 MR. JONES: Some of them are auxiliary operators 24 and have been for some period of time with no interest in n
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| () 25 progressing into the licansed position. Some of them have ACE-FEDERAL REPORTERS, INC.
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| i_jrysimons 1 in the past gone up into the nuclear control operator 2 position and have licensed successfully. So we have a 3 mixturo I would say within that group.
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| 4 MR. REMICK: ,But you will accept people who cannot 5 be licensed or have no interest in being licensed in those 6 positions. The reason I mention that is at some plants if 7 a person can't become licensed, they don't want them as an 8 auxiliary operator either and they move them out into some 9 other part of the plant. But you will accept people long 10 term in that position with the goal of not being licensed?
| |
| 11 MR. JONES: We have'same that are in that position 12 right now. In the future our program calls for people
| |
| ( 13 actually passing through the screening examination that is 14 used for the nuclear control operators. So they will have 15 that capability to become nuclear control operators in the 16 future.
| |
| 17 MR. REMICK: Since you mentioned screening, one of 18 our colleagues who is not here would sure be interested, I 19 am sure, of what kind of screening test do you use. Do you 20 use POSS or anything equivalent to POSS?
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| 21 MR. JONES: We have for some time used a screening 12 2 examination that was developed for us by Penn State 23 University.
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| 24 MR. REMICK: It must be okay then.
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| O
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| (/ 25 (Laughter.)
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| 9220'02 02 62
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| (~'7rysimons 1 MR. REMICK: Does it have any components which A_/
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| 2 test mechanical aptitude, for example?
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| 3 MR. JONES: The mechanical aptitude test is a test 4 that is administered by our Personnel Department for all 5 Duquesne Light employees. That is not part of the Penn 6 State test.
| |
| 7 MR. REMICK: Incidentally, that question I asked, 8 it was not loaded. I forgot about the fact that you used 9 that screening.
| |
| 10 (Laughter.)
| |
| 11 MR. KERR: Do you have round holes and square pegs 12 that you use for this mechanical aptitude or ---
| |
| i 13 (Laughter.)
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| 14 MR. JONES: I don't know.
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| 15 (Laughter.)
| |
| 16 MR. WYLIE: Let me ask a question about your 17 philosophy regarding the STA's. What type of individual 18 are you selecting for that position?
| |
| 19 MR. JONES: The STA's are graduate engineers.
| |
| 20 They go through a training program that is based on the 21 INPO requirements. Some of those people, or several of 22 those people are presently going through the licensing 23 program to become licensed on Unit 1.
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| 24 MR. WYLIE: Is that intent, to have licensed
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| () 25 operators for STA's?
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| i 4
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| l9220 02 02- 63 (d"%rysimons 1 MR. JONES: No, they are out of the STA program, 2 so to speak. They are moving up into the control room 3 supervisory function.
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| 4 MR. KERR: What function does an STA perform, 5 _since you haven't had any serious accidents in which they
| |
| .6 can function? What do they do in the normal course of 7 events?
| |
| 8 MR. JONES: The STA is involved in reviewing all 9 plans to take engineered safeguards equipment out of 10 service. He is also involved in control board walkdowns 11 and the observations of control room activities at 12 different times on the shift. In addition to performing
| |
| (~) 13 his normal functions during a transient or a trip, he gets s-14 involved in following a procedure and assessing the plant 15 conditions.
| |
| 16 MR. KERR: Thank you.
| |
| 17 MR. WYLIE: Well, let me follow-up that a little 18 bit. What role will the STA play and what responsibility 19 will he have in a plant transient such as, and in your case 20 it would be very difficult, but loss of all feedwater, for 21 example?
| |
| 22 MR. JONES: The STA basically is responsible for 23 looking at various plant parameters and for making his 24 observations known to the shift supervisor.
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| 25 So he is just basically an advisor to
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| (]) MR. WYLIE:
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| ' 9220 02.02. 64 i
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| ()rysimonsil. .the' shift supervisor on request?
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| 2 MR. JONES: 'Not on request. He makes it known.
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| 3 He doesn't wait-to be asked.
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| 4 MR.' KERR:: . But fut is looked upon by.the shift 5- supervisor as sort of a junior level advisor I would assume 6 since, from what.you said, the progression is upward from 7 STA toward the ---
| |
| 8 MR. JONES: His function is well known by the 9 control room supervisors, and while his career progression 10 may be'up into an operating position in the control room, I 11 don't believe that his shift technica11 advisor function is 12 viewed as a. junior function.
| |
| I) 13' MR. KERR: Well,.if you were an SRO and a shift 14 technical adviser told you to do something that was against 15 .your better judgment ---
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| 16 MR. JONES: The shift supervisor is responsible 17 .for the operation of the station.
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| 18 MR. KERR Thank you.
| |
| 19 (Slide.)
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| 20 MR. JONES: I would like to show you the 21 maintenance organization. The maintenance organization is 22 the second block from the left of this chart.
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| 23 The Director of Site Maintenance has a mechanical 24 and an electrical senior supervisor responsible for
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| () 25 directing the daily activities in these areas. The foremen ACE-FEDERAL REPORTERS, INC.
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| report directly to the senior supervisor and several l 2 maintenance engineers are available in a staff position'to i 3 provide technical assistance to the foremen and to perform 4 other. technical assignments as directed by the senior 5 supervisor.
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| 6 Craf tsmen will be assigned to each unit from a 7 common pool as the workload dictates. They are members of 8 the IBEW and obtain a position through a job bidding 9 procedure and a qualification test. Classroom as well as 10 on-the-job training is provided for mechanics, 11 electricians, I&C technicians, welders and machinists.
| |
| 12 A maintenance support function is provided and
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| () 13 responsible for such non-production activities as I 14 procedures review, plant modification review and new 15 program preparation.
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| j 16 (Slide.)
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| 17 Again, as in operations, a considerable amount of 18 nuclear plant experience exists within the electrical and i
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| 19 mechanical maintenance sections.
| |
| 20 There are 18 electrical and 46 mechanical 21 maintenance personnel presently on site who have 428 years 22 of experience. The 35 supervisors and engineers, 13 of 23 which are at Unit 2, have 233 years of nuclear experience.
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| 24 (Slide.)
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| () 25 The third function reporting to the Plant Manager ACE-FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 336-6646
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| 9220'02 02 66
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| [)rysimons1 is instrumentation and control. The I&C organization is 2 similar to the maintenance organization, except that it has 3 a computer group which is responsible for the .various 4 computers used by the operating organization.
| |
| 5 (Slide.)
| |
| 6 Again from the experience standpoint, 47 I&C 7 technicians have 272 years of nuclear experience with 174 8 years within the group of 26 supervisors and engineers, ,
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| 9 eight of which are at Unit 2.
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| 10 The last function reporting to the Plant Manager 11 is training and plant performance.
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| 12 Reporting to the Director are three senior
| |
| () 13 supervisors who are responsible for testing, monitoring and 14 evaluation of the reactor core and various plant systems 15 and components to demonstrate that required safety margins 16 are maintained.
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| 17 And as a continuing effort, the overall 18 reliability and efficiency of the station is maximized.
| |
| 19 176 years of nuclear experience exists within this group of 20 30 engineers and supervisors, eight of which are assigned 21 to Unit 2.
| |
| 22 That completes the discussion of the Plant 23 Manager's organization.
| |
| 24 (Slide.)
| |
| () 25 The next organization within the Nuclear ACE-FEDERAL REPORTERS, INC.
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| .9220 02 02 67
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| ()rysimons1 Operations Unit is Technical Services. This department is 2 headed by a manager responsible for five functions.
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| 3 The first function, plant safety review, is 4 performed by the on-site safety. committee. The chairman of 5 this committee is a permanent position with the remaining 6 members appointed on a rotating basis. The members 7 represent operations, maintenance, instrumentation and 8 control, testing, radiological controls, quality control 9 and engineering.
| |
| ; 10 Chemistry is the second function within the ,
| |
| 11 Technical Services Department.
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| 12 The chenistry section performs sampling and O) q, 13 analysis of the plant's primary, secondary, and auxiliary 14 systems. They also perform monitoring to ascurance 15 compliance with the NPDES permit, administer the station's 16 hazardous waste program and maintain drinking water 17 supplies with the EPA established limits.
| |
| 18 Chemistry personnel are available 24 hours a day 19 on a rotating shift to maintain proper chemical conditions 20 and to provide support to operations.
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| 21 MR. KERR: You said something about drinking water 22 supplies. Do you mean drinking water supplies for people 23 in the plant or people in the neighborhood?
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| 24 MR. JONES: People in the plant.
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| () 25 The material management is the third function ACE. FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 336-6646
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| -9220 02 02 68 frysimons1 reporting to the Manager of Technical Services.
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| 2 The material management section includes both the
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| . 3 requisitioning of non-stock and replacement parts as well 4 as the order, receipt, storage and issue of the Beaver 5 valley stock inventory currently valued at about $11 6 million.
| |
| 7 The director of this section also serves on a 8 corporate material management task force and is a company 9 representative to the pooled inventory management program.
| |
| 10 MR. KERR: In this technical services area, what.
| |
| 11 is it that you do a lot better than other people who 12 operate plants?
| |
| () 13 MR. JONES: We do things I think differently than 14 a lot of people that operate plants in that we take these 15 functions away from the responsibility of the plant manager 16 and let him concentrate on the production activities. This 17 allows us to devote more attention through the technical 18 services organization to each of these particular functions 19 and as a result ends up in a better overall product. I 20 think that covers all areas of technical services and not 21 just one of them.
| |
| 22 MR. KERR And how did you decide to do it that 23 way?
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| 24 MR. JONES: The organization you see today is
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| () 25 basically the organization that was approved in 1981 with ACE-FEDERAL REPORTERS, INC.
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| ?O2 347-3700 Nationwide Coverase 800 336 66 4
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| a 9220:02 02 69 n- (_jrysimons 1 some changes that happened as a result of the recent 2 corporate reorganization.
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| 3 Prior to 1981 the station superintendent or the 4 _ plant manager was responsible for all functions on site.
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| 5 It was decided in 1981 that we needed more attention to 6 detail and as a result we cut down the span of control and 7- were able to concentrate more on the details of these 8 different areas. You see the result of this in the 9 organization that you see today, and I think the everall 10- performance of. Beaver Valley indicates that this has been
| |
| 'll successful.
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| 12 MR. KERR: Thank you.
| |
| () 13 MR. WYLIE: Let me ask a question. Who reviews 14 plant modifications and. changes from the impact as far as 15 safety is concerned?
| |
| 16 MR. JONES: The plant modifications are reviewed 17 by the onsite. safety committee, and they are looking at the 18 overall question of safety. 'They are reviewed by 19 operations and maintenance people also for maintenance and 20 operability, and a part of that review includes the safety 21 of personnel that have to perform those functions.
| |
| 22 MR. WYLIE: Does that include a design review, and 23 I mean the actual going down to the design level and 24 checking to see whether there is interaction between
| |
| () 25 existing safety systems?
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| '9220 02 02' 70 L(,hrysimons1 MR. JONES: That independent design review is done
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| -2 by'the Engineering Department.
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| ~
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| 3 MR. WYLIE: From!the safety standpoint?
| |
| 4 MR. MARTIN: I might address that. Yes, there is 4
| |
| 5 la safety ' evaluation review that must be made with each
| |
| ; 6 design,.and that is done by the technical people and then 7 verified by the operations people.
| |
| 8 MR. WYLIE: And there is a separate group charged 9 with analyzing-the safety impact of that modification?
| |
| .10 MR. MARTIN: Yes. There are specialists who have 11 the responsibility who familiar with the safety 12 requirements and are familiar with the interactionuof
| |
| . () 13 systems and controls. These people provide the information 14 to the operations people when they provide the details of s
| |
| 15 the design to be made.
| |
| 16 MR. WYLIE: And they are in plant engineering?
| |
| 4 17- MR. MARTIN: They are part of the nuclear 18 engineering instruction unit of the plant. They are on-19 site engineering personnel. ,
| |
| 20 MR. WYLIE: I see. What about as far as the 4-21 operating and maintenance procedures from the safety 22 standpoint, such as the calibration of reactor safety
| |
| ~
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| 23 system instrumentation?
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| 24 MR. JONES: The technical adequacy of the j- ( 25 procedures is the responsibility of the group for which the 1 j 7
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| ; ACE-FEDERAL REPORTERS, INC. 1 202-347-3700 Nationwide Coverase 800 336-6646 1
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| ~ _ . . _ , _ . _ _
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| _ _ _ . , , , _ . _ . _ . . - , _ . _ _ _ _ _ _ _ _ , . _ _ -. _ _ _ _ _ __ _.,,, . _ ._ ._ _ _ _a
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| .9220 02 02 71 procedures are intended.
| |
| u("lrysimons 1 2 The nuclear significance and safety of thosa procedures is reviewed by the on-site safety committee, and 4 they must recommend that the procedure be approved prior to 5 the Plant Manager approving that procedure.
| |
| 6 MR. WYLIE: Down to the details of the circuitry?
| |
| 7 MR. JONES: Yes.
| |
| 8 MR. WYLIE: Fine. Thank you.
| |
| 9 MR. REMICK: Mr. Jones, I need some help. Somehow 10 I don't understand everything that I know about your 11 organization. You are General Manager of Nuclear 12 Operations, and I assume that you report to Mr. Sieber?
| |
| () 13 MR. JONES: Yes.
| |
| 14 MR. REMICK: Well, when I look at Mr. Sieber's 15 chart I don't see anything that says nuclear operations.
| |
| 16 MR. JONES: There was a picturing showing the 17 sunset position I believe that was a dotted ---
| |
| 10 l MR. REMICK: Oh, I see. The senior manager of BV-19 1.
| |
| . 20 MR. JONES: Right, and that is Mr. Sieber.
| |
| 21 MR. REMICK: But that is just for Unit 1.
| |
| 22 MR. JONES: Pardon?
| |
| 23 MR. REMICK: I am somehow confused now, and the
| |
| , , 24 reason I got into this is I was surprised that in your 4
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| () 25- organization I didn't see training. I realize we are going ACE FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800-336 6646
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| '~.'--+m9 ~ *-w--,p 3 n _, , -- ,m - ,-
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| _,___,4 , - ,y e, , . . , _ . , , , y - y . --e,
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| I 1
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| 9220 02 02 72
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| '[~'rysimons s>
| |
| 1 to get to training later, but I am interested in how 2 training fits in with operations. Is it a parallel 3 organization, and to whom is the first supervisor 4 responsible for both operations and training?
| |
| 5 MR. JONES: Well, under the present organization 6 Mr. Sieber is the manager that is responsible for both 7 operations and training.
| |
| 8 Training is within the nuclear services unit, and 9 while it reports to a different unit than operations, there 10 is much interchange between the plant people, the 11 supervisory people in developing the training programs that 12_ are used to train the people that work in the power plant.
| |
| () 13 MR. REMICK: Well, that is the thing I am 14 concerned about, and will you hit that during training.
| |
| 15 But I thought now, since we are kind of going over all 16 organization that I have become just a little lost. Maybe 17 you could tell me from your chain to -- and now you tell me 18 that Mr. Sieber is the Senior Manager of BV-1 on this i
| |
| 19 chart.
| |
| 20 MR. JONES: Mr. Sieber is the Senior Manager of BV-21 1, and the operating organization is in fact Nuclear 22 Operations Unit, for which I am the General Manager, and 23 the Nuclear Services Unit, for which Mr. Sieber is also the 24 General Manager and the Nuclear Engineering and
| |
| () 25 Construction Unit.
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| ,m
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| ( jrysimons 1 MR. REMICK: Okay. I guess it is the use of 2 different terminology on different slides that threw me 3 off.
| |
| 4 Thank you.
| |
| 5 MR. JONES: Well, Mr. Sieber wears several hats 6 here, too.
| |
| 7 MR. REMICK: And Mr. Sieber reports to Mr. Carey; 8 is that right?
| |
| 9 MR. JONES: Yes, sir.
| |
| 10 MR. REMICK: Okay.
| |
| 11 (Slide.)
| |
| 12 The fourth function in the Technical Services
| |
| (
| |
| (_, 13 Department is the technical advisory engineering. This 14 section is comprised of graduate engineers who perform as 15 shift technical advisers on each operating shift as well as 16 reviewing and assessing events which occur at Beaver Valley 17 and at other nuclear power plants.
| |
| 18 (Slide.)
| |
| 19 The last function reporting to the Manager of 20 Technical Services is the procedure section.
| |
| 21 This section is headed by a licensed supervisor 22 who is responsible for the preparation and maintenance of 23 operating, maintenance and I&C procedures used at Beaver 24 Valley.
| |
| () 25 Again, in concluding my discussion of technical ACE FEDERAL REPORTERS, INC.
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| T' 9220 02 02 74
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| ()rysimons1 services I would like to note that 118 years of experience 2 exists among the 67 people in this department.
| |
| 3 (Slide.)
| |
| 4 The third and final organization within Nuclear 5 Operations is the planning and outage management section. ,
| |
| 6 This section has three basic responsibilities.
| |
| 7 The supervisor of planning and scheduling is responsible 8 for these activities during plant operating periods as well 9 as plant outages.
| |
| 10 The supervisor of maintenance information is
| |
| \ 11 responsible for the equipment. history, maintenance 12 scheduling and work request tracking programs, as well as
| |
| () 13 the coordinating of the NPRDS activities within the nuclear 14 group and for inputting NPRDS data to the INPO data base.
| |
| 15 The outage management supervisor is currently 16 responsible for planning and directing the refueling 17 activities and will be responsible for major outage 18 management when Unit 2 become operational.
| |
| 19 The 17 people presently in this organization have 20 79 years of nuclear experience.
| |
| 21 MR. REMICK: How current are you people in 22 reporting NPRDS data to INPO and how extensively do you do 23 it?
| |
| 24 MR. JONES: All the 1984 data is inputted to INPO,
| |
| () 25 and I believe that we are up to date within perhaps the ACE FEDERAL REPORTERS, INC.
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| 9220 02 02 75
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| ,a
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| ( ,lrysimons 1 last two months.
| |
| 2 MR. REMICK: Good.
| |
| 3 (Slide.)
| |
| 4 MR. JONES: There are currently 470 persons in the 5 Nuclear Operations Unit, including a number of Unit 1 6 experienced engineers and supervisors assigned to Unit 2.
| |
| 7 Within this group are 67 NRC licensed reactor operators and 8 senior reactor operators and 183 college graduates.
| |
| 9 This slide would indicate 77, but the correct 10 number is 67.
| |
| 11 In summary I have presented an overview of the 12 organization structure of the Nuclear Operations Unit. I 13 have briefly described the functions of the organization 14 and I have noted the considerable amount of nuclear plant 15 experience which exists within each of these organizations.
| |
| 16 That concludes my presentation. Do you have 17 questions?
| |
| 18 MR. REMICK: I might have a comment at this 19 point. It is not known yet just what will be recommended 20 by the subcommittee for you to cover before the full 21 committee, but I think you should look at your organization 22 chart from the perspective that I got lost, and maybe there 23 is something that I missed, and think about something that 24 would show -- and I think I am getting mixed up between 25 Beaver Valley 1 and what you are going to be doing in the ACE FEDERAL REPORTERS, INC.
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| , , , . . . 202-347 3700 Nationwide Coverage 800 336-6646
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| I 9220 02 02 76
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| ([)rysimons1 future and so forth -- and if you could have one viewgraph 2 that would show what your intent is with an operating 3 license'for Unit 2 and how you are going to run this and 4 what is the structure and so forth, if you could do that.
| |
| 5 Maybe I got lost because there are some things I 6 don't understand. But if I got lost, the chances are 7 somebody else might get lost, too.
| |
| 8 MR. JONES: It is a large organization and it is 9 easy to get lost as we down through it in describing che 10 functions.
| |
| 11 MR. KERR: Do you understand it now?
| |
| 12 MR. REMICK: I have a better feeling for it, but I (G_) 13 am not sure I fully understand it.
| |
| 14 MR. KERR: I would say if one member of the full 15 committee understands it, maybe it should be left the same 16 because if they change it ---
| |
| 17 (Laughter.)
| |
| 18 MR. REMICK: I am not asking for a change in the 19 organization, but for a viewgraph that describes it.
| |
| 20 MR. WYLIE: Any further questions?
| |
| 21 (No response.)
| |
| 22 Perhaps we should take a break at this point and 23 pick up the next speaker after the break. So let's take a 24 break until ---
| |
| () 25 MR. CAREY: I would like to answer your question ACE-FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800-336-6646
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| 9220 02 02 77 m
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| (jrysimons 1 on reactor trips, Dr. Kerr. We had seven reactor trips in f- 2 1984.
| |
| 3 MR. KERR: Thank you.
| |
| 4 MR. WYLIE: Let's pick up at 10:45.
| |
| 5 (Recess taken.)
| |
| 6 MR. WYLIE: We would like to resume tne meeting.
| |
| 7 MR. KURTZ: The next speaker will be Mr. Fred 8 Schuster.
| |
| 9 MR. CAREY: Excuse me. Before Mr. Scnuster 10 cpeaks, I would like to clarify my comment about the 11 containment. When you dredge me back to the early 1970's, 12 to get the phrases right, there was a concern that you-ym
| |
| (_) 13 described related to what would happen if we turned on the 14 sprays. The calculations showed that, the concern being 15 that if you drew enough vacuum, there may be a potential 16 for the containment liner to buckle, the calculations 17 showed that the maximum vacuu.a vould be eight pound 18 absolute pressure and there would be no buckling of the 19 containment liner. We did not go on to find out what 20 vacuum would have to be drawn in order for that potential 21 buckling to occur.
| |
| 22 MR. EBERSOLE: So you don't know what the margin 23 is then for this. Well, there are no code requirements on
| |
| ,, 24 any vessel that I ever heard of that required that you l
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| ; (~)h
| |
| (_ 25 actually do a code test of negative pressure capability, l
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| ('Brysimons 1- and one, you know, instantly thlaks well, I ought to know v
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| 2 'what the. margins are of safety. I don't want this 3 sheathing to come flying all over the place inside the 4 containment and do damage.
| |
| 5 Do you contemplate any negative pressure drawdown 6 below the hypothetical accident?
| |
| 7 MR. CAREY: No, I don't. Under normal operation 8 we operate with five cfm vacuum pumps. We have two of 9 them. So the maximum,-other than the quench spray system
| |
| -s 10 cooling down the air,'the maximum potential, it would take 11 a very, very long time. .
| |
| 3 12 MR. EBERSOLE: What about the sudden quenching by z.
| |
| () '
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| 13 cold water though?
| |
| 14 MR. CAREY: That is the action that would give us 15 probably a two-pound drop.
| |
| 16 MR. EBERSOLE: That has happened. I recall at
| |
| , 17 Sequoyah they already did that sort of thing, and it is not 18 improbably that somebody will hit it with cold water some 19 day and you would like to know what your margin is between 20 shedding the cladding inside and the actual pre.ssure that 21 you have.
| |
| 22 Don't you feel you need at least a well calculated 23 examination of the margin or a tested one?
| |
| 24 MR. CAREY: I do not have the knowledge of how
| |
| () 25 '
| |
| much additional margin there is, but I have been assured
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| 9220 02 02 79
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| (,)rysimons1 that there is additional margin.
| |
| 2 MR. EBERSOLE: How much?
| |
| 3 MR. CAREY: I don't know. I would have to ask 4 someone. s 5 MR. EBERSOLE: Why don't we find out for the full 6 committee.
| |
| 7 MR. KERR: But in order to know the margin don't o 8 you have to know when it would fail?
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| 9 MR. EBERSOLE: Yes. -
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| 10 MR. KERR: I am told that engineers have great 11 difficulty predicting when things are going to fail. They 12 can predict that they won't fail, but predictions fof
| |
| () 13 failure are tougher.
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| 14 MR. EBERSOLE: I don't know how you define a 15 margin unless you do some sort of prediction.
| |
| 16 MR. KERR: In fact, what I am saying is I don't 17 think you can define a margin very well.
| |
| 18 MR. EBERSOLE: How do you know you aren't at it?
| |
| 19 I mean to me that is tantamount to saying I don't know how 20 accurate my calculation is anyway.
| |
| 21 MR. CAREY: I believe our calculations are very 22 accurate.
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| l 23 MR. EBERSOLE: Well, then see what happens at 24 minus 10 pounds or 7 pounds and let's call that accurate.
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| () 25 MR. CAREY: I will have someone research that for s l ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| 9220 02 02 80 you. I won't be able to have that answer for you today,
| |
| {J^7rysimons 1 2 but perhaps I will by next week.
| |
| 3 MR. EBERSOLE: That is one way to do it.
| |
| 4 MR. SCHUSTER: Good morning.
| |
| 5 (Slide.)
| |
| 6 My name is Fred Schuster. The topic of my 7 presentation is Beaver Valley Emergency Operating 8 Procedures, EOP's.
| |
| 9 Beaver Valley Units 1 and 2 EOP's will be based on 10 the emergency response guidelines, ERG's, Rev. 1 developed 11 by the Westinghouse Owners Group.
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| 12 These ERG's are a significant improvement as a
| |
| {') 13 tool for dealing with plant emergencies. They are based on 14 improved-analyses of emergencies. Their fonnat utilizes 15 vastly improved human factors qualities and techniques and
| |
| , 16 the scope of the procedures is much broader. That is, they 17 cover more potential emergencies than the previous 18 procedures.
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| 19 Duquesne Light Company has been active participant 20 in this development since its beginning following the TMI 21 accident and strongly believes in the improvements that 22 these procedures represent.
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| 23 Beaver valley's intent is to follow the generic 24 guidelines as closely as possible in order to take full
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| ()- 25 credit for the analysis efforts and the human factors ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Natiortwide Coverage 80 4 336-6646
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| 9220 02 02 81
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| ()rysimons1 principles that form the basis for the ERG's.
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| 2 The format of the Beaver Valloy EOP's has 3 subsequently been made very similar to the generic 4 guidelines.
| |
| 5 Beaver Valley 2 procedure generation package, PGP, 6 was submitted to the NRC in July of 1984. Its purpose is 7 to describe the process to be used in developing plant 8 specific EOP's from the generic ERG's.
| |
| 9 (Slide.)
| |
| 10 The PGP covers the major topic areas shown here.
| |
| 11 The first item, initial EOP development, and the 12 third item, training, contain issues somewhat unique to
| |
| ( 13 -Beaver Valley 2 and therefore warrant some discussion. -
| |
| 14 The first item, initial EOP development, covers 15 the mechanics of procedure development. For Beaver Valley 16 this consists of a series of coordinated but independent 17 activities involving a Beaver Valley.1 EOP group and a 18 separate Beaver Valley 2 EOP group.
| |
| 19 (Slide.)
| |
| 20 The next three slides show how these processes 21 were coordinated to achieve EOP's for Beaver Valley 1 and 22 Beaver Valley 2 which are similar, except where plant 23 differences require procedure differences.
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| 24 (Slide.)
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| 25 This was done to support the philosophy of ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336 6646 ;
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| 9220 02 02 82 O
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| (_,rysimons 1 operating Beaver Valley 1 and 2 with some number of dual 2 license operating personnel.
| |
| 3 (Slide.)
| |
| 4 Both Beaver Valley 1 and 2 utilized human factors 5 ' specialists as part of a verification and validation effort 6 and coordinated the EOP and control room design review 7 efforts. This resulted in improvements to both control 8 room indication and procedure flow and optimized EOP human 9 factors quality.
| |
| 10 (Slide.)
| |
| 11 The benefits of having two groups working toward
| |
| . 12 essentially the same goal on the EOP's was that with p).
| |
| (_ 13 coordination wa achieved an increased level of procedure
| |
| , 14 review by a cross-checking of the two independent efforts.
| |
| 15 We introduced Beaver Valley 1 operating experience 16 into the Beaver Valley 2 procedure effort and we 17 facilitated the use of a Beaver Valley 1 simulator 18 validation into the Beaver Valley 2 effort.
| |
| 19 (Slide.)
| |
| 20 Verification and validation of EOP's as described 21 in the PGP basically follows the guidelines published by 22 INPO.
| |
| 23 Verification provides a process to be followed in 24 determining if the EOP's are technically correct and
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| () 25 written to reflect the PGP guidelines. It is accomplished ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| | |
| 9220 02 02 83 4 (jrysimons1 by a detailed evaluation of each step checking the EOP 2 against a detailed criteria check list found in the PGP.
| |
| 3 Validation provides methods of assuring that EOP's 4 are first usable, that is that they can be understood and 5 followed by trained operators without confusion delay or 6 error and, two, that they are operationally correct, that 7 is that there is a correspondence between the control room 8 plant hardware and the EOP's and that they capable of 9 directing the operating crew in managing the event with 10 consideration for the number, qualification, experience and 11 training of the crew.
| |
| 12 This is accomplished at Beaver Valley by a
| |
| ( 13 combination of three available methods.
| |
| 14 (Slide.)
| |
| 15 Beaver Valley simulator validation is one method 16 utilized as input for evaluating such non-analytical human 17 factors considerations as compatibility with operator 18- training, time required for component and system response 19 and clarity of procedural action steps.
| |
| 20 Waikthrough validation on a BV-2 full-scale 21 control board mockup is utilized to evaluate specific BV-2 22 control board layout and instrument impact on the EOP's.
| |
| 23 And, thirdly, table-top validation is utilized to 24 deal with plant specific system differences between Unit 1 25 and Unit 2 which cannot be simulator validated.
| |
| l l
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| ~9220 02 02 84
| |
| ()rysimons1- MR. KERR: Excuse me. What is meant by table-top l 2 validation?
| |
| 3 MR. SCHUSTER: It is a process using operators 4 forming a crew as if they were performing the emergency 5 procedures in a control room environment, talking through 6 the procedure and utilizing whatever reference material is 7 needed to assure themselves that they can proceed through 8 it correctly.
| |
| 9 MR. REMICK: Table top, Bill, as in contrast to 10 under the table.
| |
| 11 (Laughter.)
| |
| 12 (Slide.)
| |
| p
| |
| () 13 MR. SCHUSTER: The other PGP topic of interest is 14 the training program. The PGP covers program objectives 15 and scope.
| |
| 16 The initial BV-2 license candidates will first be 17 trained on BV-1 and the BV-1 EOP's. EOP training was 18 recently completed for all current licensed personnel, BV-1 19 licensed personnel.
| |
| 20 It consisted of eight classroom training and 21 simulator days followed by a full day of evaluation of 22 their ability to utilize these EOP's during simulator 23 generated emergencies.
| |
| 24 Additional classroom training will be provided as
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| () 25 part of the BV-2 cross-training program. It will address ACE FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336 6646
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| 9220 02 02 85
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| (])rysimons1 the differences between Beaver Valley 1 and 2 EOP's.
| |
| 2 Subsequent license candidates will receive equivalent t i
| |
| 3 training. i 4 In summary, current status of BV-2 EOP effort is 5 that a draft of the procedures has been completed, 6 including background documents.
| |
| 7 The only remaining activity to be performed is a 8 table-top validation of the BV-1 and BV-2 differences.
| |
| 9 This is to be performed when BV-2 trained operators are 10 available.
| |
| 11 With that completed, we will have a set.of EOP's 12 based on Westinghouse Owners Group ERG Rev. I with an
| |
| ( )- 13 improved analysis basis utilizing improved human factors .
| |
| 14 techniques and covering a broader range of potential 15 emergencies. And we will have taken full advantage in the 16 BV-2 procedures of SV-1 EOP efforts and'BV-1 operating 17 experiences.
| |
| : 18. That concludes my presentatior..
| |
| 19 MR. EBERSOLE: May I just ask one question.. Do 20 you have a set of emergency operating procedures which are 21 based on a thesis that the information network is all 22 fouled up, for instance, a major control room disaster of 23 some sort, and you must resort then to going to the remote 24 shutdown panel and operate on a minimum of parameter ,
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| A)-
| |
| (_ 25 signals and control functions? In short, you are in a ACE. FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-33H646
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| 9220 02 02 86
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| (,jrysimons 1 degraded state of information flow and control capability.
| |
| 2 Do you have that all worked out?-
| |
| 3 MR. SCHUSTER: ,le have a draft of a procedure for 4 operation from the alternate shutdown panel, which is quite 5 detailed, and also a procedure draft of operation from the 6 emergency shutdown panel.
| |
| 7 MR. EBERSOLE: That is the distant one, isn't it, 8 in the other fire zone?
| |
| 9 MR. SCHUSTER: No. The emergency shutdown panel 10 is the larger with redundancy and single-failure criteria.
| |
| 11 1 MR. EBERSOLE: Right. Well, that is really just 12 an extrapolation from the mail control board since no
| |
| () 13 damage is assumed.
| |
| 14 MR. SCHUSTER: Right. That has much more 15 indication. The alternate shutdown panel is the smaller 16 one there for the purpose of the Appendix R fire. We do 17 have quite a detailed iraft in coping with that potential 18 emergency.
| |
| 19 MR. EBERSOLE: Would that be available for sort of 20 a review shortly?
| |
| 21 MR. SCHUSTER: We could make the draft available.
| |
| 22 It is not a finished document, but it does give a flavor of 23 what you are asking.
| |
| 24 MR. EBERSOLE: If possible, at least I would like 25 to see a copy of that at such time as it is convenient to ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 800-336-6646
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| 9220 02 02 87 Ch
| |
| .'y;rysimons 1 you.
| |
| 2 MR. SCHUSTER: Yes, we can get you that.
| |
| 3 MR. EBERSOLE: Thank you.
| |
| 4 MR. REMICK: Excuse me. When you are comple.ted 5 and you have a common control room, will you have one EOP 6 for both units, or will Unit 1 have a set of EOP's and Unit 7 2 have a separate set?
| |
| 8 MR. SCHUSTER: There will be a separate set for 9 each unit and they will be color coded, as was mentioned 10 earlier.
| |
| 11 MR. REMICK: Will there be much difference between 12 the two?
| |
| \
| |
| 13 MR. SCHUSTER: We have in the process that I 14 described identified the speciSic step-by-step 15 differences. We have a number of differences because of 16 some of the system differences, but I would say overall 17 that the differences are not significant in the EOP flow or 18 philosophy. I would say there are not significant ,
| |
| 19 differences in the procedures themselves.
| |
| 20 MR. REMICK: The EOP's for Unit 1, they have been 21 in use; is that correct?
| |
| 22 MR. SCHUSTER: No, they have not been placed into 23 use, but there have been quite a number of hours involving 24 training on them at the simulator. So the operators have (n-) 25 been trained, and it is just a matter of some final touch-ACE-FEDERAL REPORTERS, INC. 1 202-347-3700 Nationwide Coverage 800-336-6646
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| ]
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| 9220 02 02 88 I
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| ()rysimons1- up and then they will be implemented within a number of 2 weeks.
| |
| : 3. MR. GRADA: We are planning on implementing the 4 new procedures around November 15th.
| |
| 1 5 MR .' REMICK: I see. Do you have any reaction from 6 your operators yet on how they find them? Are they pleased 7- with them?
| |
| 8- MR. SCHUSTER: I believe they do see them as an 9 improvement over the procedures that we are now using, yes.
| |
| 10 MR. REMICK: I was impressed in the Davis-Besse 11 event with immediately the assistant shift supervisor got 12 them out and was calling out actions and people were (f 13 confirming they were taking them. It was obvious that
| |
| . 14 right from the beginning they went to those. I have 15 experienced other operators telling me not EOP's, not the 16 new set, but the old sets, that they would not be helpful 1
| |
| 17 to them in a crisis situation, and there were 50-some.
| |
| 18 I was wondering if this is too early to know how 19 your operators really accept these at Beaver Valley.
| |
| 20 MR. SCHUSTER: Well, with the extensive training 21 they have gone through, I.think we have a feeling that they 4
| |
| 22 have accepted them quite well. The training is complete-l 23 and it was'quite an extensive training, as I said, eight i 24 days, plus an evaluation day for each operator.
| |
| -( ) 25 MR. WYLIE: Thank you.
| |
| F ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800-336-6646
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| I 9220 02 02 89
| |
| ()rysimons1 We will'now move into the NRC Staff presentation.
| |
| 2 I believe Mr. Singh is the lead presenter.
| |
| 3 (Slide.)
| |
| 4 MR. SINGH: My name is Braj Singh. I am the 5 Project Manager for Beaver Valley Unit 2.
| |
| I 6 (Slide.)
| |
| 7 Some of the milestones might have been discussed 8 by the applicant, but let me go through these milestones 9 for the licensing overview.
| |
| 10 The construction permit was issued on May 3rd, 11 1974.
| |
| 12 The FSAR was docketed on May 18th, 1983, and on
| |
| () 13 the same day the environmental report was also docketed.
| |
| 14 The DES was issued in December 1984.
| |
| 15 The FES was issued in September 1985, and just in 16 October we. issued the SER. ,
| |
| 17 Of_ course fuel load is in April 1987. .
| |
| 18 The main purpose .of this slide was to show you the 19 status of the open items, the confirmatory items and 20 license condition item.
| |
| 21 Since we issued the SER, based on our review at 22 present we have 11 open items, 44 confirmatory items and 1 23 license condition.
| |
| 24 (Slide.)
| |
| ) 25 I am going to discuss first open issues and ACE FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 80433HM6
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| .9220 02 02 90 ,
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| I
| |
| ('rysimons1
| |
| ) estimated resolution date.
| |
| 2 The second one will be the significant backfit 3 issues, since we are not going to discuss all 44. I just 4 picked up six. l l
| |
| 5 Oh, I am sorry. Significant backfit issues, there l N
| |
| 6 .w ere 16 backfit issues, and that we are going to discuss, 7 and significant confirmatory issues and license condition 8 item.
| |
| 9 (Slide.)
| |
| 10 There are 11 open issues.
| |
| 11 There are no major technical differences between i
| |
| 12 the applicant and the staff.
| |
| () 13 These ll-open issues are simply because the 14 applicant has not provided the information yet or the staff 15 has reviewed it and asked for additional information and 16 they have to provide additional information.
| |
| 17 Except one item, cross-training program, they have
| |
| , 18 provided the~information and the staff is reviewing that 19 one.
| |
| 20 MR. KERR: Excuse me. I don't understand the 21 statement that there are no significant differences. If 22 you have gotten information from the applicant and asked 23 them for more information, there must have been some reason 24 that somebody asked for more information.
| |
| () 25 MR. SINGH: Most of them are in the nature of ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 800-336-6646
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| 9220 02 02 91
| |
| .( ,,)rysimons 1 clarification. Let me go one by one and I will tell. Like 2 the third one, inadequate core cooling instrumentation. As 3 I see it, just the staff needs more clarification of why 4 some of the things are missing from the FSAR or something 5 like that.
| |
| 6 Yes, you are right. The initial test program, 7 which you will see on the next slide, and pump and valve 8 leak testing, we had major differences, but it has been 9 resolved.
| |
| 10 The only thing is that we have not been able to 11 put it in the SER at this moment.
| |
| 12 So if I go one by one, preservice/ inservice ,
| |
| o
| |
| (,) 13 testing, the applicant has to provide the information.
| |
| 14 The.preservice/ inservice inspection program, the 15 same way, the applicant has to provide the information.
| |
| 16 Safe and alternate shutdown, that information will 17 be provided in August 1986. So the staff has not reviewed 18 it.
| |
| 19 Management and organization, the applicant has not 20 given even the date to us of when they will provide this 21 information. So we could not tell when we are going to 22 finish our review.
| |
| 23 When you see an estimated resolution date, that is 24 based on the information that has been provided by the l')
| |
| (_ 25 applicant of when they will provide those submittals.
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 336-6646
| |
| | |
| 92
| |
| ~
| |
| 9220 02 02
| |
| /~'T
| |
| (_jrysimons 1 The same way with the emergency preparedness plan
| |
| ~ ,
| |
| 2 also. We have'not gotten any information and we need more
| |
| - 3 information from them.
| |
| 4 MR. KERR: This is on pump and valve leak testing; 5 is that correct?
| |
| ~
| |
| 6 MR. SINGH: That one is the second one, P&V leak 7- testing.
| |
| i 8 MR. KERR: Preservice and inservice testing if 9 what you are talking about?
| |
| 10 MR. SINGH: Yes. They provided a program and the 11 staff looked into that, but a detailed program has to be 12 submitted,_No. 1 and No. 4.
| |
| g.
| |
| 4 13 MR. KERR: I realize the ground rules almost 14 require the staff to ask for additional information no 15 matter what the original submittal is, and I just was 16 curious as to-what was missing.
| |
| 17 MR. SINGH: Dr. Kerr, we don't have enough 18 information on No. 1 and No. 4. If you are trying to get 19 into that No. 2, we had some problem in the tech spec.
| |
| 20 What happened is that NRR issued a memo that if you have a 21 multi-unit plant, which in this case Beaver Valley Unit 1 22 and Unit 2, they can have the same tech spec, except if 23 there is some design change or there is such a significance 24 to the extent that you can ask another unit also to v 25 implement the same thing. P&V leak testing came in that ACE-FEDERAL REPORTERS, INC.
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| #E*.33 _ _ ,__ Nationwide Coverage 800 336 6646 _
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| 9220 02.02 93
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| ()rysimons1 category.
| |
| :2 The staff asked for the leak testing of all those 3 pumps and valves which had the leak rate of more than one 4 gallon per minute. We could not ask the staff to implement 5 that unless they go through the CRGR. The staff has gone
| |
| '6 through CRGR, got the approval and now we are in the
| |
| '7 process of writing the letter to the applicant of what is 18 our position and now accordingly they can submit the list 9- of all these pumps and valves.
| |
| 10 At the same time our criteria had changed. The 11 leak rate can be as high as five gallons per minute if the 12 pipe size,is more than 10 inches.
| |
| I) 13 MR. KERR: So the leak testing to be done on this 14 plant and startup is quite different than the leak testing 15 that was done when No. 1 was started up I take it?
| |
| t-16 MR. SINGH: Yes, sir. That CRGR requirement is 17 only for NTOL's.
| |
| . 18 MR. KERR: I didn't get that first set of 19 initials, CRGR did you say?
| |
| 20 MR. SINGH: Yes, the Committee for Review of 21 Generic Requirements. That is Dircks' office.
| |
| 22 MR. KERR: They have requirements now?
| |
| 23 MR. SINGH: See, what happens is if it is like a 24 deviation from a standard practice, then we have to go
| |
| () 25 through the CRGR and ask for the approval.
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| | |
| 9220 02 02 94 llhrysimons1 Nou, as I said, the third one, inadequate core 2 cooling instrumentation, the staff completed the. review 3 just one month -- or not even one month -- two weeks before 4 we issued the SER. So we did not have enough time to go to 5 .the applicant and ask for clarification. Otherwise, that 6 might have been resolved.
| |
| 7 As I said, safe and alternate shutdown and 8 management and' organization, the submittal has not come 9 yet.
| |
| 10 The cross-training program ---
| |
| 11 MR. KERR: Is the inadequate core cooling 12 instrumentation drastically different on this plant than on
| |
| () 13 other Westinghouse PWR's?
| |
| 14 MR. SINGH: I don't think there is too much 15 difference, but I don't know the details.
| |
| 16 MR. KERR: I would have thought that that almost 17 could have gotten through on a first submittal I guess.
| |
| 18 ! Continue.
| |
| 19 MR. SINGH: On the cross-training program, the 20 submittal has come and Region I had the responsibility to 21 review this cross-training program. Of course, NRR will be 22 the secondary reviewer for that one. I think they have to 23 establish whether the dual training is appropriate or not.
| |
| 24 For the emergency preparedness plan, the submittal
| |
| ( 25 has not come yet.
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| ACE FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| 9220 02 02 95 r~
| |
| ( )rysimons 1 MR.-KNIGHTON: Dr. Kerr, in answer to your 2 question about the staff position of no significant issues, 3 I think what we are trying to tell you is that at this 4 period of time in the review this is not unexpected. Much 5 of the information we need is to complete the docket before 6 the staff can write off on it.
| |
| L 7 MR. KERR: Thank you, George.
| |
| 8 MR. REMICK: On the cross-training program, I 9 guess I don't know what is proposed by the applicant in 10 this case.
| |
| 11 MR. SINGH: They are providing that Beaver Valley 12 Unit 2 operators will be trained on Unit 1 and Unit 1
| |
| ( 13 operators will be trained on Unit 2. Actually basically I 14 think it is a dual training. Region I should be able to 15 tell you more in detail, but I think that is the basic 16 concept.
| |
| 17 I have been given a feedback, even though I did 18 not incorporate that in the SER, that there are a lot of 19 problems. They cannot live with the submittal that has 20 come and Region I is discussing this with the applicant. I 21 think the applicant also is going to modify that position.
| |
| 22 MR. REMICK: Perhaps that question should be asked 23 under staffing. But maybe under the training session you 24 can just give a hint of what you are proposing.
| |
| . () 25 MR. KURTZ: We had intended to do so, yes, sir.
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-33HM6
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| 9220 02 02 96
| |
| ()rysimons1 MR. EBERSOLE: Pardon me just a second. Mr.
| |
| 2 'Singh, on. item No. 5, and on page 9.46 of the SER you talk l
| |
| '3 about safe and alternate shutdown.
| |
| 4 MR. SINGH: Yes.
| |
| 5 MR. EBERSOLE: It involves the switchboards I 6 mentioned earlier. Let me ask you this. These now become 7 intertwined with each other, the safe shutdown and the 4
| |
| i ~8 alternate shutdown. Is there going to be a program defined 9 for the, I guess I would call it the consecutive use of 10 these with progressively deteriorating circumstances in the 11 control room?
| |
| 12 I really question the presence of both what you
| |
| ~
| |
| I 13 call safe and alternate shutdown thinking that only one is 14 necessary. As a matter of fact, I certainly would think 15 that the staff should examine, and this is the first time I f 16' have ever seen a plant which addressed the interval ---
| |
| 17 MR. SINGH: You are right. These are two.
| |
| 18 Actually the safe shutdown is reviewed by the chemical 19 engineering branch within the Division of Engineering, and 20 alternate shutdown is reviewed by another division, the 21 Division of Systems Integration ---
| |
| 22 MR. EBERSOLE: Well, aren't these redundant?
| |
| 23 MR. SINGH: These are two different, you know.
| |
| 24 According to the Appendix R requirement, they should have
| |
| ( 25 alternate shutdown and safe shutdown. They don't need ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336 4646
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| | |
| 9220 02 02 97
| |
| ()1rysimons1 alternate shutdown if they meet all these three criteria, 2 the fire barriers -- what are those three criteria -- the 1 3 separation criteria and the barrier criteria, those 4 criteria if they meet, they don't need alternate shutdown.
| |
| 5 MR. EBERSOLE; What comes into view immediately 6 here is this designer, in fact he materialized the thesis 7 that needed the first board he built, assuming no damage in 8 the main board room, and he has presented an integral board 9 carefully designed for that purpose so you can go to it in 10 the event you can merely not occupy the main control room, 11 but there is no damage in it.
| |
| 12 This suggests that other plants all over the (mm) 13 country have distant cperating points which are not as well 14 integrated as this one, but which may be superfluous once 15 they fulfill Appendix R requirements and they become an 16 operational hazard in the context of sabotage as well as 17 distant fires occurring at the remote points.
| |
| 18 MR. SINGH: I may not be understanding your 19 question. I was a reviewer myself for many plants on 20 Appendix R alternate shutdown, and I don't see this plant 21 anywhere different from any other plants.
| |
| 22 MR. EBERSOLE: Oh, the other plants have integral 23 switchboards like this one for simply operation at a point 24 external to the control room which is merely back-wired to 25 the control room? I thought they used distributed points ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| 9220 02 02 98
| |
| .(prysimons1 of distant control not as well integrated as this design 2 is.
| |
| 3 MR. SINGH: I don't know specifically about this 4 part because the submittal has not come yet. So we don't 5 know what it is. I think this afternoon they are going to 6 discuss this part.
| |
| 7 MR. EBERSOLE: Well, maybe that will be a better 8 time to discuss it. This is the first time I have seen a 9 really-carefully ---
| |
| 10 MR. SINGH: This afternoon they should discuss 11 that part because.we have not seen the submittal yet.
| |
| 12 MR. EBERSOLE: I see. This is the first time I
| |
| () 13 have seen an integral and carefully organized 14 materialization of the least conservative interpretation of 15 GDC-19.
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| ~
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| 16 (Slide.)
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| 17 MR. SINGH: The initial test program, we have gone 18 through this open issue many times. We had several 19 meetings and still the staff has put all those positions 20 and all the questions in the SER, and I think it will 21 require a lot of effort to resolve this one.
| |
| 22 NRC has a consultant and the consultant is helping 23 in resolving this open issue. So at this moment only I say 24 that they need to provide more information and we will
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| () 25 review that.
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| ACE-FEDERAL REPORTERS, INC.
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| E-347-3700 Nationwide Coverage 800 336-6646
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| J9220 02 02 99
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| (]).rysimons1 The control room design review and safety 2 parameter display system, both are still, the submittals 3 have not come. By the end of this year they are going to 4 make the submittal, and hopefully in six to seven months ,
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| 5 our statf will complete the review.
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| 6 (Slide.)
| |
| 7 We had 16 backfit issues, and I would like to make 8 a point that those backfit issues don't mean that these 9 were backfits.
| |
| 10 Lt. der the Generic Letter 84-08 the applicant had 11 the opt'on to identify some of the items as the b'ackfit 12 items. They identified 16 backfit items. Fourteen have
| |
| () 13 been resolved through technical discussion and many 14- , meetings it required. But these two I wrote as significant 15 backfit issues because these two issues had to go through 16 the normal appeal process.
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| 17 During the appeal process the Director of the 18 Division of Licensing chaired that meeting and he heard 19 both sides of the issues and has given the decision.
| |
| 20 On steam generator level control and protection
| |
| ! 21 the issue was that the steam generator level design, 22 control design does not meet IE4E 279.
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| 23 They have the two options, either to meet IEEE 279 24 or to demonstrate that an operator can take action within
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| () 25 10 minutes.
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| ! ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| m 9220 02 02 100
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| ({]'prysimons 1 The applicant demonstrated at 100 percent power 2 that they can terminate the overfill condition, but at low 3 power and at no power they could not demonstrate that. So 4 we had to go through the appeal process. The applicant 5 mentioned that this is not required, since the protection 6 is mentioned, even if all staff postulated failures occur.
| |
| 7 Now the decision by'the Director of the Division 8 of Licensing was that pending the resolution of A-47, which 9 is the safety implication of control systems, and in the 10 interim period if does not pose any threat to the public 11 safety and health, and the applicant agreed to make any 12 modification which will be required for the resolution of A-(n_) 13 47. So that was the decision to the Director.
| |
| 14 : Of course, we have to decide, the Division of 15 Licensing still has to decide whether 50.55 AH criteria, 16 protection of a system, whether it will meet IEE;; 279 or 17 not, whether it is a backfit or not, still they are 18 reviewing and I don't have any answer from them yet.
| |
| 19 MR. EBERSOLE: May I ask a question on that 20 issue. The arguments I saw presented in the SER mostly had 21 to do with the number of control channels and so forth.
| |
| 22 MR. SINGH: Yes, sir.
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| 23 MR. EBERSOLE: It is a fact of life, isn't it, 24 that with these main feed pumps, which are parallel to all
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| () 25 boilers, that the flow of water to each boiler is ACE FEDERAL REPORTERS, INC.
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| 202-347-3700 NationwiA Coverage 800 336-6646
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| 9220 02 02 101
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| (}}rysimons1 controlled by a modulation valve, which is in turn 2 controlled by a multiplicity of control signals.
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| 3 MR. SINGH: Right. ,
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| 4 MR. EBERSOLE: But nevertheless if a valve sticks, 5 you have got to keep the pump running and it does matter 6 how many control circuits work or do not work if the valve 7 sticks, and so it is going to overfill. Is that right?
| |
| 8 MR. SINGH: No, the issue there was, and I am not 9 an expert, but the issue was that they had the three 10 channels, and two out of three should be available, and one 11 they were taking for the protection. So they could not 12 meet the single-failure criteria.
| |
| 13 MR. EBERSOLE: Let me get to a focal point of 14 consequence. I guess what happens if one of these valves 15 sticks and the pumps keep running is you are going to fill 16 up the boiler and it in turn is in parallel with the main 17 steamlines and it will run over and fill the main 18 steamline; is that correct?
| |
| 19 MR. SINGH: Right.
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| 20 MR. EBERSOLE: Will the main steamline carry that 21 water load and what will be the consequence of filling it 22 up due to the emission of water into the main steamlines 23 from one of the steam generators?
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| 24 MR. SINGH: You are right. That question came
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| () 25 during the appeal process also, and that is why we gave the ACE FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| e 9220 02 02 102
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| [)rysimons1 appeal that they don't need to make any modification 2 because even if you avoid the overfill, at this moment we 3 don't see any trait.
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| 4 MR. EBERSOLE: Have the main steamlines been 5 calculated to show that they carry full water loads at 6 pressure, including the hammer effect of filling it up?
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| -7 MR. SINGH: The water hammer effect, that is taken 8 care of in a separate section. No, I don't think they have 9 any water hammer problem at that point.
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| 10 MR. EBERSOLE: Where is this material described 11 and analyzed? I don't see it certainly in ---
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| 12 MR. SINGH: No, it is not. It is not described
| |
| -( ) 13 there, and I think we have left this issue at this moment 14 for A-47 resolution.
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| 15 MR. KNIGHTON: The initial problem had.to do with 16 Chapter 15 analyses. And as it is on the docket right now, 17 the applicant took credit for this low-level signal to 18 mitigate an accident.
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| 19 MR. EBERSOLE: Low-level signal, but I.am talking 20 about high level.
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| 21 MR. KNIGHTON: It is a low level. I think it was 22 a low level ---
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| 23 MR. EBERSOLE: Well, I am talking about the 24 failure of the high-level system to turn ---
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| () 25 MR. KNIGHTON: I am sorry. It is high level. The ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-66 4
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| 9220 02 02 103
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| (''/)rysimons w
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| 1 point is it does mitigate the accident.
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| 2 MR. EBERSOLE: What accident?
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| 3 MR. KNIGHTON: That high-level signal cuts off the 4 pumps.
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| 5 MR. EBERSOLE: It trips the pumps?
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| 6 MR. KNIGHTON: It had to do with shutting down the 7 pumps so you don't have an overfill.
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| 8 MR. EBERSOLE: Is that a safety grade cutoff of 9 the pump?
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| 10 MR. KNIGHTON: The staff is requiring it to be a 11 safety grade cutoff if you are going to use it for that 12 purpose, and therefore they have to meet IEEE 279. There
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| () 13 are two possible ways of doing that, one with hardware and 14 one demonstrating that operator action can do the same 15 thing.
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| 16 MR. EBERSOLE: In appropriate time.
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| 17 MR. KNIGHTON: Yes. They did submit information 18 on operator action. However, the staff hasn't completely 19 accepted it.
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| 20 MR. EBERSOLE: I see.
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| 21 MR. KNIGHTON: So in the meantime it has been 22 identified by the licensee or the applicant that he has 23 taken credit for that particular instrument. We don't have 24 that on the docket yet. We had the appeal item, and the
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| () 25 appeal recognized that A-47 is in fact looking at this type ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-33MM6
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| 9220/02 02- 104
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| (}rysimons1 of problem, and that in the interim there does not appear 2 - to be a significant impact on the health snd safety of the 3 public.
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| 4 MR. EBERSOLE: Well, is that based on a thesis 5 that all it will do is just fill up the pipe with water and 6 that is the end of it and it won't knock the line down?
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| 7- MR. KNIGHTON: That is right.
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| .8 MR. EBERSOLE: And that has been calculated?
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| 9- MR..KNIGHTON: That has been looked at and it was 10 discussed I believe in the appeal process. It was part.of 11 the discussion.
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| 12 MR. EBERSOLE: So there are some calculations that
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| () 13 you can hydraulically fill the main steamlines?
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| 14 MR. SINGH: George, I don't remember that in the 15 appeal process. We did not calculate or nobody ---
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| 16 MR. EBERSOLE: Well, then how did you judge 17 whether there was any consequence or not?
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| 18 MR. KNIGHTON: I think the applicant can respond 19 to that.
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| 20 MR. SINGH: Right.
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| 21 MR. EBERSOLE: Sure.
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| 22 MR. SINGH: They provided that A-47 will look into 23 that.
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| 24 Before I move to another one, let me add that even
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| -( ) 25 though right now in the FSAR it appears that they took the ACE-FEDERAL REPORTERS, $C.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| 9220 02 02 105 (3
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| L ( jrysimons 1 credit for the Chapter 15 analysis, they are going to
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| '2 revise the FSAR and they will not take the credit for 3 mitigating an accident, that part.
| |
| 4 The next one is fire suppression in the cable 5 spreading room. You know that the applicant used CO2 as 6 the main suppression system. The staff requirement was 7 that to meet the Chemical Engineering Branch, the branch 8 technical position they had to provide an automatic fixed 9 water suppression system. The applicant did not feel that 10 it was required and it was beyond the guideline of the SRP.
| |
| 11 l So we went through the appeal process and the 12 decision there was that the CO2 suppression system backed 13 ' ,up by the manual and fire brigade training, they should be 14 sufficient, with the exception that they had to make some 15 modifications in the northwest corner of the cable 16 spreading room. We had that drill by the fire brigade 17 people and the NRC staff felt that it will be very 18 difficult to reach in that northwest corner in extreme 19 accident conditions.
| |
| ; 20 The applicant just one week ago, they have 21 provided their justification and some modifications that 22 they are going to make. The staff has not reviewed them 23 yet. To me it 1coks pretty good, but the staff has to 24 review that one.
| |
| ( 25 MR. EBERSOLE: May I ask a question on that t
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| i ACE-FEDERAL REPORTERS, INC.
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| Nationwide Coverage 800-336-6646
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| _ . _ _ , _ _ _ _ __ _ _ E _347-3700
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| i i
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| I 3
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| 106
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| '9220 02 02 l v s .t
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| .Qqrysimons 1 ,
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| topic. We determined in the visit yesterday that the room 2 you are talking about is I think the largest room that will s 3 be submitted to CO2 protection.
| |
| 4 4 MR..SINGH: Yes.
| |
| 5 MR. EBERSOLE: The topic'that came up was, and it 6 is a'more or less generic one, in the metering of carbon 7 dioxide to a variety of volumetric sized rooms if you do it 5 51 ,
| |
| 8 from a common tank farm, you will require metering 9 circuitry and equipment that defines the number of cubic 10 feet that you release to each space.
| |
| 11 It has been the experience in the industry here 12 that that metering gsystem is unreliable. It is single
| |
| : 13. channel, it is not seismic and it can't be depended on to 14 stop the flow of CO2 before a possible destructive 15 pressurization of the smaller volumes.
| |
| 16 Do you follow me?,,
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| 17 MR. SINGH: Yes.I 18 MR. EBERSOLE: Thus, the CO2 system is capable, at 19 least hypothetically,_of blowing up a room like a battery 20 room, if that happened to be the case in point, which is 21
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| [ t 21 hardly a desirable thing to have happen.
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| 22 I think the staff should give us a little 23 '
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| presentation on why this sort of t,hing is okay at this 24 plant, Beaver Valley 2 as well as in the generic context.
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| 25 U!R. SINGH: Okay. .
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| ?
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| \
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| s t'
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| $., ACE-FEDERAL REPORTERS, INC.
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| 3)2-347J00 Nationwide Costrage 800-336-6646 L . . _ . _ _ _ _ , _ _ , _ _ _ _
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| | |
| 9220 02 02 107 I()rysimons1 MR. EBERSOLE: There is another little interesting 2 thing in the diesel rooms. Those are CO2 protected as 3 well. I think.it is necessary that the staff explain their 1
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| 4 understanding of how the phenomena of avoiding loss of 5 cooling to the generators, the diesel driven generators is 6 obtained since one of the effects of the CO2 discharge is 7 to close the room tightly and then subsequently there is a 8 stoppage of the ventilation system at higher temperature.
| |
| 9 I think the staff needs to tell us how they think 10 that arrangement is satisfactory in the diesel rooms. You 11 understand the damage potential is that of losing the 12 coolant, which is atmospheric air to the generator and not
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| () 13 to the diesel engine proper since it is externally 14 aspirated.
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| 15 MR. SINGH: Okay. I will try to get some answers 16 during the full committee meeting. I will someone from 17 fire protection.
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| 18 MR. WYLIE: Before you leave that, would the 19 applicant like to comment on these ---
| |
| 20 MR. KURTZ: On the steam generator level control 21 system we believe that Beaver Valley 2 did provide an 22 acceptable level of safety to the staff. Part of the )1 23 original basis was the fact that this is the same identical 24 system that is on Beaver Valley 1. In fact, it is the same
| |
| () 25 Westinghouse /NRC reviewed and approved system on 26 other ACE FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-33M646
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| 9220.02 02 108
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| ()rysimonsl~- operating plants in existence today.
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| 2 In fact, there are six Westinghouse plants out 3 there operating approved by the staff with no level 4 protection at all, and they have been reviewed essentially 5 under the same criteria as Beaver Valley 2. This was the 6 basis for our discussion as to why we felt that Beaver 7 Valley 2 did provide an acceptable level of safety.
| |
| 8 The discussion was not the high-level trip. It 9 was the low-level trip. On the high-level trip the pumps 10 do shut off, and that was not the item of concern.
| |
| 11 The issue of the overfill and so forth was just as 12 Mr. Singh indicated. It is tied directly to the unresolved (GJ' 13 safety issue, and we believe relative even to Beaver 1 and 14 Beaver 2 that certainly any regulatory requirements that
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| : 15 come out as a result of those issues that we will adopt 16 those.
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| 17 MR. KERR: But since you haven't done anything 18 about it on your own yet, you apparently don't think it is 19 an important safety issue.
| |
| 20 MR. KURTZ: We have analyzed it. In fact, we 21 addressed the overfill by means of operator action and by 22 the -- maybe I should get my expert to discuss it. Can I 23 defer this to Ron Fedin to Ron Fedin to provide us some 24 insight as to kind of what we did.
| |
| 25 MR. KERR: If you think you have treated the issue ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 336-6646
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| .~_ _ . _ . _, _ . . .-
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| 9220 02 02 109
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| ()rysimons1 so that in my mind it is no longer a safety issue, I am 2 satisfied. I got the impression that you were going to 3 wait for the NRC to decide whether it was a safety issue or 4 not, and I can understand that you would wait for them to 5 decide whether it is a regulatory issue or not, but I don't 6 think you should wait for them to decide if it is a safety 7 issue, t
| |
| 8 MR. KURTZ: Okay. Ron.
| |
| 9 MR. FEDIN: We believe we have an acceptable level 10 of safety right now, and that is what we were trying to
| |
| - 11 demonstrate to the NRC.
| |
| 12 MR. KERR: Okay. Thank you.
| |
| () 13 MR. REMICK: To continue that, did you 14 specifically look at the point Mr. Ebersole was getting at, 15 that if you did have an overfill and filled the steam 16 lines, has anybody looked if the steam lines would come 17 down or what?
| |
| 18 MR. FEDIN: No, we don't believe that we would get 19 to that event. There are several reasons that we have come 20 to our conclusion.
| |
| 21 One, we believe this is a very low probability 22 event. There are three channels that we are talking 23 about. One of the channels is the one that controls the 24 feedwater control valve. The failure has to be out of this
| |
| (_) 25 one out of three channels. It has to be a fail low which ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336 6646
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| i 9220 02 02 110 f')rysimons v
| |
| 1 would cause this valve to go fully open.
| |
| 2 The second failure has to be on one of the other 3 two channels, and the channel has to be a fail as is. 'It 4 can't fail low and it can't fail high.
| |
| 5 MR. REMICK: Excuse me. I appreciate what you 6 saying, but my question is did you specifically calculate 7 that if that'did not work and if those steam lines filled,
| |
| '8 are the supports _ adequate to keep the steam lines from 9 coming down? Did anybody do that calculation and what was 10 the conclusion?
| |
| 11 MR. FEDIN: No.
| |
| 12 MR. REMICK: No, you did'not. Thank you.
| |
| () 13 MR. EBERSOLE: Well, irrespective of how many 14 control channels on a control valve you have, if it 15 mechanically sticks in place, it sticks in place.
| |
| 16 MR. FEDIN: Well normally we are running at 100 17' percent power, and if it sticks it- is not going to change 18 positions. Something would have to first go open. If it 19 went open, and we are looking at it causing to go open by 20 the feedwater control system. That is the situation that.
| |
| 21 we are looking at here.
| |
| 22 MR. EBERSOLE: Yes, but if it merely sticks in 23 situ and yet you trip the plant, you will overfill rapidly, 24 won't you?
| |
| 25 MR. FEDIN: We also have the feedwater isolation ACE-FEDERAL REPORTERS, INC.
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| .202-347-3700 Nationwide Coverage 800-336 6646
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| 9220 02 02 111
| |
| ' ('T\_/rysimons 1 valves that will close if we have a trip, and also we have 2 a low T-av signal.
| |
| 3 MR. EBERSOLE: So you have a backup in the motor 4 trip?
| |
| 5 MR. FEDIN: That is correct.
| |
| G MR. EBERSOLE: Do you close the main feedwater 7 -system off when you trip the reactor?
| |
| 8 MR. GRADA: That is correct.
| |
| 9 MR. EBERSOLE: So what happens when you trip every j 10 time, you tell the feedwater system to stop; is that right?
| |
| ~
| |
| 11 MR. GRADA: Only if we get a low T-av signal. If ,
| |
| 12 we have a reactor trip situation and a low T-average signal
| |
| [) 13 from the reactor coolant system, it will close the 14 feedwater isolation valvds.
| |
| 15 MR. EBERSOLE: I see. Thank you.
| |
| 16 MR. WYLIE: Does the applicant have any comment on I
| |
| 17 the fire suppression?
| |
| 18 MR. KURTZ: We have a presentation this afternoon 19 and it will somewhat address this issue.
| |
| i 20 MR. WYLIE: All right.
| |
| 21 (Slide.)
| |
| 22 MR. EBERSOLE: One quick question. When your 23 reactor trips you will get a low T-av as a consequence of 24 trip which says to me that every time you trip the reactor
| |
| () 25 you shut the feedwater off. Am I correct?
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| ACE. FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| 9220.02 02 112
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| ('rysimons1 j MR. GRADA: On a P-4 signal, which is a reactor 2 trip, at 554 degrees,-which is not low, that just means you 3 are decreasing in power, the main feedwater valves get an
| |
| '4 isolation , signal. The feed header isn't wrapped up.
| |
| 1- 5 However, you still have bypass-control capability. ,
| |
| 6 MR. EBERSOLE: Right. I really am trying to get 7 at the challenge frequency of the aux feedwater system.
| |
| 8 MR. GRADA: Well, every time the plant does trip 9 because of the shrink in the steam generators, you do get 10 an. aux feedwater start signal on low level.
| |
| 11 MR. EBERSOLE: Is that a safety challenge or juct
| |
| : 12. an operational ~ challenge and you can back-it up by main b( [ 13 feed shortly thereafter.
| |
| 14 MR. GRADA: Well, we keep the bypass valves-15 cracked to minimize the thermal introduction of cold aux 16 feedwater.
| |
| 17 MR. EBERSOLE: Could you give us a little bit of a 18 picture as to what the challenge frequency is on your aux s
| |
| 19 feed systems on 1 and 2 that you anticipate and have had in 20 - the past, not now, but later?
| |
| 21 MR. GRADA: Well, historically, I mean if we are u
| |
| 22 talking for this year, for example, we have had eight 23 demands by virtue of reactor trips on the aux feedwater,
| |
| - 24 not chall'enges, but.because we have had main feed 25 available.
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| ACE FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800-336-6646
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| 9220 02 02 113 t")rysimons1 i
| |
| m MR. EBERSOLE: Right. That is what I wanted to ---
| |
| 2 MR. GRADA: Are you talking strictly in terms of 3 no main feed available?
| |
| 4 MR. EBERSOLE: Yes, right.
| |
| 5 MR. GRADA: I can address that at the full 6 committee.
| |
| 7 MR. SINGH: These are the 16 backfit issues.
| |
| 8 (Slide.)
| |
| 9 Out of 44 I picked up seven significant 10 confirmatory issues.
| |
| 11 The first one is soil structure interaction 12 analysis. This has been resolved. The main issue there
| |
| ( 13 was that the applicant's soil structure analysis was done 14 at the ground level, whereas the staff required the 15 foundation level. We had several meetings. We had our 16 consultants and the applicant provided their evaluation 17 from six consultants, I think five or six consultants from 18 MIT and Berkeley and all over, the best experts they could 19 get in this country. We also had our consultant from 20 Brookhaven National Laboratory. They looked into that and 21 this has been resolved simply. I could not close this item 22 because the TER from Brookhaven National Laboratory came 23 just one week before my issuance of the SER, but this is 24 the result.
| |
| bs/ 25 Nos. 2, 3 and 4, equipment qualification, ACE FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 80 4 336-6646
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| | |
| l 9220 02 02 114 (J'1rysimons'l methodology and procedures have been approved by the 2 staff. However, the complete submittal for the program has 3 not come. We don't see any problem in those three items.
| |
| 4 MR. KERR: Does No. 3 mean that they simply have 5 to tell you in writing how they are going to assure that 6 the pumps and valves will be reliable? In effect is that 7 what that means?
| |
| 8 MR. SINGH: That will be looked into.
| |
| 9 MR. KERR: I am trying to find out what it means, 10 what it is that you require that they do. Do they write 11 you a letter saying we are going to make sure that the 12 pumps and valves will operate?
| |
| () 13 MR. SINGH: They have to provide a list of the 14 pumps and valves and what program they have and how they 15 consider that ---
| |
| 16 MR. KERR: And how reliable do they have to be?
| |
| 17 MR. SINGH: I am not an expert on that. I cannot 18 tell you that.
| |
| 19 MR. KERR: Well, I don't want an expert opinion.
| |
| 20 I just want an engineer's opinion. How reliable does the 21 NRC require that they be?
| |
| 22 Does anybody know?
| |
| 23 MR. KNIGHTON: Well, Dr. Kerr, what we are talking 24 about here is they present the program in which they will
| |
| ) 25 do their demonstration.
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| ACE-FEDERAL REPORTERS, INC.
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| ll02-347-3700 Nationwide Coverage 800-336-6646
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| .9220 02 02 115
| |
| .'(_,2rysimons
| |
| .a 1 MR. KERR: Well, but you have to make a judgment 2 as to whether it is adequate, and how do you decide that it 3- is adequate?
| |
| 4 MR. KNIGHTON: They do this primarily by an audit.
| |
| 5 MR. KERR: But you look for something. You have 6 to look for something. You are trying to assure 7 reliability, and I am trying to understand what reliability 8 is acceptable.
| |
| 9 MR. SINGH: Excuse me. I think they have to 10 provide from the manufacturer what type of qualification 11 and what type of quality assurance has been done on the 12 pump and valve. And let me make it clear, it is not so .
| |
| 13 simple.
| |
| 14 MR. KERR: I am now trying to find out how the NRC 15 decides whethe.r what they provide is adequate. Do you just 16 look to make sure they have submitted a lot of paper, or ---
| |
| 17 MR. SINGH: No. They go on the site. An onsite 18 audit takes place.
| |
| 19 MR. KERR: Okay. What do you look for when you 20 get on site since the things aren't even in operation yet?
| |
| 21 MR. SINGH: Adequate certification.
| |
| 22 MR. KERR: You look for paper, right?
| |
| 23 MR. SINGH: To me it looks that ---
| |
| 24 MR. KERR: And what does the paper say about the 25 reliability?
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| | |
| l
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| '9220 02'02 116 l
| |
| [,)rysimons1 MR. KNIGHTON: Let me interrupt a second. Dr.
| |
| 2 Kerr, we really don't have the people here to address your 3 particular question. I will be glad to get someone for the 4 full committee meeting.
| |
| 5 MR. KERR: I don't have to have somebody for the 6 full committee meeting. I mean you can just tell me that 7 you either require some sort of numerical reliability or 8 you require something different. It is not a trick 9 question.
| |
| 10 MR. KNIGHTON: I don't believe it is a numerical 11 reliability.
| |
| 12 MR. SINGH: It is not numerical. I think it is a A
| |
| 's_/ 13 certification more.
| |
| 14 MR. KERR: So it is an assurance that they have
| |
| .15 ordered things according to specs and that you have a copy 16 of the specs and that the specs answer QA and all those 17 things?
| |
| 18 MR. SINGH: Exactly.
| |
| 19 MR. KERR: So when you get all that you still 20 don't know how reliable the valves and pumps are.
| |
| 21 MR. KNIGHTON: No, but'we have a warm feeling.
| |
| 22 MR. SINGH: We have to depend on the certification 23 of ---
| |
| 24 MR. KERR: But does certification -- you tell me 25 it does not give you any numerical value for reliability.
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| +
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| 9220 102 02 117 hrysimons1 Do they?
| |
| ie 2 MR. SINGH: No.
| |
| 3 MR. KERR: So you still don't know how reliable 4 they are.
| |
| 5 MR. KNIGHTON: And we wouldn't know historically 6- as you go ahead and progress in the operation of the .
| |
| 7 plant. That depends on the maintenance and everything 8 else.
| |
| 9 MR. KERR: Well, I am curious about what is meant 10 by pump and va*.ve operability assurance.
| |
| 11 MR. GRADA: Sir, I would like to address that.
| |
| 12 . MR. KERR: Sure.
| |
| () 13 MR. GRADA: That issue is associated with 14 submittal of the~overall ASME 11 pump and valve inspection 15 and testing program.
| |
| 16 MR. KERR: You have to commit to that, don't you?
| |
| 17 MR. GRADA: Yes.
| |
| 18 MR. KERR: Then what is the issue?
| |
| 19 MR. GRADA: It is just, you know, that is a 20 confirmatory issue that we will submit the program.
| |
| '21 MR. KERR: And the program just says that we will 22 comply with the ASME codes?
| |
| 23 MR. GRADA: No, it is the overall program, what 24 the program description covers, you know, what pumps and
| |
| () 25 valves are embraced by the ASME 11 program, the frequency I
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide coverage 800 336-6646
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| -9220 02 02 118-e-
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| (_)rysimons1 of testing and the methodology of testing.
| |
| 2 MR. KERR: Okay. And when this is all done you 3 still don't know what the reliability will be.
| |
| 4 MR. GRADA: You have an historical data base, you 5 know, or through NPRDS you are not going to have that, no.
| |
| 6 MR. KERR: Thank you.
| |
| 7 MR. KNIGHTON: It is utilizing your basic industry 8 standards.
| |
| 9 MR. CAREY: Dr. Kerr, one of the problems with 10 submitting this program is that we have to make a 11 determination that all of the parameters that are required 12 to be obtained to full comply with the ASME 11 testing O
| |
| sj 13 program are actually obtainable by existing instrumentation 14 and, if not, what additional instrumentation might be 15 required to obtain them.
| |
| 16 That is the reason it is taking us so long to 17 develop the details of the program.
| |
| 18 MR. KERR: Okay. And this is different than what 19 you had to do when you built Beaver 17 20 MR. CAREY: That is correct. On Beaver Valley No.
| |
| 21 1 unit this was not an issue at the operating license 22 stage. In fact, we submitted the program and the program 23 was reviewed by the staff for probably two or three years.
| |
| 24 I do not believe that they issued their approval of our
| |
| ) 25 ASME 11 pump and valve testing program until about 1980, ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 80 4 336-6646
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| 9220 02 02 119
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| -()irysimons1 which was four years after commercial operation.
| |
| 2 MR. KERR:. Thank you.
| |
| 3 MR. SINGH: Let me add that most of the issues 4 that we are talking about, they have a team, like the team 5- they have got for Part 1 they call it. They have got a 6- team, you know, not one person, one reviewer, but a team of 7 four or five reviewers go and audit the whole program. But 8 again, we don't have a numerical number, but the 9 certification will depend on that.
| |
| 10 MR. i9F uE: Pardon me. Let me ask easier 11 questions than Bill asked, you know, the black and white 12 routine ---
| |
| 13 (Laughter.)
| |
| 14 On the environmental qualification of mechanical 15 and electrical equipment, it is easy for us to define the 16 containment interior as a hostile environment and to 17 provide appropriately qualified equipment to work in there 18 if it has to. It is somewhat less easy to go outside in 19 the aux building and so forth and define where we get into 20 a hostile-versus a mild, a potentially hostile versus a 21 normally mild condition.
| |
| 22 MR. SINGH: Right.
| |
| 23 MR. EBERSOLE: We have learned that the staff has 24 permitted some odd things to take place. I will take a
| |
| ( 25 case in point. NEMA Type 4 enclosurt,s have been known to ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800-336 6646
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| '9220 02 02 120
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| (~Nrysimons 1 have been bored with holes in them to eliminate the v
| |
| 2 . implosion potential caused by containment pressure and 3 permit the intrusion of moisture at which time then the
| |
| , 4 operator has to analyze leakage currents in milliampere 5 circuits and determine if there is enough to work the 6 circuits.
| |
| -7 MR. SINGH: Right.
| |
| 8 MR. EBERSOLE: That is hardly what I would call a 9 conservative approach to a problem, rather than maintaining 10 hermetic seals that will resist external pressure.
| |
| 11 Nevertheless, it has been done and it is causing an awful 12 lot of trouble all over the country.
| |
| () 13 Secondly, out in the aux building where you have 14 moderate to high pressure steam lines and so forth, it is 15 not always true that you look at the potential for 16 atmospheric steaming at atmospheric pressure which applies 17 a heavily steaming atmosphere to initially cold terminal 18 boards which are open in design and thus presents a problem 19 of short-circuiting through immediate condensation on 20 possibly dirty contacts or terminal boards therein, and you 21 find this equipment has been designed for the hypothetical 22 modest atmosphere being maintained all the time, which is 23 not true.
| |
| 24 Is the staff looking at these matters?
| |
| ) 25 MR. SINGH: Yes.
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| ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800 336-6 9 6
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| 9220 02 02 121 I knrysimons 1 MR. EBERSOLE: And is it being done thoroughly at 2 this plant?
| |
| 3 MR. SINGH: Yes, the staff has looked into those 4 harsh conditions for, say, Beaver Valley 2, and I know for 5 South Texas RSB took a position for the RHR since the RHR 6 is there. Specifically they asked a question for the harsh 7 condition and how you are going to do the qualification for 8 these RHR pumps and all those things, and they look into 9 that I think.
| |
| 10 MR. EBERSOLE: Well, in looking at it there are 11 two other problems.
| |
| 12 One has these pressurized lines emerging into the 13 aux building and the isolation are hypothetically at least, 14 if the operability assurance works, they are supposed to 15 close upon pipe failure or a leak of any kind in a 16 prescribed interval of time. That permits sort of a 17 metered emission of steam and vapor into these open spaces, 18 which are normally at modest conditions.
| |
| 19 The other hypothesis is if you don't close those 20 lines there is a continued emission of this high 21 temperature water and fluid, you know, fluid and vapor 22 which leads to a much more and far extended severe 23 environment in the aux building with all of its open 24 switchboards and apparatus.
| |
| O- 25 What position does the staff take that they will ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 ._ Nationwide Covege _ _ 800 336-6646 _ _ __ _ _
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| | |
| a
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| -9220 02 02 122 r^g ls harysimons 1 always get a guaranteed closure in a specified interval of 2 time and thus have a modest contamination of the 3 environment or will they face the-more conservative view 4 that in fact they don't close at all and you have continued 5- emission, you know, from a reactor water cleanup as a case 6 in point?
| |
| 7 MR. SINGH: I do not know at this moment what they 8 have ---
| |
| 9 MR. EBERSOLE: Why don't you develop a little 10 argument and tell the full committee about this. This is a 11 standard problem.
| |
| 12 MR. SINGH: -Right. We will try to address this in
| |
| ( 13 the full committee.
| |
| 14 MR. KNIGHTON: You want to listen to the subject 15 of the equipment qualifications for harsh environments and 16 how we arrive at this.
| |
| 17 MR. EBERSOLE: Yes.
| |
| 18 MR. SINGH: The next one is the analysis of 19 combined LOCA and seismic loads. We do not have any 20 problem with that, the staff. I mean the staff doesn't 21 have any problem. The applicant has provided the analysis 22 for a maximum combined load on the grid and the staff found 23 it acceptable, except that they used the computer code, 24 MULTIPLEX-3, which is not an approved code, and we are 25 looking into the approval of that code. So that is what is ACE-FEDERAL REPORTERS, INC.
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| _ _ . . _ . _ . 202 347 3700_ __ Nationwide Coverage ,__ __ 800-336-6646_ __ __ _ _ _ , _
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| i 9220 02 02 123 G('\mrysimons 1- the hedge.
| |
| 2 Next is steam generator tube rupture. I think the ;
| |
| 3 Westinghouse Owners Group is looking into that, and once 4 the Owners Group generic program is submitted, I don't 5 know, the staff may ask for the plant specific analysis.
| |
| 6 But this is being addressed by the generic owners group, 7 the Westinghouse Owners Group.
| |
| 8 And the last one is the quality assurance 9 program. The submittal has not come yet. It looks like 10 there is one hedge regarding the iodine monitoring 11 equipment. I think the staff wants that qualified and the 12 applicant has a different view, but that just developed O
| |
| %' 13 about two or three days ago. I don't know the full 14 details, but hopefully it should not be a bic problem once 15 the submittal comes from the applicant.
| |
| 16 (Slide.)
| |
| 17 There is one license condition item, and I think 18 this also will be resolved before the fuel load date.
| |
| 19 We had 23 concerns, the staff. I could not put it 20 in the SER at that time because the staff wanted to resolve 21 these and it one time. There were 23 concerns, the meeting 22 took place and all the concerns have been addressed, except 23 one regarding the qualification of the. accumulator tank.
| |
| 24 The staff wants the qualified pressure indicator 25 or level indicator, and the applicant does not feel that ACE-FEDERAL REPORTERS, INC.
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| Ri M 37-3700 Nationwide Coverra 800-336-6646
| |
| | |
| 9220 02 02 124 l n:rysimons<1 they need to provide these qualified indicators because 2 these are not required by the operator for mitigation 3 consequences of accidents and these are just for 4 establishing the preoperation condition only.
| |
| 5 The staff is looking into that because various 6 branches, the Reactor System Branch, ICSB and all other 7 branches are involved in this one. So they need ---
| |
| 8 MR. KERR: One could conclude from this, and I am 9 sure I must be making a mistake, that the staff is making 10 regulatory guides a requirement. That is surely not the 11 case.
| |
| 12 MR. SINGH: We are looking into the emergency G
| |
| kl 13 response capability according to Reg. Guide 1.97, the 14 requirements, and there are a lot of requirements there, 15 and all these requirements ---
| |
| 16 MR. KERR: I am not making myself clear.
| |
| 17 Regulatory guides, at least one branch of the staff 18 periodically tells me that regulatory guides are not 19 requirements.
| |
| 20 One could conclude from this that another branch 21 of the staff is making regulatory guides requirements.
| |
| 22 Which is the true staff?
| |
| 23 MR. SINGH: Okay. It see this being the primary l 24 responsibility, but sometimes when the question comes, like l
| |
| () 25 ICSB, it seems that, you know, it is okay, but they cannot ACE-FEDERAL REPORTERS, INC. 1
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| _ _202 347-3700 Nationwide Covertre 800-336-6646
| |
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| 9220 02 02 125 r"s
| |
| (__hrysimons 1 make the decision themselves.- So they can go and ask for a 2 second review.
| |
| 3 MR. KERR: ICSB doesn't have the policy-making 4 decision to say that a regulatory guide is a requirement, 5 does it?
| |
| 6 MR. SINGH: That is right. They don't have a 7 decision, but an interpretation.
| |
| 8 MR. KERR: They can interpret the regulatory guide 9 as a requirement; is that what you are telling me?
| |
| 10- MR. SINGH: That is what I am saying, the 11 interpretation.
| |
| 12 MR. KERR: I would think that might be illegal.
| |
| 13 MR. SINGH: No, I think it is whether they meet 14 the intent of that Reg. Guide 1.97 or not.
| |
| 15 MR. KERR: But regulatory guides are guides. They 16 are not requirements, or at least that is what one part of 17 the staff tells me.
| |
| 18 MR. SINGH: You are right, but this may not be in 19 black and white exactly written. That may be the problem.
| |
| 20 MR. KERR: WelA, all the regulatory guides I have 21 seen were written in black and white, no color.
| |
| 22 (Laughter.)
| |
| 23 MR. SINGH: But I don't know what is the problem 24 here. I will look into that definitely. You know, all O
| |
| (/ 25 these things ---
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Cov@me 800 336-6646
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| | |
| '9220 02 02 126 unrysimons 1 MR. KERR: I don't see why one has to look into 2 that question. You mean there is some doubt in your mind 3 about whether regulatory guides are requirements?
| |
| 4 MR. KNIGHTON: Dr. Kerr, may I interject in this.
| |
| 5 Really, as you well understand, reg. guides are a staff 6 interpretation, and the applicant can follow that 7 interpretation or he can offer the equivalent degree of 8 safety. He has that opportunity.
| |
| 9 MR. KERR: Yes.
| |
| 10 MR. KNIGHTON: And all of NRR is supposed to 11 follow that.
| |
| 12 MR. KERR: So he is offered an alternative.
| |
| 13 MR. KNIGHTON: That is right, and it is being 14 reviewed. If it is not accepted, it is accepted on the 15 basis that they do not believe that it has the equivalent 16 degree of safety.
| |
| 17 MR. KERR: But reg. guides are presumably a method 18 of satisfying a regulation. Now nowhere does it say that I ,
| |
| 19 know of that the alternative has to have the same degree of 20 safety. It simply says it has to satisfy the regulation.
| |
| 21 MR. KNIGHTON: Exactly the same -- well, we are 22 using those terms interchangeably. The regulation requires 23 a level of safety.
| |
| 24 MR. KERR: Well, okay, in that sense, yes.
| |
| \> 25 MR. KNIGHTON: That is what we are saying. The ACE FEDERAL REPORTERS, INC.
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| . _ _,_ SD37 9700 Nationwide Coverme 800-336-6646
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| 9220 02 02 127 l nnrysimons 1 staff has identified theirs in the reg. guide, what they 2 interpret as an acceptable way of achieving that.
| |
| 3 MR. KERR: That is right.
| |
| 4 MR. KNIGHTON: The licensee come in and has to 5 offer his approach. He has every opportunity to have a 6 different approach. Now at various levels of NRR you have 7 to carry that and you find out whether this becomes the 8 -equivalent.
| |
| 9 MR. KERR: Okay. I just wanted to make sure that 10 they hadn't suddenly become requirements without my 11 realizing it.
| |
| 12 , MR. SINGH: If you don't have any questions, this O
| |
| k-) 13 concludes my presentation. Thank you.
| |
| 14 MR. KURTZ: Mr. Wylie, before we leave Mr. Singh's 15 issues, maybe we could go over a couple of the confirmatory 16 issues, unless you would like to do it afterwards, just to 17 clarify a couple of minor points.
| |
| 18 MR. WYLIE: Suppose you go ahead and do that then.
| |
| 19 MR. KURTZ: Roger, would you like to address 20 those?
| |
| 21 MR. MARTIN: We, too, are very familiar with Mr.
| |
| 22 Ebersole's items such as at junction boxes that would 23 collapse if not vented and if vented would have moisture. i l
| |
| 24 We have worked with the manufacturers in our construction
| |
| )
| |
| ; 25 procedures to develop splices or connectors that would be l
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| ACE. FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 800 336-6646 _
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| :9220 02 02- 128 h;rysimons1- humidity proof.-
| |
| 2 Yes, the consideration about a leak, a steam line 3 leak, we have provided temperature detectors which would 4 not require an operator to be present in that location-5 where in some remote place a line might crack. The 6 isolation valve that is close to that crack has been
| |
| . 7 provided,-and when the temperature sensor indicates thera 8 is an adverse condition it closes the valve.
| |
| 9 We have also taken a very conservative approach 4
| |
| l 10 assuming where line breaks might be occurring, and of
| |
| : 11. course you know there is some re-evaluation of the actual 12 rupture of a line. We have taken the classical approach 13 ,that has been in use in the past and assumed the most 14 conservative case, and if your line would rupture in that
| |
| . 15 particular cubicle, all the safety related equipment in 16 that cubicle are considered to be in that same environment.
| |
| 17 If there is no other way to provide for this, we l
| |
| 1 18 relocate the safety equipment in other areas. So that has 19 been very thoroughly investigated I believe.
| |
| 20 MR. EBERSOLE: All right. So if it wasn't 21 environmentally qualified you moved it.
| |
| 22 MR. MARTIN: That sometimes was the only 23 alternative.
| |
| i 24 MR. EBERSOLE: It is the easiest thing to do.
| |
| 1 j 25 MR. MARTIN: That is very true. Yes, that is ACE-FEDERAL REPORTERS, INC.
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| i
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| . . _ . , _ ..-. ..__ _.__202 3437g n_,,._,_,ya@3 wide coverase _ _ _ _800 336 6646
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| | |
| '9220 02 02 129 harysimons1 true.
| |
| 2 MR. EBERSOLE: And you are not going to deal with 3 this matter of trying to estimate leakage currents and so 4 forth. You are going to go to the ---
| |
| 5 MR. MARTIN: I think it is more realistic to 6 provide some other enclosure, a relocation, and use that
| |
| '7 approach.
| |
| 8 MR. EBERSOLE: Well thank you.
| |
| l 9 MR. KURTZ: The other issue we would like to
| |
| , 10 address was the computer code MULTIFLEX-3, and I am going
| |
| , 11 to have Mr. Kirk Troxler. address that issue.
| |
| 12 MR. TROXLER: MULTIFLEX-3 is a newer revision to i' - 13 the MULTIFLEX Code which has been used-tm the analysis of 14 plant structural motion, and we have used the new version 15 and now put the staff a little bit behind the eight ball in 16 that they have got to take a look at the changes that we 17 made to the newer version and ensure that those meet their 18 criteria for changes to codes.
| |
| 19 MR. KURTZ: Those are all.the comments we have, 20 sir.
| |
| 21 MR. WYLIE: Okay. Thank you.
| |
| 22 Mr. Wenzinger.
| |
| 23 MR. WENZINGER: Good morning, gentlemen.
| |
| 24 My name is Edward Wenzinger, and I am the Branch 25 Chief in NRC Region I who is responsible for the Beaver
| |
| ~
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 800 336-6646
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| | |
| B 9220 02 02 130 llharysimons1 valley Station, both units.
| |
| 2 I am responsible for NRC inspection and 3 enforcement at Beaver Valley. I have with me today other 4 members of the NRC Region I Staff and I would like to 5 introduce them, if I could, at this time.
| |
| -6 Each of you would you please stand up when I 7 introduce you.
| |
| 8 Mr. Tripp, who is the Section Chief for Beaver 9 Valley Units 1 and 2.
| |
| 10 Mr. Walton, who.is the Senior Resident Inspector 11 at Unit 2.
| |
| 12 Mr. Prividy, who is the Resident Inspector at Unit O 13 2.
| |
| 14 Mr. Troskoski, who is the Senior Resident at Unit 15 1.
| |
| 16 And Mrs. Asars, who is the Inspector at Unit 2.
| |
| 17 The purpose of this presentation is to provide a 18 basis for the current Region I staff conclusion that the
| |
| ~
| |
| 19 overall licensee performance during construction of Beaver 20 Valley Unit 2 has been satisfactory and compliance with NRC 21 requirements and safety objectives has been acceptable.
| |
| 22 This conclusion has been reached after 23 . consideration of certain key factors, namely, corporate 24 involvement by the licensee in construction activities, NRC 25 inspection of construction quality and licensee management ACE-FEDERAL REPORTERS, INC.
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| 202 347-3700 Nationwide Coverage 800 336-6646
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| l p 9220 02 02 131 p
| |
| l
| |
| ( barysimons 1 attention to NRC concerns.
| |
| 2 There is active corporate involvement in 3 construction activities as evidenced by weekly site visits 4 by the Chairman of the Board and the Vice President-Nuclear 5 Group is located on site.
| |
| 6 As a further point of introduction, I will 7 acquaint you with several general facts of Beaver Valley 8 Unit 2 and the related Region I inspection program.
| |
| 9 I will discuss for you inspection history, 10 enforcement record, regional construction team inspections, 11 independent non-destructive examinations, construction
| |
| ~
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| 12 deficiencies, allegations, systematic assessment of O
| |
| \# 13 -licensee performance and our inspection of licensee 14 preoperational testing.
| |
| 15 I will confine my remarks to the salient points of 16 these aspects of the inspection program. I had previously 17 planned to discuss several aspects of differences between 18 Units 1 and 2, but I think the licensee has done a fairly 19 decent job of doing that. So to keep the presentation a 20 little bit shorter, I will elilainate that part unless you 21 want to hear more.
| |
| 22 Duquesne Light is responsible for the design, 23 construction and operation of Beaver Valley Unit 2. Their 24 construction permit was issued on May 3rd, 1974. Stone and
| |
| \'' 25 Webster Engineering Corporation serves as the ACE-FEDERAL REPORTERS, INC.
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| 202 347. moi) Nmfrenwide @ overage 800 336 6646
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| 1
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| ~9220 02 02 132 l
| |
| (' 1 A-);crysimons 1 architect / engineer-and the construction manager.
| |
| 2 The Region I inspection program is performed by 3 both resident and region-based inspectors who obtain 4 information through direct observation in the field, 5 personnel interviews and review of procedures and records 6 to determine whether construction and installation of 7 ' safety related structures, systems and components meet 8 applicable requirements.
| |
| 9 Since August of 1981 a senior resident inspector, 10 Mr. Walton, has been essigned to Beaver Valley Unit 2.
| |
| 11 A second resident inspector, Mr. Prividy was 12 assigned in October of 1984.
| |
| () 13 In September of '84 the Unit 1 senior resident 14 inspector, Mr. Troskoski, was dedicated on a part-time 15 basis to follow the preoperational testing program.
| |
| 16 (Slide.)
| |
| 17 Inspection history can be traced from the initial 18 inspection of July 11, 1972 until the present time during 19 which approximately 130 inspections have been conducted.
| |
| 20 Region I inspections monitored activities including soil 21 and foundation, concrete work, safety related structures, 22 piping, welding, electrical activities, safety related 23 mechanical components and instrumentation. .
| |
| 24 The resident inspector's office was established on i 25 site in August 1981. Approximately 12,000 direct 4
| |
| ACE. FEDERAL REPORTERS, INC.
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| - - -_-_ - __ . __ _ _202 347 3700 _ , _ ,
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| Nationgide Coverage __ _ 800 336 _6646
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| 1 9220 02 02 133 ew i
| |
| ( hcrysimons 1 inspection hours have been devoted to Beaver Valley Unit 2 2. This level of inspection effort is more than for other 1 3 facilities at a similar stage of construction and there are 4 several reasons for that.
| |
| 5 This plant has been under construction for more 6 than 10 years and we have had a resident inspector present 7 for a longer period than at the other sites. At sites such 8 as Millstone 3 there have been about 6700 hours of 9 inspection. At Nine Mile Point about 8000 and at Hope 10 Creek nearly 8000.
| |
| 11 The NRC inspection of licensee's preoperational 12 testing program was begun in January of this year.
| |
| 13 Currently about half of their systems have been turned over 14 for testing which indicates that a substantial amount of 15 inspection activity is still to be performed.
| |
| 16 The inspection program uses inspection and 17 enforcement measure to promote adherence to regulatory 18 requirements, to reduce repeated non-conformances and 19 encourage self-identification and correction of non-20 conformances.
| |
| 21 Notices of violations have been issued when they 22 have been necessary. Sixty-six non-conforming conditions 23 as opposed to 65, which was in the text that we sent to you 24 by the way, have been identified for Beaver Valley Unit 2.
| |
| 25 This enforcement data compares very favorably with that of ACE-FEDERAL REPORTERS, INC.
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| _ l 202-347-3700 _ _ NationwideCoyerqp _ ___ 800 336-6646
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| | |
| ( ~
| |
| t 9220 02 02 134 narysimons 1 four other plants at a similar point in construction, 2- especially in light of the number of inspection hours that 3 have b,een spent on this plant.
| |
| 4 The number of non-conforming at other plants, Unit 5 3 at Millstone had 40 such events, Nine Mile Point 2 had 4
| |
| 6 64, Hope Creek had 58 and Shoreham had 75.
| |
| - 7 i. There have been no escalated enforcement issues, 8 .nor are there any major outstanding enforcement items at s A 9 ' Beaver Valley Unit 2 at the present time.
| |
| 10 (Slide.)
| |
| 11 Two regional construction team inspections have n
| |
| 12 been conducted. These inspections provide a more in-depth 13 assessment of construction quality. The team is a multi-14 disciplinary team and conducts a coordinated inspection of 15 various functional areas to examine program effectiveness, 16 The first inspection was conducted in April 1983.
| |
| 17 One weakness identtfied in this inspection was design 1
| |
| 18 control. This design control weakness was in the engineer 19 support area and was a key contributor to the cause of the 20 engineering construction interface problems that they 21 experienced.
| |
| 22 The second team inspection was conducted in March
| |
| )
| |
| 23 of 1985. While no major hardware problems were identified 24 an a result of this inspection, there were lingering
| |
| ; s
| |
| ''' 25 problems that persisted in the engineering construction C ,'
| |
| ACE-FEDERAL RE?ORTERS, INC.
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| 202 M7.279 ' ' Nationwide Coverage 800 336-6646
| |
| | |
| l l
| |
| l I
| |
| 9220 02 02 135 l (om,2Orysimons 1 interface for electrical activities.
| |
| 2 This conclusion was reached during the inspection 3 when certain cable pulling and electrical termination 4 procedures were conducted improperly.
| |
| 5 MR. KERR: What is the meaning of engineering 6 construction interface problems? Does that mean that the 7 people who were building it weren't building it the way the 8 engineers designed it?
| |
| 9 MR. WENZINGER: That is correct, and the principal 10 reason was confusion in the drawings as to how it ought to 11 be built.
| |
| 12 MR. KERR: Thank you.
| |
| () 13 MR. WENZINGER: The inspection, that is the one in 14 March of '85, did note that the licensee had made 15 significant overall progress in improving this interface 16 problem. They did improve drawings in the construction and 17 inspection areas. They placed a larger number of engineers 18 in the field to help resolve the problems as they arose, 19 and the put additional key experienced engineers at the 20 site monitoring this work.
| |
| 21 MR. WYLIE: Before you leave that one, what is that 22 last one? What is the lingering problems in the electrical 23 construction interface?
| |
| 24 MR. WENZINGER: Glenn, I wonder if you might 25 answer that, please.
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
| |
| | |
| l 9220 02 02 136 l narysimons 1 MR. WALTON: The electrical issues, a lot of them 2 go back to the compliance with the Reg. Guide 1.75 in 3 regards to separation or the need to meet the reg. guide 4 criteria. Some of the others are unsupported cable 5 lengths, regarding vertical cable in tray, tray to tray, 6 between buildings that are seismic, the need to support the 7 cable and/or the raceway, the hilti bolts, torquing, 8 retorqueing and the case where they may have been taken 9 down for construction, and then shims under base plates on 10 electrical.
| |
| 11 MR. WYLIE: Thank you.
| |
| 12 (Slide.)
| |
| (]'
| |
| 13 MR. WENZINGER: Three independent non-destructive 14 evaluation verifications by NRC Region I have been 15 conducted using the region's mobile NDE laboratory.
| |
| 16 The first inspection was in July of 1981 at the 17 B&W facility in Mount Vernon, Indiana. The examinations 18 were conducted on selected welds and base materials on the 19 neutron shield tank. They examined thicknesses, 20 laminations and used magnetic particle and radiographic 21 examinations.
| |
| 22 All results were acceptable. The radiographic 23 examination did uncover minor inclusions on two welds.
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| 24 However, they were considered acceptable.
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| m m7
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| \/ 25 The second and third inspections were conducted at ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide CovGm3 800-336-6646
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| 9220 02 02 137 narysimons 1 the site in February of 1982 and September of 1984. Both 2 of these inspections were conducted to provide 3 representative samples of piping systems, components, pipe 4 sizes, materials and ASME Class 1, 2 and 3 shop and field 5 welds.
| |
| 6 The items selected were previously accepted by the 7 licensee based on vendor, shop and onsite OA records. The 8 results of both inspections showed good correlation with 9 licensee's determinationc. All items were found 10 acceptable.
| |
| 11 Especially noteworthy was the records that the 12 licensee kept. They were quite complete.
| |
| p b 13 (Slide.)
| |
| 14 Significant deficiencies in design and 15 construction as defined in 1C CFR 50.55(e) are required to 16 be reported to the NRC. Licensee management attention has 17 been devoted to this reporting activity and the licensee 18 has been responsive to our requirements.
| |
| 19 As of September 1985 the licensee reported 62 20 significant deficiencies of which 48 are resolved, that is 21 they have either been fixed or they have justified what 22 they have done by analysis, and 14 remain outstanding. I 23 The number and nature of these deficiencies are 24 comparable to most other construction sites. For example, l i :
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| \ ''
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| 25 at Nine Mile 2 they had 117, at Millstone 3 they had 58 and l
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| l l
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| ACE FEDERAL REPORTERS, INC.
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| K@D374700 Nationwide Covercn3 800-336-6646 l
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| 9220 02 02 138 l bcrysimons 1 at Hope Creek there were 82.
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| ! 2 The majority of the reported deficiencies for 3 Beaver Valley Unit 2 have involved problems with vendor 4 supplied items. A good example of this would be two ,
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| 5 deficiencies concerning poor workmanship practices found in 6 factory installed wiring for 40-volt motor control centers 7 and the m,ain control board.
| |
| 8 The site quality group have reported specific ;
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| 9 instances of chaffed insulation on switchboard wiring, bent 10 lugs and excessive gaps between terminal lugs and wiring 11 insulation.
| |
| ; 12 The licensee notified Region I appropriately 13 concerning both deficiencies and performed the necessary 14 rework, repair and inspection to correct these
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| ?7 deficiencies.
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| i 16 Region I then inspected the sampling of the .
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| 1 17 reworked items before closing these reports.
| |
| ; 18 MR. EBERSOLE: May I ask a question?
| |
| '19 MR. WENZINGER: Sure.
| |
| 20 MR. EBERSOLE: Did you find any cases where the 21 field took it upon theuselves to make a unilateral decision 22 to put in terminal boxes of wha'tever special requirements l 23 they chose in lieu of making connections right into 24 hermetically sealed equipment? +
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| 4 25 MR. WENZINGER: Not that I am aware of.
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| l
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| - ACE-FEDERAL REPORTERS, INC.
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| __ , _.- , _ _ ,_. 202-347 3700 _ _ _ , . Nationwide Coverage _ __ .__800-336-6646 _ _ , _ _
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| 9220 02 02 139 n
| |
| N._2:arysimons 1 MR. EBERSOLE: I see. This has been one of the 2 plagues.of the business where they find it difficult to 3 make the connection in the actual equipment and interpose 4 another box to make the connection and then it is an 5 unqualified box. Have you found no cases of that?
| |
| 6 MR. WENZINGER: No, sir.
| |
| 7 MR. EBERSOLE: Thank you. <
| |
| 8 (Slide.)
| |
| 9 MR. WENZINGER: Allegations received by NRC Region 10 I address both safety related and non-safety related 11 areas. Each allegation is reviewed by regional management 12 and appropriate follow-up is based on the potential safety e
| |
| km) 13 significance of each allegation.
| |
| 14 Region I records indicate that only seven 15 allegations have been received on Beaver Valley Unit 2 16 i project, that is allegations received by the NRC.
| |
| I 17 A portion of one allegation was substantiated 18 while six others could not be substantiated and there are 19 currently no open allegations. ;
| |
| 20 The low number of allegations can be attributed to l 21 .the high regard for quality by the construction, inspection I 22 and other project personnel.
| |
| 23 NRC inspectors in the March 1985 regional I
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| 24 construction team inspection interviewed approximately 20 r~%
| |
| k-[ 25 OC and 20 craft personnel selected at random and confirmed l
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| l ACE-FEDERAL REPORTERS, INC.
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| ._, 202-347-3700 Nationwide Coverage _
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| 800 335-6646 l
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| 9220 02 02 140 l' ..
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| (_.':crysimons 1 that workers do not feel inhibited from reporting quality 2 concerns to their management, and no additional allegations 3 were received during those interviews either.
| |
| 4 (Slide.)
| |
| 5 The systematic assessment of licensee performance 6 encompasses an integrated staff effort, which includes 7 review of licensee performance over either a 12 or possibly 8 an 18-month cycle.
| |
| 9 An analysis is performed with regard to the NRC 10 observed strong points and weaknesses of licensee 11 construction and quality assurance. The process serves to 12 identify those areas where licensee management should
| |
| ' ~'
| |
| 13 devote greater attention and to which greater NRC 14 inspection resources will be allocated.
| |
| 15 The systematic evaluation is prepared by Region I 16 with input from the resident inspectors, regional 17 inspectors, specialist inspectors, NRC staff and regional 18 management.
| |
| 19 Since the inception of this program the 20 performance of the licensee has been assessed five times.
| |
| 21 The first three SALP evaluations assessed the licensee 22 performance from March 1, 1980 through November 30, 1982.
| |
| 23 The performance during this period was either Category 1 or 24 2 in nearly all functional areas.'
| |
| '' 25 However, the fourth SALP identified a decline in ACE FEDERAL REPORTERS, INC.
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| 201 M9.3900 TMmwNh Caverage 800-336-6M6
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| 9220 02 02 141 y~s
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| (_,harysimons 1 the licensee's overall performance. The performance of 2 three areas, piping systems and supports, electrical power 3 supply and distribution and engineering construction 4 interface was given a Category 3 rating.
| |
| 5 Are you gentlemen familiar with our SALP rating 6 definitions?
| |
| 7 MR. KERR: Yes.
| |
| 8 (Other ACRS members nodding affirmatively.)
| |
| 9 MR. WENZINGER: Significant weaknesses in the 10 design and engineering effort was of most concern since it 11 represented the root cause of many of the most significant 12 project problems.
| |
| 13 Design documents were not receiving adequate 14 constructibility reviews before they were sent to the field 15 for implementation. A large number of design changes and 16 reinspections of piping supports were necessary because of 17 each kind of deficiency.
| |
| 18 The licensee responded to these concerns by taking 19 various initiatives. An engineering confirmation program 20 was initiated and other organizational changes were 21 initiated which helped to improve this problem.
| |
| 22 The fifth systematic assessment of licensee 23 performance is the most recent, and it assessed licensee 24 performance through March of this year. Improvement was 25 shown in all three areas that received Category 3 the last ACE = FEDERAL R5 PORTERS, INC.
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| 202 * '-3700 Nationwide Coverage 800-336-6646
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| | |
| l I
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| l 9220 02 02 142 i
| |
| (~T L isrysimons 1 time.- ,
| |
| i 2 The licensee initiatives implemented during this !
| |
| 3 assessment period were effective in improving perforr.ance 4 in those weak areas.
| |
| 5 Furthermore, the licensee developed project 6 mechanical and electrical plans to provide coordinated 7 solutions to the significant mechanical and electrical 8 items that had not yet been completed.
| |
| 9 It is evident that these plans are vitally needed 10 since some lingering construction interface problems still 11 existed in the electrical and I&C areas during.this period.
| |
| 12 Several meetings have been held between NRC 13 management staff and the licensee staff to review these 14 issues, particularly in the electrical and I&C area.
| |
| 15 MR. REMICK: Did the applicant challenge any of 16 the ratings on the SALP reports, any of the five SALP 17 reports?
| |
| 18 MR. WENZINGER: We have discussed all the ratings 19 at our management meetings and the ratings have not been 20 changed as a result of those discussions.
| |
| 21 MR. REMICK: But were they challenged?
| |
| 22 MR. WENZINGER: Well, it depends on what you mean 23 by challenge. -
| |
| 24 MR. REMICK: No formal request to change it.
| |
| 25 MR. WENZINGER: My recollection of that is no, ACE-FEDERAL REPORTERS, INC.
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| 202.fm.27n T&t@srt@CavTagg fRNhYbcF2B
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| 9220 02 02 143 g
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| C Agrysimons 1 there were none.
| |
| 2 MR. REMICK: Thank you.
| |
| 3 MR. WENZINGER: Preoperational testing has begun 4 recently, and as of September of 1985 about half of the 5 systems have been turned over to the startup group for 6 preoperational testing, but only a minimum amount of 7 testing has actually be conducted.
| |
| 8 Since September of 1984 the senior resident from 9 Unit 1 has been assigned on a part-time basis to follow 10 this preoperational testing.
| |
| 11 Region I does consider that the test program has 12 been satisfactorily started, and we have had several region-13 based inspections of the licensee's area of preoperational 14 testing. These inspections have demonstrated the 15 licensee's commitment to quality at the initiation of this 16 phase of the project's completion.
| |
| 17 (Slide.)
| |
| 18 The Region I staff concludes that the overall ,
| |
| l 19 licensee performance during construction of Beaver Valley 20 Unit 2 has'been satisfactory and compliance with NRC 21 requirements and safety objectiveu has been acceptable.
| |
| l 22 Our basis for this conclusion has been that there :
| |
| )
| |
| 23 is positive corporate corporate involvement in construction J 24 project activities. The licensee's Chairman of the Board, n/
| |
| '- 25 John Author, has visited the site weekly since 1984, and l
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| l l
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| ACE. FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coveryp _ 800-336-6646
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| 9220 02 02 144 marysimons 1 Mr. Carey devotes most of his time to this project and is 1
| |
| 2 located on site.
| |
| 3 Region 1 has a high degree of confidence in the 4 construction quality of Beaver Valley Unit 2, and this 5 conclusion is confirmed by the good results from three 6 inspections using our NDE mobile laboratory, very few l
| |
| 7 allegations and no significant problems that have come out 8 of our construction team inspections.
| |
| 9 We believe there is a high level of licensee 10 management attention to NRC concerns, and these concerns 11 are actively pursued to satisfactory resolution.
| |
| 12 Do you have any questions?
| |
| 13 MR. REMICK: I assume, ,since you didn't mention 14 it, that there was no IDVP for this' plant.
| |
| 15 MR. WENZINGER: No, sir.
| |
| 16 MR. REMICK: And how about an IDI?
| |
| 17 MR. WENZINGER: No, sir.
| |
| 18 MR. REMICK: Is there any reason why this as an 19 NTOL did not have one or the other?
| |
| 20 MR. WENZINGER: Yes, there is. Typically those 21 have been conducted a little bit later in the design and 22 construction. For example, Millstone 3, which is the one I 23 have the most recent knowledge of, has had an IDVP type of 24 inspection performed by Stone and Weoster several months
| |
| ''~# 25 ago, and they are schedule for fuel load in late November ACE-FEDERAL REPORTERS, INC.
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| men .
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| wenemwmu _ cmem
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| | |
| 9220 02 02 145 73
| |
| ( ,larysimons 1 of this year.
| |
| 2 MR. REMICK: Isn't that awfully late? Why would 3 you do it that way versus now if it was going to be done?
| |
| 4 MR. WENZINGER: Well, one of the reasons in the 5 case of Beaver Valley at least is that the work of Stone 6 and Webster has been examined in some detail by NRC and, 7 additionally, this inspection that was done on the 8 Millstone project which is also a Stone and Webster plant, 9 as you are probably aware. So it is basically inspection 10 of the architect / engineer's design process, and both 11 because of our previous NRC activities and because of the-12 internal audits that have been done by Stone and Webster, O
| |
| kJ 13 it has not been considered necessary, at least not to this 14 point.
| |
| 15 MR. REMICK: So the staff does not anticipate an 16 IDVP or encouraging the applicant to do an IDVP for Beaver 17 Valley 27 18 MR. WENZINGER: I can't speak for the NRR staff.
| |
| 19 I will let them speak for themselves.
| |
| 20 MR. KNIGHTON: There has been no request by the
| |
| -21 staff for them to do that. It is not a regulatory 22 requirement. I suspect it is mainly because this is the 23 second unit.
| |
| 24 MR. REMICK: Thank you.
| |
| 25 MR. KERR: Do you think there is a high ACE FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage _
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| 800-336 6646
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| 9220 02 02 146 O
| |
| C anrysimons 1 correlation between the number of inspection hours and the 2 quality of this plant?
| |
| 3 MR. WENZINGER: No.
| |
| 4 MR. WYLIE: Any other questions?
| |
| 5 (No response.)
| |
| 6 Does the staff have any comments?
| |
| 7 MR. KURTZ: No, we have no comments.
| |
| 8 MR. WYLIE: Well, suppose we break until 20 after 9 1 and resume then.
| |
| 10 MR. KURTZ: Lunch will be in the Aquacade Room, 11 and that is right off the main lobby.
| |
| 12- (Whereupon, at 12:20 p.m., the subcommittee 13 recessed, to reconvene at 1:20 p.m., the same day.)
| |
| 14 15 16 17 18 19 20 21 22 l
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| 23 1
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| 24 25 1
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| i ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 336-6646
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| | |
| ,m, i 1
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| '-J220 03 03 147 merysimons 1 AFTERNOON SESSION
| |
| , 2 (1: 20 p.m. )
| |
| 3 MR. WYLIE: The meeting will resume.
| |
| 4 MR. KURTZ: The next speaker will be Gene Ewing in 5 the area of quality assurance.
| |
| 6 (Slide presentation) 7 MR. EWING: Good afternoon. My name is Gene 8 Ewing. I am the manager of the Quality Assurance Unit.
| |
| ~
| |
| 9 Today, I would like to present an overview of quality 10 assurance / quality control.
| |
| 11 (Slide) 12 My presentation will include the three sub-13 headings shown on the agenda for quality assurance.
| |
| 14 As the Quality Assurance manager, I am responsible 15 for maintaining and managing the Duquesne Light Company 16 Quality Assurance Programs and am authorized to report 17 quality problems directly to any level of management 18 necessary to ensure corrective action.
| |
| 19 I report directly to the vice president of the 20 Nuclear Group and am responsible for directing the 21 activities of the Quality Assurance Unit.
| |
| 22 This unit administers the quality assurance and 23 quality control activities and the in-service inspection O 24 programs for both Beaver Valley units.
| |
| 25 The Duquesne Light Company as the owner and ACE-FEDERAL- REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| | |
| j 9220 03 03 148
| |
| \)
| |
| ''mtrysimons 1 operator of the two nuclear power units recognizes its 2 responsibility to operate these facilities with due regard 3 for public and plant safety.
| |
| 4 Our operations quality assurance program has 5 governed the continual safe and successful operation of 6 Beaver Valley Unit 1 since it began operations in 1976.
| |
| 7 Because we recognize a close correlation between safety and 8 plant quality, we abide by an ongoing program for_ quality 9 achievement and assurance in both the design, construction, 10 and the operation of our nuclear power facilities.
| |
| 11 Our design and construction and our operations 12 quality assurance programs define the requirements and 7s b 13 specify the responsibilities for implementing these 14 programs.
| |
| 15 The design, procurement, fabrication, and 16 construction of Beaver Valley Unit 2 has been carried out 17 in accordance with the Duquesne Light design and 18 construction quality assurance program.
| |
| 19 This program complies with the requirements shown 20 as Item 1 on this slide.
| |
| 21 (Slide) 22 I would like to point out that with few 23 exceptions, all contractors work under the Duquesne Light
| |
| - 24 design and construction OA program. Ninety days prior to 25 fuel loading, the Duquesne Light operations quality ACE FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800w336-6646
| |
| | |
| 220 03 03 149 marysimons 1 assurance program will be applied to Unit 2.
| |
| 2 This program complies with the requirements shown 3 as Item 2 on this slide.
| |
| 4 MR. REMICK: Would that be the same program?
| |
| 5 There won't be a Part B for Unit 2 and a Part A for Unit 17 6 MR. EWING: There may be some areas where we may 7 have to separate it as an appendix-type to distinguish 8 between the two units. But the primary program will be the 9 same.
| |
| 10 As I stated previously, this program has been 11 functioning for Unit 1 for about ten years. New and 7y 12 revised codes, standards, regulatory guides, and Ll 13 regulations are continually reviewed and incorporated into 14 the program as appropriate 15 Duquesne Light personnel are required to act in 16 strict accordance with the requirements of the Duquesne ,
| |
| 17 Light quality assurance programs , and management gives full 18 support to maintaining an ef fective quality program.
| |
| 19 Additionally, contractors who perform activities 20 affecting quality on safety-related items are required to 21 comply with the applicable requirements of our QA program.
| |
| 22 (Slide) 23 The organization of the Quality Assurance Unit is l
| |
| 24 shown on this slide.
| |
| (m)
| |
| V 25 The operating plant activities for Unit 1 are ACE-FEDERAL REPORTERS, INC. i 202-MW-WOO P# nfmirf h @rverage fTism l
| |
| | |
| 220 03 03 150 merysimons 1 monitored by the director of operations OA. This 2 department is presently staffed with 12 employees, all of 3 which have four-year college degrees.
| |
| 4 The support activities such as engineering, 5 construction, procurement, and administrative functions are 6 reviewed by the director of Engineering and Procurement 7 OA. This department is also staffed with 12 employees 8 having four-year college degrees.
| |
| 9 The nondestructive examination, pre-service and in-10 service inspection activities are the responsibility of the 11 director of Pre-Service and In-Service Inspection. This s 12 department is presently *staf fed with eight Duquesne Light 13 employees and is being supplemented with outside 14 consultants.
| |
| 15 Moving over to the far right, the quality control 16 activities for our operating plant, Beaver Valley Unit 1, 17 is the responsibility of the director of Operations Quality 18 Control. This department is presently staffed with 29
| |
| '19 employees.
| |
| 20 These four departments are permanent Duquesne 21 Light organizations which are staffed with Duquesne Light 22 Company employees.
| |
| 23 The quality control activities for the i l
| |
| (s 24 construction phase of Beaver Valley Unit 2 are the l
| |
| (_) l 25 responsibility of the director of Site Quality Control. ;
| |
| 1 l
| |
| ACE-FEDERAL REPORTERS, INC.
| |
| 202-349-3 3 0 R"atiowid?@rverase f37hf136-6646 i
| |
| | |
| 1220 03 03 151 mnrysimons 1 This is a temporary Duquesne Light organization which was 2 developed specifically to support the construction of Unit 3 2. Ninety days prior to fuel load, the activities of this 4 organization will be assumed by the Operations Quality 5 Control.
| |
| 6 The final Quality Assurance Unit organization 7 which will be established to support two operating units is 8 shown on this slide.
| |
| 9 (Slide) 10 It is anticipated that this organization will be 11 staffed with 100 permanent Duquesne Light enployees, and m
| |
| 12 this will be supplemented during outages with contractor or (G
| |
| 13 consultant personnel on an as-needed basis.
| |
| 14 It is projected that the present staff of 61 15 Duquesne Light employees will .txt increased to 92 during 16 1986, and the final complement of 100 personnel will be 17 reached in 1987.
| |
| 18 The Quality Assurance Unit is staffed with 19 competent individuals who have the experience and knowledge 20 necessary to ensure that the Duquesne Light Company quality 21 assurance program is ef fectively implemented and 22 main tained .
| |
| 23 There are presently over 500 man years of nuclear 24 industry experience in the Quality Assurance Unit. We
| |
| (~)
| |
| q,-
| |
| 25 presently have two individuals who have been or are ACE-FEDERAL REPORTERS, INC.
| |
| ?n?.t.171700 Narmnwide Coverane 800-136-6646
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| | |
| 220 03 03 152 marysimons 1 presently certified reactor operators.
| |
| 2 I'd like to clarify Mr. Sieber's statement this 3 morning. He said we had two active licenses. We only have
| |
| - 4 one active license at this time. One is currently 5 certified as a senior reactor operator on Beaver Valley 1.
| |
| 6 The second was licensed on the old Shipping Port plant.
| |
| 7 But that is not an active licence.
| |
| 8 (Slide) 9 The 61 Duquesne Light employees presently assigned 10 to the Quality Assurance Unit can be classified in the 11 following levels of management:
| |
| em 12 17 of these individuals are considered to be in U --
| |
| 13 supervisory positions; 23 are in engineering or auditing-14 type positions, and 21 are inspectors or technical 15 specialists. 39 of these employees, or 65 percent of the 16 organization, have one or more four-year college degrees, 17 and 16 employees have received an associate degree.
| |
| 18 MR. REMIC K: Does this include quality control as 19 well as quality assurance?
| |
| 20 MR. EWING: These figures include the Quality 21 Assurance and the Operations Quality Control Department.
| |
| 22 Those are the permanent Duquesne Light organizations. It 23 does not include the site quality control organization.
| |
| /''}
| |
| 'w.)
| |
| 24 MR. REMIC K: If it's possible to generalize -- and 25 maybe one can't -- where do you get your OC and QA people?
| |
| ACE-FEDERAL REPORTERS, INC.
| |
| 2D2147-1700 Nattenwide Coverage 800-3 M-6646
| |
| | |
| 20 03 03 153 marysimons 1 What do you look for? Are they primarily industrial 2 engineering types or is it such a mixture --
| |
| 3 MR. EWING: We have quite a mixture. We have the 4 engineering degree people; we have a couple with political 5 science degrees who have an associate degree from the local 6 college in NOA; we have an industrial engineer. It pretty 7 much covers the gamut. Chemistry is covered.
| |
| 8 So we try to maintain a variety so we have all 9 disciplines.
| |
| 10 In addition to this staff which provides support 11 to both units, there are presently about 370 temporary 12 personnel who are responsible to the director of Site 13 Quality Control for performing the quality control 14 activities for the construction phase of Unit 2.
| |
| 15 This number includes supervision, QC ongineering, 16 inspection, and clerical personnel necessary to support the 17 quality control activities of the Unit 2 project.
| |
| 18 (Slide) 19 One indication of our ability to implement and 20 maintain an ef fective quality assurance program is 21 reflected in the NRC' SALP report.
| |
| 22 this slide summarizes the results of the last two 23 SALP reports for Beaver Valley Unit 1. The most recent 24
| |
| ' N, Unit 1 SALP evaluation resulted in five functional areas V
| |
| 25 being rated as Category 1, and the remaining four ACE-FEDERAL REPORTERS, INC.
| |
| 2D2 347:3700 Nationwide _ Coverage 800_-33 & 6646 _
| |
| | |
| , 9220 03 03 154 !
| |
| U marysimons 1 functional areas received a Category 2 rating. !
| |
| 2 Based on this evaluation, the Unit 1 SALP 3 evaluation period was extended from a 12-month interval to 4 an 18-month interval . ,
| |
| 5 (Slide) 6 The next two slides summarize the results of the 7 last three SALP evaluations for Beaver Valley Unit 2. The 8 most recent evaluation resulted in three areas being rated 9 Categcry 1 and the remaining eight areas were rated 10 Category 2. These results are supportive of the fact that 11 Duquesne Light is constructing Unit 2 in a quality manner j3 12 and that both units will be operated in a manner to ensure V
| |
| 13 public and plant sa fe ty .
| |
| 14 The construction of Unit 2 has progressed with a 15 minimum of quality problems .
| |
| 16 MR. KERR: Excuse me, could I see the last slide 17 again, please?
| |
| 18 I guess it puzzles me a little. I'm not sure how 19 significant these things are, but it puzzles me a little 20 that there are not any "ones."
| |
| 21 MR. EWING: Well, that's only part of the slide.
| |
| 22 There is the other part of it. There are three Category is 23 and eight Category 2s.
| |
| 24 MR. KERR: You were just saving the best for the 25 last.
| |
| ACE-FEDERAL REPORTERS, INC.
| |
| 202 347-3700 Nationwide Coq _ 80 4336 6646
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| | |
| 220 03 03 155 mc ysimons 1 (Laughter) 2 MR. EWING: Unfortunately, we couldn' t get them 3 all on one slide.
| |
| 4 The abilitu of the Site Quality Control 5 organization to . spond to quality issues has been a strong 6 point of this pro,*ect. Some of the issues which have 7 required significar i efforts to resolve have been the 8 problem of vendor workmanship as it relates to electrical 9 wiring. This one was discussed earlier this morning.
| |
| 10 An extensive investigation was conducted of all 11 major electrical equipment suppliers and a program was 12 instituted for re-inspection and resolution of this item.
| |
| 13 Based on the results of this program, this item is now 14 closed.
| |
| 15 Another issue which required a major effort on the 16 part of the Site Quality Control Department was Regulatory 17 Guide 1.75, the electrical cable separation issue.
| |
| 18 A program was developed to perform. re-inspection 19 of installations to identify non-conforming conditions so 20 that an engineering evaluation could be performed to 21 resolve the identified non-conforming conditions. This 22 program is still ongoing.
| |
| 23 A third issue which has been given significant rw 24 management attention is the problem of errors in OC d
| |
| 25 inspectors' work. During the course of this project, ACE-FEDERAL REPORTERS, INC.
| |
| e n.su rsaceem cnanem
| |
| | |
| 220 03 03 156 m;rysimons 1 covering about nine years, three situations have occurred 2 in which a significant error was found in an inspector's 3 work. In each case, an extensive investigation was 4 conducted; an evaluation of the root cause of the problem 5 was established, and appropriate corrective action was 6 taken.
| |
| 7 In two of these instances, potential significant 8 deficiency reports were filed with the NRC, even though it 9 was subsequently established that these incidents had no 10 safety significance.
| |
| 11 An overall evaluation of our QC inspectors has 7-~y 12 shown competent and effective performance of their
| |
| + )
| |
| Q.J 13 responsibilities. This can be attributed to a centralized, 14 comprehensive training and certification program which is 15 administered by Duquesne Light for all of its inspectors.
| |
| 16 Exit interviews are conducted of all inspectors 17 leaving the site to ensure that any quality issues they may 18 have are addressed. No significant items have been 19 identified during these exits.
| |
| 20 The NRC has received very few allegations relating 21 to Beaver Valley 2, and none of them have been initiated by 22 a OC inspector.
| |
| 23 These positive aspects of the organization have (7 24 enabled us to maintain a relativel> low turnover rate for V
| |
| 25 our QC personnel.
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| J 220 03.03 157 d
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| mErysimons'l One final program I'd like to describe before I 2 conclude is our quality concern phone line. This program 3 was established nearly two years ago to provide a means for
| |
| ~4 all site personnel to report any quality concerns they
| |
| . 5 might have to an independent organization for follow-up.
| |
| 6 The individual may remain anonymous if he wishes. All 7 calls are received by the Quality Assurance Unit, they are 8 recorded, investigated, evaluated, and closed out.
| |
| 9 The number of concerns received by this method has 10 been small, which can be expected at this stage of the 11 project. As the project nears completion and staffing G
| |
| -) 12 reductions occur, it is expected that there will be 13 increased activity in this area.
| |
| 14 It is planned to give this program more visibility 15 as we approach the end of the project.
| |
| 16 In conclusion, compliance with the Duquesne Light 17 quality assurance program will provide assurance that the 18 . installed quality of the plant is maintained throughout its 19 life. That proper administrative controls are in effect at 20 all times, and that decisions related to the operation of 21 the plant are made at the proper level of responsibility 22 and with the necessary technical advice.
| |
| 23 Effective implementation of this program provides
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| - rx 24 -assurance that Beaver Valley Unit 2 has been constructed U
| |
| 25 and will be operated with a high degree of public and' plant ACE-FEDERAL REPORTERS, INC.
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| K@D37-9700 Nationwide Com 80433MM6
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| ..9220 03 03 158
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| \
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| > /merysimons I safety.
| |
| 2 That concludes my presentation. Any questions?
| |
| 3 MR. REMIC K: Is there a requested hearing for your 4 operating license?
| |
| 5 MR. KURTZ : This is an uncontested proceeding.
| |
| +
| |
| 6 MR. REMICK: It is uncontested.
| |
| 4 7 MR. KURTZ: Yes.
| |
| 8 MR. REMICK: I have another question. It's 9 obvious that you have gotten very good evaluations on your 10 QA program and you are to be complimented, and I hope that 11 means that there is quality in the plant.
| |
| ,- 12 But do you have any concrete evidence that the iD v 13 good OA program that apparently you t; ave has improved 14 quality in the plant? Is there any way to show it other 15 than satisfying your regulatory requirements? You have the 16 paper trail there, you got good reports. Is there any --
| |
| 17 MR. EWING: Well, I think our operating experience 18 has shown that. Unit I has a very good operating record 19 and, I think, Unit 2 has a good construction record. I 20 think quality is an attitude and as long as you can get 21 that attitude across to everyone, your quality problems 22 will be very few.
| |
| 23 MR. REMICK: And you feel that attitude does 24 exist.
| |
| : 25 MR. EWING: Ye s , I d o .
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Covemge 800-336-6646
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| 220 03 03 159 m:1rysimons 1 MR. REMICK: Did you have in the building of Unit 2 1 as formalized a OA program? Was it pretty well 3 established at that time or was it kind of a fledgling 4 program?
| |
| 5 MR. EWING: Well, that was the operations OA 6 program which was written for the operation of Unit 1.
| |
| 7 That has been refined and, I guess I would say, upgraded as 8 other requirements have come in. We feel it's been tested 9 very well and it's performed adequately.
| |
| 10 MR. KURTZ: The next speaker will be Mr. Tom 11 Burce, in the area of training.
| |
| ,r 3 12 MR. BURNS: Good afternoon. I'm Tom Burns,
| |
| ' .,)
| |
| 13 director of Operations Training, and I'll be discussing 14 training facilities and programs.
| |
| 15 (Slide presentation (
| |
| 16 At Duquesne Light Company we consider an effective 17 training program to be essential for achieving excellence 18 of nuclear operations. It's our policy to properly train 19 individuals in responsible positions to operate, maintain, 20 and manage our nuclear facilities.
| |
| 21 We have been developing and implementing training 22 programs for many years that meet or exceed our 23 requirements. Our programs routinely receive high ratings rm 24 from the NRC and INPO during audits, evaluations, and C
| |
| 25 inspections.
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| ACE-FEDERAL REPORTERS, INC.
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| 220 03 03 160 mcrysimons 1 Therefore, I'm very confident when I tell you that 2 our training programs and facilities are among the best of 3 any utility in the country today.
| |
| 4 Our commitment to training is evidenced by the 5 obvious investment in our Training Center and available 6 training tools provided to the staf f, including a plant-7 specific simulator -- Unit 1 -- and an I&C and electrical 8 training system.
| |
| 9 The Training Center provides -- this is addressing 10 a question that came up yesterday -- the Training Center 11 provides a total floor space of 42,000 square feet in the
| |
| ,s s 12 Training Building and 28,000 square feet in our Simulator L) 13 Building.
| |
| 14 A further indicator is our participation in the
| |
| ~
| |
| 15 INPO accreditation program and our ef forts to ensure the 16 industry goal is met by completion of the designated 17 programs by mid-1986. We have completed the job analysis 18 and submitted a self-evaluation report of the indicated 19 programs in the slide.
| |
| 20 (Slide) 21 As you can see, in July of 1984 we turned in three 22 programs consisting of the licensed, nonlicensed, and 23 license requal program.
| |
| 1 g-) 24 In July of 1985, this year, we submitted four more v
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| 25 programs, shift technical advisor, radiation protection j i
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| l ACE-FEDERAL REPORTERS, INC. ;
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| sib 347-3700 Nationwide CmHU3 800 336-6646
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| 220 03 03 161 merysimons 1 technician, chemist and I&C technician; and our schedule 2 for the following three programs ir May 1986, which will 3 include mechanical, electrical, and tech staff and 4 managers.
| |
| 5 MR. REMICK: On any of those, have you had the 6 accreditation team visit ye t?
| |
| 7 MR. BURNS: Yes, we have. We have had the 8 accreditation team visit on the first three programs. As a 9 matter of fact, my next statement covers that visit.
| |
| 10 During our first INPO accreditation visit , the 11 team was particularly impressed with our instructor f~. 12 development program, our instructor presentations , our O 13 training administrative manual, and our simulator 14 scenarios.
| |
| 15 Of course, along with the accreditation effort is 16 the implementation of the systematic approach to training.
| |
| 17 To support the SAT effort, the training section is now 18 staf fing a program development section.
| |
| 19 Also, in keeping with our effort to ensure only 20 the best courses are a part of Beaver Valley's training 21 programs, our thermo-dynamics course for licensed operators 22 has been evaluated by the American Council on Education and 23 has been recommended for three semester hours in nuclear l
| |
| 24 technology in the upper division baccalaureate category.
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| (m3
| |
| ' _/
| |
| 25 It is our intent to continue this evaluation process.
| |
| 1 1
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| ACE-FEDERAL REPORTERS, INC.
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| 202-349-3700 rawmictfncomrm 80 4336-6646 ;
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| (
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| J 220=03 03 ^ 162 i l
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| marysimons 1 (Slide) 2 I would now like to describe to you our initial 3 licensed operator training program and our licensed
| |
| '4 operator retraining program.
| |
| 5 The licensed operator training program consists of 6 six phases. Phase 1 consists of various theory courses 7 which prepare the trainee with a sound technical background 8 for understanding-plant systems and overall plant l 9 operations.
| |
| 10 Phase 2 consists of plant-specific system training 11 in the form of lecture series, evaluated by written 12 examinations, used to track comprehension and progress.
| |
| '13 Phase 3 consists of actual system tracing in-plant 14 and completion of procedure review followed by an oral 15 examination administered by a qualified instructor.who is 16 guided by a system qualification standard.
| |
| .17 Phase 4 consists of simulator training which is 18 interspersed throughout the program to allow hands-on 19 operations of various system control.s and culminating with 20 1r start-up certification in abnormal and emergency 21 operations.
| |
| 22 Phase 5 consists of on-shift training which is 23 also interspersed throughout the training program. The 24 trainee is assigned to an on-shif t program after qualifying 25 on secondary and primary systems to complete OJT watch-ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336 4646
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| 220 03 03 163 mcrysimons 1 standing qualifications.
| |
| 2 Towards the end of the program, he is assigned 3 three months on shif t as the extra operator.
| |
| 4 In Phase 6, trainees participate in instructor-led 5 review of technical subjects and are administered written 6 and oral examinations, including a third-party exam similar 7 to the NRC examination.
| |
| 8 (Slide) 9 This slide shows an overview of the training 10 program to give you an idea of how the various phases are 11 carried out.
| |
| ,y 12 You can see that simulator and on-shif t training L) 13 is scheduled out through the systems training to reinforce 14 what is learned in the classroom.
| |
| 15 This program has been very successful. Our 16 success rate is 88 percent.
| |
| 17 MR. REMIC K: Is that on first time or --
| |
| 18 MR. BURNS: That's the first time, yes, sir.
| |
| 19 MR. REMIC K: In other words, the first time the 20 people take the NRC exam 88 percent pass, or first-time --
| |
| 21 MR. BURNS: That is an average for the last five 22 classes.
| |
| 23 MR. REMICK: Okay.
| |
| ("; 24 MR. BURNS: The last five operator classes that we U
| |
| 25 put up for licensing.
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| E D37-3700 Nationwide Cog 800-336-6646
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| 220 03 03 164 mtrysimons 1 MR. REMIC K: Have there been any people of the 12 2 percent that subsequently were not licensed, or were they 3 all licensed subsequently?
| |
| 4 MR. BURNS: This includes people going up for a 5 second time, and they were counted within that class. If 6 they failed the first time, they were not included as a 7 pass.
| |
| 8 MR. REMICK: Well, I guess I'm not sure I 9 understand. The 88 percent includes people going up for a 10 second time examination.
| |
| 11 MR. BURNS: Thare are very few of those.
| |
| f\ 12 MR. REMICK: Very few. But the 88 percent' figure G
| |
| 13 does include them.
| |
| 14 MR. BURNS: We have two classes out of the last 15 five that were a hundred percent.
| |
| 16 MR. REMICK: I see.
| |
| 17 MR. BURNS: Individuals chosen to license on Unit 18 2 will be experienced licensed operators from Unit 1 or 19 individuals completing the initial training program and 20 Unit 2 cross-training program.
| |
| 21 All individuals presently plan to receive Unit 2 22 cross-training and license on Unit 2 or dual license are 23 experienced Unit 1 licensed ROs and SROs.
| |
| l r's 24 The Unit 2 cross-training program has been G
| |
| 25 developed to, as a minimum, meet the requirements of NUREG-ACE-FEDERAL REPP".TERS, INC.
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| 202-349-37ti) Nmionwide Coverage 800-336-6646
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| 220 03 03 165 merysimons 1 1021. In accordance with these guidelines, a system 2 dif ference analysis has been submitted to the NRC Region I 3 for determination of licensing and the examination process 4 to be followed.
| |
| 5 MR. REMICK: I'm not sure I understand. Are you 6 saying that somebody with a Unit 1 license would be trained 7 in the system difference, and then you would request a 8 waiver of other examination to be licensed on Unit 2. Is 9 that what it amounts to?
| |
| 10 MR. BURNS: Our options are with licensed 11 individuals, the NRC has the option of administering a full 7s 12 examination which includes theory and operational
| |
| (_)
| |
| 13 examinations down to a systems difference examination and a 14 plant walk-through for the second unit.
| |
| 15 We are at this time requesting, we have requested 16 of Region I to give us a waiver on the operational part of 17 the exam and the theory exam for our licensed experienced 18 personnel.
| |
| 19 MR. REMICK: I see. And then they would hold a 20 license for both Unit 1 and Unit 2.
| |
| 21 MR. BURNS: Well, we have had a preliminary 22 meeting with Region I a '.d right now we are looking at 23 licensing the operators on either Unit 1 or Unit 2. We are eS 24 looking at dual licensing experienced supervisors.
| |
| V 25 That decision has not been made as of yet. We ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 __
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| Nationwide CoGQp _
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| 800-336-6646
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| 9220 03 03 166 n
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| marysimons 1 have an operational characteristics dif ference analysis 2 vhich we will be submitting to Region I very shortly, and 3 we tentatively set up another meeting for January to 4 discuss the final licensing.
| |
| 5 MR. REMICK: Would you propose that whatever
| |
| ~
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| 6 licensing they must take for Unit 2, would they have the 7 walk-around portion of that, or would that be waived?
| |
| 8 MR. BURNS: It's my indication from what I_have 9 heard from Region I right now that a walk-through would be 10 included with the examination.
| |
| 11 MR. REMICK: Is that what you proposed, or --
| |
| 12 MR. BURNS: Yes.
| |
| O 13 MR. REMICK: It is.
| |
| 14 MR. B URNS: We requested a waiver on the theory
| |
| . 15 and the operational exam, which is the simulator 16 examination.
| |
| 17 MR. REMICK: I see.
| |
| 18 MR. KERR: I wasn't quite certain that I 19 understood what you were requesting in terms of dual 20 licensing. At this point you are only requesting dual l
| |
| 21 licenses for people at the SRO level or other supervisory 22 levels? ,
| |
| 23 MR. BURNS: The SRO level experienced, yes.
| |
| 24 MR. REMICK: How about, although they ars not 25 licensed, how would you handle STAS? Would there be one ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-33t,-6646
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| l 1
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| ,9220 03 03 167
| |
| ('')marysimons 1 STA for both units on shift?
| |
| 2 MR. BURNS: Yes , one STA for both units.
| |
| 3 The license retraining program is designed to !
| |
| 4 ensure licensed personnel remain competent to operate in a 5 safe, reliable, and efficient manner under normal, 6 abnormal, and emergency conditions.
| |
| 7 (Slide) 8 This program is conducted continuously for 24 9 months and is followed by successive 24-month programs.
| |
| 10 Each program is comprised of two retraining cycles one year 11 in length.
| |
| 12 (Slide)
| |
| /.")
| |
| Lj 13 License retraining is conducted in five phases of 14 instructions and evaluation. Phase 1 consists of the 15 annual written examination, modeled in scope and style to 16 the NRC requalification examination.
| |
| 17 Phase 2 consists of formal classroom training, 18 based in part on the results of the annual examination. It 19 is also based on current industry events, operations 20 feedback, and required subject reviews.
| |
| 21 This phase is presented in six modules of 22 instruction repeated six times to accomodate the operating 23 schedule.
| |
| ,s 24 MR. REMICK: You have six shifcs, then?
| |
| N.]
| |
| 25 MR. BURNS: We have five shifts. We operate five ACE-FEDERAL REPORTERS, INC.
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| s 202-347 3700 ,_ _ _ Nationwide Coverage _ 800-336-6646
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| ,,9220 03 03 168
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| ()
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| ' mcrysimons 1 shifts. We run the retraining program for each shift, plus 2 one for non-shift and make-ups.
| |
| 3 MR. REMIC K: I see.
| |
| 4 MR. BURNS: Individuals that might have missed --
| |
| 5 MR. REMIC K: - And how long would these modules run?
| |
| 6 MR. BURNS: These modules are three days in 7 length.
| |
| 8 MR. REMICK: So what percentage of time would you 9 expect your licensed personnel to be spending in continuing 10 training or requalification training?
| |
| 11 M R. BURNS: Our licensed people spend 18 days of
| |
| - 12 classroom. annually, plus simulator time.
| |
| \_/
| |
| 13 MR. REMIC K: That's not a very large percentage, 14 is it, of time?
| |
| 15 MR. BURNS: That is just.the classroom phase.
| |
| 16 l This year, we have scheduled eight days of simulator 17 training coming up the next cycle, plus we have -- I'll be 18 describing some other things that we do along with the 19 classroolu.
| |
| 20 MR. REMICK: Do you have any feeling for what 21 percentage it works out that they spend in continuing or 22 regualification training? Have you thought of it that way?
| |
| 23 MR. BURNS: No. I can tell you the number of days
| |
| - 24 and the number of hours and so forth, annually, that an i
| |
| %)
| |
| 25 individual does that.
| |
| ACE-FEDERAL REPORTERS, INC.
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| 2024 47-3700 Nationwide Coverage 800 336-6646
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| l 1
| |
| I 9220'03 03 169 l h arysimons m 1 MR. REMICK: The days would help.
| |
| 2 MR. BURNS: Well, each individual spends 18 days 3 of classroom annually, plus simulator training. This cycle
| |
| -4 coming up, we have eight days scheduled. He has individual 5 study assignments to do which I will be discussing in a 6 second.
| |
| 7 MR. KERR: In your view, is requalification t
| |
| 8 valuable?
| |
| 9 MR. BURNS: Pardon me, sir?
| |
| 10 ,
| |
| MR. KERR: In your view, is requalification
| |
| - 11 training valuable?
| |
| 12 MR. BURNS: Yes, it is. It's very valuable.
| |
| 13 Phase 3 consists of plant manipulation training 14 which is accomplished on the Unit 1 class-specific 15 simula tor. This training meets and exceeds the 16 -requirements of NUREG-0737.
| |
| 17 Phase 4 consists of review and self-study of 18 significant operating experience reports, incident reports, 19 design changes , and procedure review.
| |
| 20 Phase 5 consists of performance evaluation, which 21 is a combination of performance ratings as observed during
| |
| .22 simulator training and actual performance on the job.
| |
| 23 As a part of the accreditation effort, this s: 24 program has been evaluated by the INPO accreditation team.
| |
| . :2 5 Thers. were no concerns or recommendations noted.
| |
| ACE-FEDERAL REPORTERS, INC.
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| t_ 202-347 3700 Nationwide Coverage 800 3364646 __ ,_
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| 9220 03 03 170
| |
| 'A S- marysimons 1 MR. REMIC K: I thought you were going to give me 2 the bottom line number of days for all five phases in 3 requalification on the average.
| |
| 4 MR. BURNS: Okay. Phase 2, the formal classroom 5 training , is eight days -- I'm sorry, 18 days. The phase 3 6 simulator training for this year coming up is eight days.
| |
| 7 Phase 4 is a monthly assignment that an individual 8 gets, and Phase 5 is continuous in the control room on the 9 job and then during his simulator training.
| |
| 10 I guess the bottom line is, there is 18 days of 11 classroom, plus the eight days of simulator.
| |
| 12 MR. REMICK: Is the annual written exam done in O' 13 one of those days?
| |
| 14 MR. BURNS: That is done in the last part of the 15 18th day.
| |
| 16 MR. REMICK: I see. So you are at least somewhere 17 above ten percent, probably more like 14,15 percent.
| |
| 18 MR. BURNS: Yes. Now, that is only license 19 retraining. Attached to the license retraining modules, we 4
| |
| 20 do fire brigade training, first-aid training. These are 21 extra days. EPP training, so on and so forth.
| |
| 22 MR. REMICK: I see.
| |
| 23 MR. BURNS: That's additional training outside the 24 scope of license retraining.
| |
| U,_s 25 MR. REMICK: I see.
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| ACE-FEDERAL REPORTERS, INC.
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| , , . . - - . _ _ _ -347-3700_ _ _ - _ _ _ _ _ _
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| | |
| . 9220 03'03 171 O" mcrys'imons .1 MR. CAREY: I'd like to make a comment, Dr.
| |
| 2 Remick. Every time I'm looking for someone who isn't 3 working in the control room, they tell me he is in 4 training.
| |
| -5 (Laughte r) 6 (Slide) 7 MR. BURNS: As you observed yesterday, we have in 8 place a Beaver Valley Unit 1 plant-specific simulator which -
| |
| 9 meets and exceeds the requirements of ANS 3.5 and Reg Guide 10 1.149. We began training on our simulator in February of 11 this year as planned, and have completed 2,625 hours of
| |
| .; 12 successful training as scheduled. This reflects an
| |
| ~O 13 availability of 99 percent.
| |
| 14 The simulator has proven to be an invaluable
| |
| -15 training tool and has t'eceived excellent feedback comments 16 from our experienced operators , our operator trainees , and 17 NRC licensing personnel who have conducted operational 18 exams. , ,
| |
| 19 Also, to ensure the simulator maintains this type ,
| |
| 20 of training value, we have in place all required 21 administrative procedures to track plant design changes and 22 update simulator hardware and software.
| |
| 23 (Slide) 24 At this time, I would like to briefly discuss an
| |
| ,O overview of a selected number of our non licensed programs.
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| 25 ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800-336-6646
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| . - - - , . . ~ .
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| c__-. - - _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
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| '9220 03 03 172
| |
| .(
| |
| ctrysimons 1 MR. RENICK: Before you go on to that, are you up 2 to date on the .rimulator with all plant changes in Unit.1 l 3 to date? 'Or do .you have a backlog of modifications on the 4 simulator?
| |
| ~
| |
| 5 .MR. BURNS: We have changes to make. We are not-6 greatli .ac klogged . We just completed a design change of 7 the new steam generator blow-down system in-Unit 1.- We 8 don't have those switches on the bench board yet.
| |
| 9 MR. REMICK: Do you have any plans to use the i 10 simulator for. your I&C training program? I 11 MR. BURNS: For I&C? For I&C technicians?
| |
| 12 MR. REMICK: Yes, I&C technicians.
| |
| ( ,
| |
| 13 MR. BURNS: Not at this time. The I&C-technicians l
| |
| l 14 have their own site-specific I&C simulator, which simulates )
| |
| 15 temperature flow, pressure, and level. ,
| |
| 16 MR. REMICK: Some people use the simulator so 17 people know exactly where the instrumentation is in the 13 control room and so forth. I assume it's your I&C 19 technicians that do maintenance on your --
| |
| t.
| |
| 20 MR. BURNS: That is correct.
| |
| 21 MR.-REMICK: And some people use the simulator to 22 give them actual experience where things will be located 23 and the walk-through procedures, and so forth, so that they-24 are f amiliar before going into --
| |
| 0 25 MR. BURNS: That's a possibility, yes, cir.
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| ACE FEDERAL REPORTERS, INC.
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| Nationwide Coverase 800-336 4 646
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| | |
| /-,220 9 03 03 173 I
| |
| '')mtrysimons 1 (Slide) 2 General employee training at Beaver Valley 3 consists of station orientation which provides instruction 4 on industrial, radiological, and fire safety, security, and 5 quality assurance.
| |
| 6 (Slide) 7 Radiation worker training provides the background 8 information and practical experience to allow individuals 9 to perform their job duties safely in the work place where 10 radiological hazards may exist.
| |
| 11 Our program was one of the first to be evaluated
| |
| , 12 and incorporated into the INPO standarditation program.
| |
| ('~' )
| |
| 13 General employee refresher training is required 14 for all employees annually.
| |
| 15 Our radiation technician training program consists 16 of academic and practical instruction in a formal classroom 17 setting and actual in-plant proficiency demonstrations.
| |
| 18 This training enables the technician to employ proper 19 radiological controls during periods of maintenance, 20 testing, and operations.
| |
| 21 The course is approximately 45 weeks in length and 22 provides health physics related topics and basic plant 23 system knowledge, along with the study of emergency and 24 casualty procedures. Also incorporated into this program (s) 25 'is an in-depth review and formal check-of f on radiological i
| |
| ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 800-336-6646
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| l 1
| |
| 220 03 03 174 merysimons 1 control manual procedures which is dispersed accordinagly 2 throughout the program.
| |
| 3 Program implementation is supplemented by the 4 radiological operations staff who assist with the in-plant 5 practice and procedure training.
| |
| 6 Concerning this program, our most recent NRC 7 inspection of this training area stated, "The licensee's 8 strength in the radiation technician program was 9 demonstrated by the development and ef fective 10 implementation of their radiation technician training and 11 continuing training programs."
| |
| 7s 12 MR. REMIC K: Does this have a continuing training
| |
| '( ) 13 aspect to it?
| |
| 14 MR. BURNS: Yes.
| |
| 15 MR. REMICK: It does. And how about --
| |
| 16 MR. BURNS: We have continuing training for 17 licensed operators, nonlicensed operators, STAS, chemists, 18 rad techs, and maintenance.
| |
| 19 MR. REMICK: You mentioned the check-off on 20 procedures. Is that a formalized on-the-job-training type 21 of thing with call cards --
| |
| 22 MR. BURNS: Yes.,
| |
| [
| |
| 23 MR. REMICK: -- and somebody signing of f, and so i 24 forth.
| |
| S J
| |
| ( 25 MR. BURNS: Yes.
| |
| - ACE-FEDERAL REPORTERS, INC.
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| e K%PJ7-Ei2 Nationwide CovGUB 800-336-6646 .
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| | |
| I i
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| 1
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| '9220 03-03 175 ,
| |
| D''y )
| |
| .(smarysimons-1 (Slide) i i
| |
| 2 Training for station maintenance personnel is l 3 conducted in three distinct levels of instruction.
| |
| 4 Maintenance orientation training is designated -- excuse 5 me. t 6 . Maintenance orientation training is designed to 7 provide newly-assigned maintenance workers with 8 instructions and general plant lay-out in various plant 9 systems.
| |
| 10 This program also addresses the specifics of 11 maintenance and operations administrative procedures. This 12 enables the workers to identify the rules and practices
| |
| -15 , affecting their duties and responsibilities.
| |
| 14 The general maintenance training program is 15 designed to provide maintenance workers with generic basic 16 instructions concerning topics such as personal and fire 17 safety, basic and advance. rigging, measurement tools, and
| |
| '18 basic lubrication, just to name a few.
| |
| 19 Specific maintenance training is separated into 20 topics particular to each maintenance section, I&C, 21 mechanical, and electrical. This program is designed to 22 build and improve skills necessary to, ensure routine and
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| , 23 emergency maintenance at the station is performed ccrrectly 24 and efficiently.
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| O 25 Training for each discipline provides technically-ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700
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| * Nationwide Coverage M336-6646
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| ~9220 03 03 176
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| { i
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| ?--marysimons-l related classroom instruction, hands-on laboratory 2 sessions , and a structured in-plant OJT program. Each 3 discipline has a dedicated instructor and classroom 4 laboratory area.
| |
| 5 Specific training for the I&C technician includes 6 basic _and advanced training on repair and installation of 7 process and control instrumentation.
| |
| 8 For the mechanic, basic and advanced training on 9 the repair and installation of various plant system 10 components such as pumps and valves, and for the 11 electrician, basic and advanced training in the repair and 12 installation of station system electrical components such 13 as motor-operated valves and circuit breakers.
| |
| 14 In conclusion, I would like to reaffirm that we 15 fully recognize the importance of providing good training 16 programs and are dedicated to that. effort. Thank you. ,
| |
| 17 MR. REMICK: To what extent did you have., ,
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| 18 formalized and systematic and performance-based training of 19 rad tech, your electrical-mechanical maintenance, your I&C 20 before the- decision to go for accreditation? What has been 21 your history here in the past?
| |
| 22 MR. BURNS: We have found the f urthest we are on 23 the SAT is with our licensed and nonlicensed operator 24 program, and we have found that there were very few areas O 25 that we did not already cover.
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 ' ationwideCoverage 800 336-6646
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| 9220 03 03 177 tO u-mcrysimons 1 Our practice in developing --
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| 2 MR. REMIC K: I'm talking maintenance , maintenance 3 now, and I&C and rad tech.
| |
| 4 MR. BURNS: Radiation technician is the same way.
| |
| 5 We were very close to the job analysis. And the I&C 6 technician, looking at the initial requirements to meet the 7 job requirements for I&C second class or first class, and 8 along with the programs that we do within the training 9 section, we are not that far off.
| |
| 10 We have made a vast improvement in our OJT 11 program. That is where we did the most work and are 12 continuing along those lines.
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| C'
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| 'J 13 MR. REMIC K: Earlier you said that your training 14 programs were the best or one of the best in the country, 15 and I congratulate you on that assuming it's true.
| |
| 16 But I couldn' t help but notice that you filed your 17 self-evaluation report in the licensed area over a year 18 ago, and you did not mention any programs were accredited.
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| 19 So you must have had some things af ter that point that you 20 had to still do.
| |
| 21 MR. BURNS: We did have some items that we had to 22 take care of , upgrading our on-the-job-training check list l 23 to agree with the job analysis for the nonlicensed and 24 licensed operator. However, there weren' t that many for O 25 the licensed operator that were not already covered between ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 33M646
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| 9220 03 03 178
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| (')
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| \ 'marysimons 1 our simulator training and on-shift program.
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| 2 There were some other areas. I think to answer 3 your question as to the length of time, we have submitted
| |
| -4 our response to INPO and we expect to be scheduled the end 5 of NovemberE for our visit before the Board.
| |
| 6 We are doing our complete accreditation process in-7 house. We are doing it ourselves. And after our visit, we 8 did have to divert some of our manpower over to performing 9 some of the required items for submitting and completing 10 the self-evaluation reports for the other areas.
| |
| 11 Now we are, as I said, we are expecting to have 12 our visit within a month for the first three programs.
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| .O
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| (_/
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| 13 MR. REMICK: Have you undergone any of the NRC-14 administered requalification examinations at Beaver Valley?
| |
| 15 MR. BURNS: No, we have not.
| |
| 16 MR. REMIC K: You have not. .
| |
| 17 MR. BURNS: Any other questions? Thank you.
| |
| 18 MR. KURTZ: The next speaker will be Mr. Ron 15 Fedin, decay heat removal cold shutdown.
| |
| 20 (Slide presentation) 21 MR. FEDIN: Good afternoon. My n ame is Ron Fedin ,
| |
| 22 I'm a senior project engineer for Duquesne Light.
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| 23 (Slide) 24 The safe shutdown design basis for Beaver Valley 25 Unit 2 is to provide the capability to bring the plant to ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverage 800 336-6646
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| ,.9220 03 03 179
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| ''ntrysimons I hot stand-by following any design basis event.
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| 2 Also hot stand-by is the safe shutdown design 3 basis, Duquesne Light has upgraded the Beaver Valley Unit 2 4 plant design to facilitate reaching cold shutdown 5 conditions following safe shutdown earthquake , loss of of f-6 site power, and any single active failure.
| |
| 7 The Beaver Valley Unit 2 design now has the 8 capability to achieve both hot stand-by and cold shutdown 9 for these criteria.
| |
| 10 (Slide) 11 In the early 1970s, safe shutdown had been defined 12 as hot stand-by. In 1978, criteria for cold shutdown 13 capability was being discussed by the industry for older 14 design plants.
| |
| 15 Duquesne Light at this time, in conjunction with 16 our architect-engineer, Stone & Webster, and our NSSS 17 supplier, Westinghouse, began a detailed review of the cold 18 shutdown design issue to provide additional means to 19 improve the Beaver Valley Unit 2 design wherever feasible.
| |
| 20 Duquesne Light's implementation of the(r approach 21 to cold shutdown improvements resulted in 19 specific 22 designs being initiated in 1980. The revisions improved 1
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| 23 Beaver Valley Unit 2's safety-related capability to 7, 24 accomodate all design basis events.
| |
| (-) 25 However, Duquesne Light did not only limit ACE-FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 3364646
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| 9220 03 03 180
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| ( )marysimons 1 themselves to safety-related equipment. Many upgrades were d
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| 2 tmplemented in non-safety related systems to address 3 anticipated abnormal events and to provide wider diverse 4 methods of accomplishing safe shutdown f unctions.
| |
| 5 Several of the more prominent modifications l 6 include upgrading all three pressurizer PROVs to safety 7 grade status. The atmospheric dump valves and residual 8 heat removal valve were upgraded to safety-grade status ,
| |
| 9 and one was increasing the atmospheric steam dump ;
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| 10 capability.
| |
| 11 We redesigned the residual heat removal suction 12 and discharge valves, along with the RHR system flow 13 transmitters, to be above the maximum flood elevation 14 inside containment.
| |
| 15 We replaced two manual valves on the line 16 connecting the redundant RHR trains with motor operators 17 . capable of being operated from the control room. We 18 provided a reactor head vent and let-down capability; 19 alternate power supplies capability was added for several 20 safety-related and non-safety related components and
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| \
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| 21 systems.
| |
| 22 We provided addition ~al instrumentation on the 23 emergency shutdown panel to be able to accomplish a cold 24 shutdown from this remote location which will be amplified
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| . f"%
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| 25 in the following presentation.
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347 3700 Nationwide Coverase 800-336-6646
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| 220 03 03 181 mtrysimons 1 An additional back-up non-safety related water 2 source was also provided for the auxiliary feedwater 3 syatem. This includes a gravity feed input from the 4 600,000 gallon demineralized water tank.
| |
| 5 General Design Criteria 34 states that systems be 6 provided to carry out the safety function of transferring 7 fission product decay heat and other residual heat such as 8 specified field design limits, the design criteria, the 9 s reactor coolant pressure boundary are not exceeded.
| |
| 10 It can be shown that the Beaver Valley Unit 2 ll, plant which includes the standard Westinghouse three-loop
| |
| ,e y 12 NSSS designs, along with the system design improvements
| |
| .)
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| 13 previously described, can accomplish all of the key 14 f unctions needed to achieve safe shutdown.
| |
| 15 Suitable redundancy in components and features and 16 suitable inter-connections are provided to accomplish 17 required system safety functions assuming any single act of 18 failure.
| |
| 19 (Slide) 20 Thus, Beaver Valley Unit 2 plant design meets the 21 criteria of GDC-34 of Appendix A to 10 CPR 50 and provides 22 reasonable assurance that this facility can be operated 23 without undue risk to the health and safety of the public.
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| ,rn 24 (Slide)
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| (>
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| 25 Last week, the ACRS has requested that Duquesne ACE-FEDERAL REPORTERS, INC.
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| 202 347-MG MTawerage 800 3Mx*!)
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| ,,9220 03 03 182
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| -(l
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| '''m rysimons 1 Light review simplified sketches of both the Beaver Valley 2 Unit 2 RHR residual heat removal system and ECCS systems 3 here at the ACRS subcommittee.
| |
| 4 The residual . heat removal system for Beaver Valley 5 Unit 2 is a two-train system, two isolation valves, both at 6 the suction on both trains. These are two completely 7 independent full capacity systems. Each isolation valve 8 has an interlock which will prevent its opening when 9 pressure is above 425 pounds and will automatically close 10 the isolation valves when pressure gets to 750 pounds.
| |
| 11 Both isolation valves and motors and the 12 appropriate control valves are powered from 1-E power O 13 sources.
| |
| 14 The emergency core cooling system for Beaver 15 valley Unit 2 incorporates the recirc spray system, the low 16 head safety injection pumps, the high head safety injection 17 pumps, and the quench spray system.
| |
| 18 If we have an event calling upon the emergency 19 core cooling system, initially the high haad safety 20 injection pumps turn on pulling water from the refueling 21 water storage tank. Similarly, the low head safety 4
| |
| 22 injection pumps turn on pulling water from the refueling 23 water storage tank. 628 seconds after the initiation, the 24 recirc spray pumps turn on and put water into the
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| \ .
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| 25 containment spray header.
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| ~
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| ACE-FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 33 & 6646
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| 9220 03'03 183 mrrysimons 1 When the water in the refueling water storage tank
| |
| .2 gets below level, which is about half-way down the tank, 3 the low head safety injection pumps turn of f. These valves 4 close. These valves open, and two of the recirc spray 5 pumps now push water into the low head safety injection 6 header and also supply water to the suction of the high 7 head safety injection pumps.
| |
| 8 In conclusion, I would like to repeat the Beaver 9 Valley Unit 2 design meets the General Design Criteria 34 10 of 10 CFR 50, Appendix A.
| |
| 11 MR. EBERSOLE: Let me ask, in the hypothe tical 12 case of prolonged loss of all AC power -- all AC power --
| |
| f-)
| |
| NJ We have a presentation on station 13 MR. FEDIN:
| |
| t 14 blackout coming up.
| |
| 15 MR. EBERSOLE: That's right, later. Excuse me.
| |
| 16 MR. FEDIN: That will be coming up later this 17 afternoon.
| |
| 18 I would like to correct two items for the record 19 that we talked about earlier regarding the four steam 20 generator water level backfit item. It was stated by Mr.
| |
| 21 Kurtz that the item of concern was the low level trip. It 22 is actually the high level trip that that one is dealing l 23 with.
| |
| 24 And I had also stated earlier that the P-4, the
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| (-
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| V l
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| 25 reactor trip in addition to a low TF closes the feedwater ACE-FEDERAL REPORTERS, INC.
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| ,_._. _ ___-_202-34?-3700 _ _ _ _ _._ Nationwi4e Coverage _ __ __80433M646 , _
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| . a 922d 03 03 184
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| (' - -
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| ,_)mtrysimons1 isolation valves. It should have been the feedwater 2 regulation valves.
| |
| 3 That concludes my presentation.
| |
| 4 MR. KURTZ: The next speaker will be Mr. Ken Grada 5 on station blackout -- I'm sorry, Mr. Erv Eilmann on 6 emergency and alternate shutdown panels.
| |
| 7 MR. EILMANN: I thought there for a minute I was 8 going to get of f easy.
| |
| 9 (Laughter) 10 (Slide presentation) 11 MR. EILMANN: My name is Erv Eilmann and I'm a 12 senior project engineer in the Nuclear Construction 13 -Division. I will be addressing the topic of emergency and 14 alternate shutdown panels .
| |
| 15 (Slide) 16 Both the emergency and alternate shutdown panels 17 have the capability to bring Beaver Valley Unit 2 to a safe 18 shutdown condition in the unlikely event the control room 19 becomes uninhabitable.
| |
| 20 The emergency shutdown panel, while satisfying the 21 requirements of GDC-19 is utilized only in the event that 22 something should render the control room uninhabitable for 23 the operators , such things as on-site or of f-site toxic 24 chemical releases, smoke infiltration from fires outside of 25 the control b'uilding complex.
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 336-6646
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| - j 9220.03 03- 185 i
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| (~)
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| - k 'mtrysimons-1 In the case the control room should become 2 uninhabitable, .the operators would evacuate to the 3 emergency shutdown panel in accordance with approved .
| |
| 4 procedures.
| |
| f 5 The emergency shutdown panel, as you saw yesterday b 6 on the tour, is located two floors below the control room.
| |
| 7 This is the instrumentation relay room where we went f
| |
| , 8 through, and the~ emergency shutdown panel is located in the 9 back of that room-in its own separate cubicle.
| |
| l.'
| |
| 10 The emergency shutdown panel is designed to 11 achieve hot stand-by condition and has the capability to 12 : proceed to cold shutdown. Transfer of each component's LO l
| |
| 13 control is accomplished by individual. switches at the i- .14 emergency shutdown panel.
| |
| 15 This transfer electrically' separates individual 16 components from the control room without changing the 17 status of the equipment.
| |
| 18 (Slide) 19 As this figure shows here in simple form, it shows 20 a switch at this point here. This switch is actually 21 located on the panel and it just demonstrates that this 22 switch is thrown to close off the control room portion, and 23 now the system is run through the emergency shutdown panel.
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| z 24 The emergency shutdown panel is capable of
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| - C:)
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| 25 controlling the shutdown systems of both safety-related T
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| < - ace-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 336-M46
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| 220 03 03 186 m:rysimons 1 trains -- orange and purple -- as well as the necessary non-2 safety related systems.
| |
| 3 (Slide) 4 The only postulated loss of control room 5 habitability the emergency shutdown panel is not utilized 6 for is that of an interior fire. The control room is one 7 of five rooms in three fire areas. The control room, cable 8 spreading room, cable tunnel, instrumentation and relay 9 room, and west communication that are all part of this 10 control building complex.
| |
| 11 In these rooms it is not possible, due to the c3 12 congestion of electrical cables and their raceways to fully 13 meet the separation of redundant safe shutdown trains and 14 to ensure safe shutdown capability.
| |
| 15 (Slide) 16 For these three fire areas an alternative shutdown 17 capability was provided by using an alternate shutdown 18 panel. The alternate shutdown panel is located, as you saw 19 yesterday, in the auxiliary building at Elevation 755.
| |
| 20 In the unlikely event that the control room would 21 become -- that a fire would occur in one of these five 22 rooms, the operators would proceed from the main control 23 room through the access tunnel to the alternate shutdown r 24 panel.
| |
| 25 Now, yesterday on your tour we pointed out tha t we ACE-FEDERAL REPORTERS, INC.
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| 202 347 07D Nationwide Coverage 800 336-6646
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| 220 03 03 187 marysimons 1 could not go through that access tunnel because it wac 2 boarded'off or sealed off because it right now enters into 3 the Unit 1 area, control area.
| |
| 4 The access tunnel -- this is not drawn correctly, 5 the stairs are actually outside here and the control room 6 operator would proceed out this door down the stairs 7 through the control access to the alternate shutdown panel.
| |
| 8 The alternate shutdown panel, as was the case with 9 the emergency shutdown panel, has transfer switches of each 10 component also located at it. The alternate shutdown panel 11 contains only one safety-related train and includes the
| |
| (--)
| |
| 12 necessary controls to achieve and maintain shutdown df the v
| |
| , 13 reactor; maintain reactor coolant; acnieve and maintain hot 14 stand-by condition, and to achieve and thereafter maintain 15 a cold shutdown condition.
| |
| 16 In conclusion, the capabilities of Beaver Valley 17 2's emergency and alternate shutdown panels provide a safe 18 reans of shutting down the plant in the unlikely event the 19 control room becomes uninhabitable for any situation, 20 including a fire.
| |
| 21 MR. EBERSOLE: May I ask a question?
| |
| 22 MR. EI LMANN : Certainly.
| |
| 23 MR. EBERSOLE: Do you believe that both of these 24 remote shutdown boards are necessary, or would you rather 25 just have one? And if you had one, which one?
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| ACE FEDERAL REPORTERS, INC,
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| _- N e e -
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| 220 03 03 188 marysimons 1 MR. EILMANN: Okay, let me back up to one I can 2 talk here.
| |
| 3 Due to the vintage of our plant and design of our 4 plant, both panels are necessary for Beaver Valley Unit 2.
| |
| 5 We could not get away with one or the other.
| |
| 6 MR. EB ERSOLE: You could not get away with just 7 the alternate shutdown panel?
| |
| 8 MR. EILMANN: That's correct , sir.
| |
| 9 MR. EBERSOLE: Why is that?
| |
| 10 MR. EILMANN: In order to satisf y the requirements 11 of GDC-19, we have to supply an alternative means from the
| |
| '' 12 control room in which to shut the plant down in the case 13 the control room becomes uninhabitable.
| |
| 14 And this other means or this other shutdown panel 15 must be able to handle a single failure and loss of off-16 site power. Therefore, you need both safety-related 17 trains.
| |
| 18 In the case you shutdown panel contains only one 19 train. an emergency shutdown panel satisfies that GDC-19, 20 both trains are located in there and we have the capability 21 to deal with single failure activities.
| |
| 22 MR. EBERSOLE: I don't think GDC-19 specifically 23 said you needed two channels , did it?
| |
| ~
| |
| () 24 MR. EILMANN: No, it requ!res you to have the
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| \. ,'
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| 25 capability to do it with single failure , and we have- ae t ACE-FEDERAL REPORTERS, INC.
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| .m, , ,, , ,m m.m m.c _ . -m- l
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| ~_ .- _ _ __ __ _ . _ - ._ - . . _ . _ __
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| 1 l
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| J l
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| -0220 03 03 189 i
| |
| LJ ,
| |
| mnrysimons 1 that through the redundant trains. )
| |
| 2 MR. EBERSOLE: Is that the current staff 3 requirement that both of these boards are necessary? Is 4 that the current staff requirement, you must have both of 5 these capabilities?
| |
| 6 MR. SINGH: That's right, right now it is the 7 requirement.
| |
| 8 MR. EBERSOLE: You have to have two alternate 9 shutdown .
| |
| 10 MR. SINGH: No. I think it's my understanding 11 that if they have to design again, the place where they 12 have the alternative shutdown panel -- I think they don't 13 need the emergency shutdown panel.
| |
| 14 MR. EILMANN: Well, I can drag this out, probably, 15 into some deep design philosophy. But in that situation, 16 say that we did delete this panel and we now put both 17 safety trains in there, if we had a fire in this room, we 18 would now lose both safety trains. We need something up-19 stream of that now to control and bring the plant to safe 20 shutdown.
| |
| 21 So in the design of our plant, if we probably had 22 to do it over again, we would certainly look for a means of 23 getting appropriate electrical separation in this area to r^) 24 try and alleviate one of those panels. But because of the
| |
| \ .)
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| 25 age and the vintage of our plant, it was not possible.
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| ACE-FEDERAL REPORTERS, INC.
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| W W -1700 Nationwide Coverarr 800 1 % 6646
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| | |
| 220 03 03 190 mnrysimons 1 MR. REMICK: What assurance do you have in the 2 emergency shutdown panel room that you won' t get the same 3 infiltration of smoke or toxic chemicals and so forth that 4 might have made the control room uninhabitable?
| |
| 5 MR. EILMANN: The emergency shutdown panel is 6 located two floors below and has its own independent 7 ventilation system. The control room ventilation system is 8 on the same floor as the main control room.
| |
| 9 And then, the emergency shutdown panel has its own 10 ventilation system and it is its own three-hour fire 11 barrier or fire zone.
| |
| rx 12 MR. REMICK: Where are the relative intakes to (v )
| |
| 13 those two rooms? For example, on the same side of the 14 building, or are they purposely designed to be 180 degrees 15 apart, or anything like that?
| |
| 16 ,
| |
| In other words, if you are going to infiltrate 17 chemicals from a barge or something externally, what 18 assurance do you have that it won' t be sucked into both 19 areas, the control room and the emergency shutdown panel 20 area?
| |
| 21 MR. EILMANN: I'm not familiar with that question 22 and I would like to have Jack Harding address that if I 23 may, please.
| |
| ,r"x 24 MR. REMIC K: Sure.
| |
| x ,)
| |
| 25 MR. RARDING: My name is Jack Harding.
| |
| ACE-FEDERAL REPORTERS, INC.
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| ?D7147M00 Nationwide Coverare 80M16-6646
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| | |
| ~ . . .- - a ..:. .....;,
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| .,e9220 03 03 191
| |
| -V marysimons 1 The ventilation systems are in two separate 2 buildings totally. The control room ventilation system is 3 right next to the control building. The ventilation system 4 -for the emergency shutdown panel is in the auxiliary 5 building, completely separate buildings. I'm not sure of 6 the distance between the two.
| |
| 7 In case of a barge accident or chemicals coming up.
| |
| 8 through the atmosphere, we have a habitability system for 9 the control room. We would not evacuate the control room, 10 we would go to a bottle air pressurization system and still 11 maintain habitability in the control room.
| |
| 12 MR. . REMICK: I guess if you had confidence in 13 that, then why have the emergency shutdown panel for the 14 purpose of loss of habitability of the control room? It 15 seems to me if you can isolate it and supply its own air, 16 other than internal fire you would have no need for 17 emergency shutdown.
| |
| 18 Is there something I'm missing?
| |
| -19 M R. GRADA: Kenny Grada. That was for the i
| |
| 20 exposure fire in the control room, that's all .
| |
| 21 MR. REMICK: Okay. Which one of these meets the 22 criteria that you mentioned about loss of all AC power, 23 which, emergency or alternate?
| |
| i 24 MR. EILMANN: I'm sorry, would you repeat that?
| |
| }
| |
| 25 MR. REMICK: Yes. Which one of these rooms meets 1
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| ACE-FEDERAL REPORTERS, INC.
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| ., m e,m m., - c=_ .m m -
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| 220 03 03 192 marysimons 1 the criteria of being able to shut down in case of loss of 2 all AC power?
| |
| 3 MR. GRADA: Kenny Grada again. Neither one of 4 those panels are designed for loss of all AC power. You 5 would maintain occupancy in the control room.
| |
| 6 MR. REMIC K: You would what?
| |
| 7 MR. GRADA: Under loss of all AC power you would 8 maintain, you know, the control room.
| |
| 9 MR. REMICK: I see. I thought the statement was, 10 one of these --
| |
| 11 MR. GRADA: Single failure.
| |
| 12 MR. EILMANN: Both of these are designed for loss 13 of off-site power.
| |
| 14 MR. REMICK: Oh, off-site power.
| |
| 15 MR. EILMANN: And the emergency panel for single 16 failure.
| |
| 17 MR. REMICK: But not all AC power but off-site 18 power.
| |
| 19 MR. EILMANN: Not a blackout station condition.
| |
| 20 MR. REMIC K: Is the ventilation system then in 21 these run off your diesel generators? Suppose that you 22 went to one of these and you lost of f-site power, would the 23 ventilation system still work in the room?
| |
| 24 MR. HARDING: Yes. It is powered by the diesel r^}
| |
| 25 generators.
| |
| ACE. FEDERAL REPORTERS, INC.
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| ?n?.W.17m Nannnude Coverage 800-336-6646
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| r^220 03 03 193 Q).
| |
| mrrysimons l- MR. REMICK: Okay, thank you.
| |
| -2 MR. EBERSOLE: You say the presence of the 3 emergency shutdown panel is justified by the f act that the 4 alternate shutdown panel, if it is damaged by fire, may 5 carry away one channel to which it's related. Is that 6 right?
| |
| 7 MR. EILMANN: I'll ask you to repeat that because 8 I think that's not correct.
| |
| 9 MR. EB ERSOLE : Okay. If you have some fire, 10 exposure fire in the alternate shutdown panel, that 11 - hypothetically at least disables the working channel of 12 heat removal that that represents; is that right?
| |
| }
| |
| 13 MR. EILMANN: If'we have a fire in the orange.--
| |
| 14 MR. EBERSOLE: Yes.
| |
| 15 MR. EILMANN: - -- in the alternate shutdown panel, 16 we would essentially render the orange train as inoperable.
| |
| 17 MR. EBERSOLE: Right. Now then, does that also 18 present the potential for spurious and undesired operation 19 as well as inoperability?
| |
| 20 MR. EILMANN: There is a potential and we are 21 presently -- that is the nature of our open item under safe 22 and alternate, that there could be a spurious signal.
| |
| 23 We are presently studying that or perform an We do not know what
| |
| {} 24 analysis to determine what those are.
| |
| 25 those are at this time.
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| ACE-FEDERAL REPORTERS, INC.
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| m m mn m. - c= = .m v-
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| 220 03 03 194 mrrysimons 1 MR. EBERSOLE: Right. If that orange train were 2 lost, what is to prevent the main control room panels from 3 simply taking over the function?
| |
| 4 MR. EILMANN: Am I understanding correctly that 5 we've had a fire that renders this area --
| |
| 6 MR. EBERSOLE: No, no. The other one , the orange.
| |
| 7 MR. EILMANN: Okay. If the fire is just in this 8 area, we've only af fected the orange train. We can operate 9 the control room and safely shut the plant down with the
| |
| . 10 purple train.
| |
| 11 MR. EBERSOLE: Why do you have to go to the purple f
| |
| e' 12 train, why can't you do it from the main control room?
| |
| O 13 MR. EILMANN: Because the orange train would be --
| |
| 14 if the fire is just in the alternate shutdown panel itself, 15 the orange train would be af fected.
| |
| 16 MR. EBERSOLE: Well, doesn't that leave still 17 another train from the main control room?
| |
| 18 MR. EILMANN: Yes, the purple train.
| |
| 19 MR. EBERSOLE: So why do you need the emergency 20 shutdown panel?
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| 21 MR. EILMANN: The emergency shutdown panel?
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| 22 MR. EBERSOLE: Yes.
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| 23 MR. EILMANN: All right, the emergency shutdown
| |
| ( 24 panel is if we cannot contain or remain within the control 25 room.
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| ACE-FEDERAL REPORTERS, INC.
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| ?n'.t M.1700 Natinnwide Cm erace 800-316-6646
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| '220 03 03 195
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| )
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| 'n s mnrysimons 1 MR. EBERSOLE: But that doesn't occur 2 coincidentally with the fire in the alternate panel.
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| 3 MR. EILMANN: No, we do not postulate tWo events 4 for the fire.
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| 5 MR. EBERSOLE: So I don' t see why you have any use 6 for the emergency shutdown panel at all.
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| 7 MR. MARTIN: I think there might be -- Roger 8 Martin -- there might be a misunderstanding that the 9 control circuits that are indicated " orange train" to the 10 alternate shutdown panel are not thu same orange train 11 circuits that go completely to the main control room
| |
| (~) 12 there. They are two separate sources of orange train-type U
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| , 13 control.
| |
| 14 MR. EB ERSOLE : What I'm really searching for is a 15 continued justification of what I would call the hazard 16 potential of the emergency shutdown panel. In view of the 17 fact that you now have a competent alternate shutdown panel 18 for a fire and presumably it is okay for one channel, I 19 agree, not for two --
| |
| 20 MR. EILMANN: It is okay only from the standpoint 21 it is not safety grade.
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| 22 MR. EBERSOLE: Yes.
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| 23 MR. EI LMANN: There are portions of the circuitry 24 in this shutdown panel which run off of non-safety grade
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| (' }
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| 25 equipment.
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| ACE-FEDERAL REPORTERS, INC.
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| w u- ,-nn w ,n,mia,entuu, amiu.uu
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| 220 03 03 196 mrrysimons 1 MR. EBERSOLE: Yes, I understand that. But it's 2 to accomodate primarily the Appendix R.
| |
| 3 M R. EI LMANN : For the fire only. And the 4 requirements that specify the need for emergency shutdown 5 panel are much more st-ingent than what we have devised for 6 this room.
| |
| 7 MR. EBERSOLE: I see.
| |
| 8 MR. CAREY: I think you have to remember that we 9 tried to duplicate No. 1 unit. No. 1 unit started out with 10 an emergency shutdown panel that me t the requirements for 11 No. 1 unit to bring the pla.it to a hot shutdown.
| |
| 12 When we got to No. 2 unit., we felt that we would
| |
| <-)
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| 13 eventually have to go to cold shutdown, and we didn' t 14 anticipate Appendix R. So we designed a panel to provide 15 the capability' to go to cold shutdown, and we thought we 16 were all done.
| |
| 17 Then Appendix R came along and we found out we 18 weren't done.
| |
| 19 MR. SINGH: Tha t's wha t I was saying , tha t if they 20 would have designed after Appendix R, they might not have 21 come up with the emergency shutdown panel.
| |
| 22 MR. EBERSO LE: Right. Does this represent Unit 1 23 as well? Is this the way Unit 1 is rigged?
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| 24 MR. EILMANN: Unit 1 does not have an alternate
| |
| -)
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| 25 shutdown panel.
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| ACE-FEDERAL REPORTERS, INC.
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| 202 34 13700 Nationwide Coveraae 800-336-6646 o
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| - 220 03 03 197 marysimons 1 MR. EBERSOLE: It does not have an alternate 2 shutdown panel. How do you cope with Appendix R in Unit 17 3 MR. GRADA: This is Kenny Grada. We have a back-4 up indicating panel that's located in the cable vault and 5 powered of f of one train. But it's principally an 6 indication only and we rely on operator control in certain 7 motor-operated valves , aux feed , main steam relief .
| |
| 8 MR. EBERSOLE: You've got a passive system that 9 relies on what , voice communication to operators?
| |
| 10 MR. GRADA: We installed a separate communications 11 system outside of the af fected fire areas. But we didn't 12 want to install any additional cable because every cable -
| |
| )
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| 13 that we had to add, we had to look at hot short, open 14 short, short to ground.
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| 15 MR. EB ERSO LE : All right, thank you.
| |
| 16 MR. EILMANN: To further answer a question asked .
| |
| 17 earlier, there are other facilities with similar 18 arrangements with two panels -- Nine Mile Unit 2, North 19 Anna Unit 1, and Surry 1 and 2. This is not a unique 20 approach.
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| 21 MR. EBERSOLE: So this really represents evolution 22 of the fire problem.
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| 23 MR. EILMANN: Correct. As we went through the
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| (^) 24 years and new regulations and new concerns came up, it 25 evolved that we had to have an alternate shutdown panel.
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| I ACE-FEDERAL REPORTERS, INC.
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| W u* 19m Nahnnsde Cnurne EM6-6646 . . . . . _ _
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| 220 03 03 198 marysimons 1 As I said earlier, should we design it today, I'm 2 sure that we would take steps to try and eliminate one of 3 those through better electrical separation in our cable 4 control area, cable vault-areas.
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| 5 MR. EBERSOLE: Was it not possible to design the 6 alternate shutdown panel so that in the event of 7 destruction of it by fire, there would be no inadvertent 8 operation or results from that?
| |
| 9 MR. EILMANN: Would you repeat that?
| |
| 10 MR. EBERSO LE: I say, was it not possible to 11 design the alternate shutdown panel so if it were destroyed
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| ,g
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| , 12 it could not result in spuriobs operation or undesired
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| (). -
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| 13 f unctions? . .
| |
| 14 MR. EILMANN: I believe that it is designed that 15 way. If there were a fire in that room -- we are not sure 16 if it's going to cause spurious singles.. We are now 17 looking at that study. But we do have the availability of 18 other trains to go back to the control room in order to get 19 t,he plant shut down.
| |
| 20 MR. EBERSOLE: Thank you.
| |
| 21 MR. EILMANN: I'd like to address a couple other 22 items that are open from the site tour and, I guess, this 23 morning.
| |
| 24 The first one I'd like to get into is to deal 25 with, there was some question yesterday about the diesel ACE-FEDERAL REPORTERS, INC.
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| - 202.M7 3700 Nationwide Coverage 800 336-6M6
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| i f
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| ,1 -
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| .,,9220.03 03 199
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| (
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| T
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| '~ ccrysimons_1 generator, CO2 system and ventilation, and there was some 2 questioning relating to the staff, do you require anything 3 f urther from us in that area, would you like any f urther --
| |
| 4 MR. EBERSOLE: You might clarify, I think, for the
| |
| ! 5 other company here how you justify the closure of the
| |
| + 6 diesel generator room with CO2 with none-seismically 7 qualified apparatus.
| |
| 8 MR. EILMANN: Okay. The ventilation system and 9 fans in the diesel generator room are actuated off a
| |
| ,e l 10 Category I detector, and that detector is different than 11 the heat detector that is used actually, the CO2 system.
| |
| 12 The ventilation fans are set to shut off at 130 O 13 degrees and the CO2 is set to go of f at 180. So, the CO2 14 system in no way is tied to the ventilation systems or fans 15 in the diesel generator building.
| |
| 16 So an inadvertent operation of CO2 would not cause ,
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| 17 the vents or the f ans to shut off.
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| 18 MR. EBERSOLE: Right.
| |
| 19 MR. EILMANN: The other point that came up this 20 afternoon during the NRC presentation was the cable 21 spreading room, CO2 backfit issue, and I'm not sure if 22 there are any additional questions you might have in that 23 area. If there are, I'll be glad to address those.
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| 24 MR. WYLIE: Well, let's see, I believe there was a
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| (
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| 25 question regarding the staf f's inability or suggested ACE. FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 336 6646
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| l 220 03 03 200 c:rysimons 1 inability to reach certain areas in that cable spreading 2 room with the fire brigade; is that correct?
| |
| 3 MR. EILMANN: Okay, during the staff's visit down
| |
| . 4 here, our brigade which we are very proud of got put 5 through a very strenuous test of showing or demonstrating 6 accessibility. Their face masks were totally blackened and 7 they showed access to the staff by carrying their f ull jet 8 air packs and entering with a hose.
| |
| 9 In the area in question, in that cable spreading 10 room area, in the northwest corner, is a enngestion of 11 cables which the staff felt was unaccessible or could not s 12 be reached.
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| ~
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| 13 We have made some improvements to that area to 14 further enhance our ability to fight fire there. Those 15 improvements have entailed removing some platforms -- let 16 me see if I can pull up the drawing to help aid --
| |
| 17 The northwest corner area right in here, we saw 18 access as we came through here to get back. We have 19 removed the platforms that access to the bottom of the 20 control boards. They are in there now through 21 construction, but once construction is complete, we will 22 remove these control panel -- the bottom of the control 23 board access platforms which run in these area and were
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| ~'
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| 24 presently inhibiting us from getting further in.
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| 25 We will remove those and any associated conduits ACE FEDERAL REPORTERS, INC.
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| 20>1491700 Nationwide Covera,e R00 3%-(M6 (
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| 9220.03 03 201
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| .Omarysimons,1 that are obstructing that aisle now that we have created by 2 removing those platforms. That allows us now an additional 3 eight feet access in this area than what we previously had.
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| 4 Also, we will be purchasing special nozzles --
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| 5 referred to sometimes as Navy nozzles -- and they are a 6 .long extension, four to ten-foot type pipe extension 7 nozzles that allow you to reach into areas that perhaps are 8 somewhat a little unaccessible to get to.
| |
| 9 We feel with these enhancements, along with the 10 design that we already have in there that we have 11 demonstrated to the staff, that we have the assurance that 12 no fire in there will go without being attended to.
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| .O- 13 MR. REMICK: I'm curious about that, the metal 14 nozzles, poking them into the midst of an electrical fire.
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| 15 Isn' t there some hazard to the poor guy handling those?
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| 16 MR. EILMANN: There is some concern about that.
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| 17 They are the fog head nozzles which, for a fire brigade you 18 don't want to put a jet, a straight stream because you can 19 sometimes get some travel back.
| |
| 20 But these are fog nozzles that fit onto -- and 21 they, you know, stick those in so it prevents some 22 feedback, l
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| 23 MR. WYLIE: "Could you put back that other slide
| |
| - 24 that shows the control room for a moment? Maybe you can 25 help me out a little bit. I was a little confused. Yes, ACE FEDERAL REPORTERS, INC.
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| . _ _ . . @M_7_3700_ __.. _ _ _ ___ Nationwide W_ ___ __ 800 33H646_ ______ _ _ .
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| ,_9220 03 03 202 4 i
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| '''marysimons 1 that one.
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| '2 MR. EILMANN: This is not by scale.
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| 3 MR. WYLIE: Well, yes. Now, looking at Unit 1 4 from your position there, that's the way you look at the 5 simulator; right?
| |
| 6 MR. EILMANN: Yes. The simulator that we saw 7 yesterday is looking at it like this. Yes.
| |
| 8 MR. WYLIE: And Unit 2, then, is laid out 9 opposite.
| |
| 10 MR. EILMANN: Unit 2, as I said, is misdrawn. It 11 looks the same as this panel, just this way. The 12 safeguards is this leg, and it should be the same length as k
| |
| 13 that. And the reactor controls , reactor controls in this.
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| 4 14 The shorter leg, which is the turbine controls, should be 15 this shorter like here.
| |
| 16 This is not drawn to the perspective that it 17 should be.
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| 18 MR. WYLIE: That's confusing, yes.
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| 19 MR. EILMANN: Pardon me?
| |
| 20 MR. WYLIE: I said it's a little confusing.
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| 21 MR. EILMANN: Yes. That's why I tried to just go 22 by that real fast.
| |
| 23 (Laughter) 24 MR. CAREY: Excuse me. This is Jack Carey. The 25 board is the same board rotated 90 degrees, is the way to ACE FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 33H646
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| r<
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| l
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| ,_9220 03 03 203
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| ! I L ^-)ccrysimons1 look at it.
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| 2 MR. EILMANN: Thank you.
| |
| 3 MR. KURTZ: The next speaker is Mr. Kenny Grada on 4 station blackout.
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| l 5 (Slide presentation) 6 MR. GRADA: I'm the manager of Nuclear Safety at 7 Beaver Valley and since March of this year, I've been L 8 filling in as director of site Operations.
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| I
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| ! 9 I've prepared this brief presentation on station i 10 blackout due to a recent question on, what do you do at l
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| 11 Beaver Valley during a blackout event.
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| 12 To address this issue, I'll be discussing some l
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| O 13 design features and mitigation systems, along with the 14 operator actions required upon recognition of a blackout l
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| 15 event at Beaver Valley.
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| 16 Station blackout is defined as a simultaneous loss 17 of of f-site power with f ailure of on-site emergency diesel 18 generators. Although blackout was not a design basis 19 event, Duquesne Light through its participation in 20 Westinghouse Owners Group has developed an emergency 21 procedure to take full advantage of existing design l 22 features to mitigate the ef fects of blackout on the fission j 23 product barriers until power is restored to the grid or on-l l 24 site sources of AC restored.
| |
| l 25 Can I have the first slide, please?
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| i c i ACE FEDERAL REPORTERS, INC, 202 347 3700 ____ _____ Nationwide CoveQ _ _ _ _ __ _ _800 346646
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| f-9220 03 03 204 V ccrysimons 1 (Slide) 2 These mitigation systems and design features 3 include the following to minimize the challenges no the 4 critical safety functions and limit recovery time under 5 black-out conditions:
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| 6 Steam generator power operated relief valves to 7 provide controlled heat removal from the secondary system 8 and limit the operation of steam generator safety valves.
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| 9 These valves can be manually operated with a loss 10 of all AC along with the decay heat removal and auxiliary 11 feed pump discharge valves.
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| 12 Turbine-driven feed pump to maintain a secondary 13 heat' sink for the primary system. Flywheels on the reactor 14 coolant pump to ensure an adequate flow goes down and core 15 cooling until natural circulation conditions are 16 established.
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| 17 We have 25 percent design margin on station 18 batteries. We have floating ring seals installed in the 19 main flanges of the reactor coolant pumps to limit leakage 20 in the event of a number-one seal failure.
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| 21 System cross ties, which assure a long-term source 22 of make-up to the safety-related feedwater system. S i x --
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| 23 peaking units with a combined capacity of 204 megawatts 24 electrical under the control of the system operator, one of
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| [}
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| 25 which has black-start capability.
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| ACE FEDERAL REPORTERS, INC.
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| 220 03 03 205 marysimons 1 We have six 345 kv and seven 138 kv lines in the 2 switch yard. Any of the 345 kv and three of the 138 kv can 3 supply emergency power to both Beaver Valley 1 and 2 4 emergency buses.
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| 5 We have a combined nuclear-coal complex generating 6 capacity between Beaver 1, Beaver 2, and the Mansfield 7 units in excess of 4,000 megawatts electrical, which makes 8 it one of the power densest areas in the United States.
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| "9 Operator action is initiated upon recognition of a 10 plant trip produced by the loss of of f-site power. Then 11 procedural guidelines are contained in Procedure ECA 00,
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| , 12 which is entitled, " Loss of all power." This is transition 13 from the normal reactor trip procedure or may be entered 14 directly upon identification of a blackout event.
| |
| 15 Next slide, please.
| |
| 16 (Slide) 17 MR. EBERSOLE: Pardon me, before you go to that.
| |
| 18 How many generating units are in that 4,000 megawatt 19 electric?
| |
| 20 MR. GRADA: Five.
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| 21 MR. EBERSOLE: Five of them. So that's five 22 units.
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| 23 MR. GRADA: Yes, sir.
| |
| g) 24 MR. EB ERSOLE: They are pretty much local, aren't
| |
| \-)
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| 25 they?
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| ACE FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Com M336 6646
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| r9220 03 03 206 VC rysimons 1 MR. GRADA: Yes.
| |
| 2 MR. EILMANN: I ask the standard question, the 3 turbine-driven aux feedwater pumps, are they things that 4 maintain secondary water feed in the event there is no AC 5 power.
| |
| 6 Describe to me the dependencies, if any, including 7 valves and cooling fans of the aux feed pumps on AC power.
| |
| 8 MR. GRADA: Well, the steam supply valves, okay, 9 are DC-powered.
| |
| 10 MR. EBERSOLE: Both of them?
| |
| 11 MR. GRADA: Yes , sir.
| |
| 12 MR. EBERSOLE: They.are both DC-powered?
| |
| 13 MR. GRADA: And they would fail open on loss of 14 power.
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| 15 MR. EBERSOLE: They fail open on loss of power?
| |
| l 16 MR. GRADA: The steam supply to the -- turbine, 17 yes, sir. It starts --
| |
| 18 MR. EBERSOLE: Are they not motor-driven so they 19 fail in situ?
| |
| 20 MR. GRADA: No.
| |
| 21 MR. EBERSOLE: What kinds of valves are they, air 22 valves?
| |
| ! 23 MR. GRADA: They are electro-hydraulic valves with f
| |
| i 24 a --
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| 25 MR. MARTIN: They are solenoid valves.
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| ACE. FEDERAL REPORTERS, INC.
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| .m, u, _ ,,, u , - _ m c__ - _ _ _ m s u ,, ,,
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| r 1 220 03 03 207 marysimons 1 MR. EILMANN: Solenoid operated, but they --
| |
| 2 MR. EBERSOLE: They are solenoid-operated 3 hydraulically actuated?
| |
| l 4 MR. SCHUSTER: No, they are straight solenoid 5 operated.
| |
| 6 MR. EBERSOLE: Straight solenoid valves that 7 handle the steam flow to the aux feed pumps? That's a 8 pretty big solenoid valve.
| |
| 9 MR. SCHUSTER: I'm Fred Schuster. Yes, they are 10 direct solenoid valves. ,
| |
| 11 MR. EBERSOLE: What's the diameter of the valves?
| |
| g3 12 MR. SCHUSTER: Pardon?
| |
| L) 13 MR. EBERSOLE: What's the pipe diameter for the 14 aux feed pumps? Tha t's pretty big.
| |
| 15 MR. SCHUSTER: I believe it's three-inch, but I'm 16 not absolutely --
| |
| 17 MR. EBERSOLE: So it's a three-inch solenoid 18 valve?
| |
| 19 MR. GRADA: Yes. We have many large solenoid 20 pilot-operated valves in the plant.
| |
| 21 MR. EBERSOLE: Yes, but they have an auxiliary 22 source of some kind of mechanical power.
| |
| 23 MR. SCHUSTER: Pressure, pilot operated.
| |
| r- 24 MR. EBERSOLE: Pilot operated. And what's the
| |
| \_-
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| 25 pressure that operates them, what is it? Is it oil or -- ,
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| ACE. FEDERAL REPORTERS, INC.
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| F%PSm - -- RteneGba~]_____________M_________
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| 4 220 03 03 208 marysimons 1 MR. SCHUSTER: It's steam pressure.
| |
| 2 MR. EBERSOLE: Oh , pilot-operated steam pressure ,
| |
| 3 and they f ail open.
| |
| 4 MR. GRADA: Yes, sir.
| |
| 5 MR. EBERSOLE: Upon actuation of the solenoid and 6 if it goes dead, they stay open; is that right?
| |
| 7 MR. EILMANN: Yes, sir.
| |
| 8 MR. EBT RSOLE: I see. What about environmental 9 cooling for the turbine-driven aux feed pumps?
| |
| 10 MR. GRADA: That would not be available in the 11 event of a loss of all AC, but the compartment size is such g-) 12 that if you, you know, merely opened the doors between 13 inter-connecting departments, there wouldn' t be a cooling 14 problem.
| |
| 15 That particular issue was evaluated under NUREG-CR-16 3226.
| |
| 17 MR. EBERSOLE: Okay. So then you have eliminated 18 AC dependencies.
| |
| 19 MR. GRADA: Yes, sir.
| |
| 20 MR. EBERSOLE: Thank you.
| |
| 21 MR. GRADA: And on the governor control there is 22 no AC/DC or air requirement.
| |
| 23 MR. REMICK: Where are the peaking units you r~s 24 referred to?
| |
| O 25 MR. GRADA: They are located at Brunaud's Island, ACE FEDERAL REPORTERS, INC.
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| E4fS4EG Nationwide h 800 336 4 646
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| 220 03 03 209 marysimons 1 approximately 29 miles away. They are under the control of 2 the system operator.
| |
| 3 MR. REMICK: So if you lost AC power from the 4 transmission line that goes in that direction, you would 5 not necessarily have those. If that was your reason for --
| |
| 6 MR. GRADA: Well, we would have to lose multiple 7 lines. We have, as I said earlier, we have six 345 kV 8 cross ties and seven 138 kv. So it would have to be 9 virtually a total destruction of the switch yard.
| |
| 10 MR. MARTIN: Let me elaborate on that. We have a 11 loop system. The Duquesne Light system can be fed from two
| |
| ,es 12 directions so that the peaking units which are basically in
| |
| )
| |
| 13 the geographic center of our system would be able to feed 14 from one direction or the other to reach the Beaver Valley 15 Station.
| |
| 16 MR. REMICK: Thank you.
| |
| 17 MR. EBERSOLE: Is the floating ring seals -- are 18 you referring to the main coolant pump seals?
| |
| 19 MR. GRADA: No, these are installed in the main 20 flange of the pump. The original design is based on you 21 having seal injection and limiting the leak-of f in the 22 event of a complete wipe of the No.1 seal in the main 23 coolant pumps.
| |
| 24 To limit leakage, I have seen numbers in the range 25 of 50 to 75 gallons a minute.
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| ACE. FEDERAL REPORTERS, INC.
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| - ___ __-_ F%fD94WD____ _ _-_ __ _ DttarC@Cacm _ _ CTM3CD
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| i
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| ^220 03 03 210 mnrysimons 1 MR. EBERSOLE: This is prolonged leakage with loss 2 of cooling on the seals?
| |
| 3 MR. GRADA: As I said, it assumes that you have 4 seal injection which under a loss of all AC you wouldn't.
| |
| 5 MR. EBERSOLE: Right.
| |
| 6 MR. GRADA: But they would offer another 7 restriction to reduce the dif ferential pressure on that No.
| |
| 8 1 seal.
| |
| 9 MR. EBERSOLE: Right. Do you have the GPM rate on 10 the loss of cooling to the seals as a function of time?
| |
| 11 MR. GRADA : We have not received the full French r^ /
| |
| 12 report from the tests that were conducted May 29 and 30.
| |
| 13 under W CAP 10541 they were predicted to be in the 14 neighborhood of 21.2 gallons a minute.
| |
| 15 Westinghouse is looking at a material, it's a 16 Parker East 740-70 -- material for commercial -- for 17 replacement of the E-515-80 material in the pumps.
| |
| 18 MR. EBERSOLE: How long will the batteries last 19 under this case?
| |
| 20 MR. GRADA: We have looked and with some 21 conservatism we would get a minimum of four hours out of 22 the batteries. But if you took some measures to, say, kill 23 the Train B batteries, that could run you out, you know, 24 another four hours.
| |
| {
| |
| 25 Again, the loads that we looked at are based on ACE-FEDERAL REPORTERS, INC.
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| en u- 3-m % im a, em en., un m uw
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| 220 03 03 211 marysimons 1 name-plate rating like 183 amps on the solid state 2 inverters. But from our experience at Unit I we know that 3 these values are typically 35 to 40 percent, you know, 4 below that.
| |
| 5 MR. EBERSOLE: So you root number is about four 6 hours that you can tolerate.
| |
| 7 MR. GRADA: Minimum, yes, sir.
| |
| 8 MR. EBERSOLE: Thank you.
| |
| 9 MR. GRADA: Can I have my next slide, please?
| |
| 10 (Slide) 11 Procedure -- 00 has the operator verifying or 12 performing the following . items : :
| |
| -)_
| |
| 13 Reactor trip which he would do by checking the rod 14 bottom lights, the RPIs at zero decreasing nuclear flux and 15 the main trip by-pass breakers are closed.
| |
| 16 Turbine trip by checking that the throttle valve, 17 governor valves intercept and reheat stop valves are 18 closed.
| |
| 19 Rehoat steam and main steam isolation. Generator 20 output breakers and exciter breakers open, and RCS 21 isolation, he would check that the power operated relief 22 valve and the let-down system is isol'ated to minimize the 23 inventory loss from the reactor coolant system.
| |
| n us 24 25 And verifying that we are in f act delivering aux feed flow to the steam generators.
| |
| ACE FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Com 800 336 6646 J
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| i
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| , )
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| 9220 03 03 212 n
| |
| Q.-marysimons 1 Next slide, please.
| |
| 2 (Slide) .
| |
| 3 Follow-up actions would include placing emergency
| |
| '4 equipment in -- locks such as high head, low head, quench -
| |
| 5 spray, recirc spray, component cooling water pump, motor- ,
| |
| 6 driven aux feed pump, and cor.tainment air recire fans 7 putting them on --
| |
| 8 Attempting local diesel generator starting and ,
| |
| 9 local restoration of of f-site power sources. Isolation of t
| |
| 10 reactor coolant pump seal injection, leak-off and thermal 11 barrier cooling. Steam generator isolation by checking the l t
| |
| - 12 MSIV's by pass, main and feedwater reg valves are closed. >
| |
| '% ,/-
| |
| 13 Isolating aux steam to auxiliary support 14 equipment. Venting hydrogen off the main unit. Shutting 15 non-essential DC loads to prolong battery life, and 16 depressurization of the steam generators to approximately I 17 240 pounds per square inch gauge at the maximum rate.
| |
| 18 Depending on the integrity of the reactor-coolant 19 system following the depressurization of the steam 20 generators, the operator's actions are then directed to one 21 of two sub-procedures, ESOBAY 0.1 which is recovery without !
| |
| 22 SI required, or ECA 0.2 which is loss of all AC with SI 23 required.
| |
| 24 During this period of time, the Duquesne Light ,
| |
| 25 system operators have procedures for starting oil-fired t
| |
| ACE-FEDERAL REPORTERS, INC. !
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| '-''mcrysimons 1 peaking units for the priority restoration of power to both 2 of our nuclear facilities within 45 minutes from the event.
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| 3 We believe that the design features discussed, in 4 conjunction with the Westinghouse Owner's Group procedures 5 and testing associated with the reactor coolant pump seals, 6 will resolve the principal issues associated with 7 unresolved safety issue A-44, station blackout, and B-23, 8 reactor coolant pump seal integrity.
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| 9 MR. EBERSOLE : Could you mention what would happen 10 in your depressurization maneuver if some of your PORVs 11 stick open?
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| ,_s 12 MR. GRADA: Well, that's the PORVs on the k_) 13 secondary?
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| 14 MR. EBERSOLE: Yes.
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| 15 MR. GRADA: That's not been looked at, but since 16 the -- you know, two things. One is that you would have 17 manual capability to isolate them, okay?
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| 18 Secondly, during the first stages of the 19 depressurization you are going down at the maximum rate to 20 try to conserve your inventory in the coolant system.
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| 21 MR. EBERSOLE: Why are you depressurizing?
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| 22 MR. GRADA: First of all because you have no means 23 of make-up to the reactor coolant system and you want to 24 limit the imposed differential pressure on --
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| O 25 MR. EBERSOLE: Reduce the primary pressure, right?
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| ACE FEDERAL REPORTERS, INC.
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| 220 03 03 214 mcrysimons 1 MR. GRADA: Reduce the primary pressure so that 2 you reduce the differential pressure across your No. 1 3 seal. You can get into a mode where you can use your 4 accumulators, if necessary.
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| 5 MR. REMIC K: Could you put the slide back on the 6 primary actions?
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| 7 MR. GRADA: Could we have Slide 1, please?
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| 8 (Slide) 9 MR. REMIC K: I assume these are primary actions in 10 the case of what, loss of of f-site power or loss of all --
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| 11 MR. GRA DA: Well, there are two ways that we can 7 '3 12 get into these, okay? If the operator just recognizes a b
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| 13 reactor trip which, you know, loss of off-site power would 14 induce, then he would be in procedure E-00 which more or 15 less replicates these actions.
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| 16 MR. REMIC K: You must have made some assumption up 17 there when you said primary actions. I assume that's loss 18 of off-site power?
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| 19 MR. GRADA: That is correct.
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| 20 MR. REMICK: I don't see on there anywhere that 21 you have -- tha t the turbine-driven main feed pump is on.
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| 22 But you do have auxiliary feedwater flow.
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| 23 MR. GRADA: Well, that's the pump that would be r';)
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| \
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| 24 providing that flow.
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| 25 MR. REMICK: Oh, that is considered one of the ACE FEDERAL REPORTERS, INC.
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| (3 As 9220 04 04 215 marysimons 1 auxiliary --
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| 2 MR. GRADA: Yes, sir. We have two motor-driven 3 ones.
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| 4 MR. REMICK: I guess I misunderstood. I thought 5 your main pumps were two electric driven and the TARY 6 turbine. The TARY turbine is auxiliary. I see, I'm sorry.
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| 7 MR. EBERSOLE: What happens to illumination and 8 communication?
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| 9 MR. GRADA: We have battery powered communication 10 that would be available for a minimum of two hours.
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| 11 MR. EBERSOLE: What about general illumination?
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| g-)/
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| (_
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| 12 MR. GRADA: Go ahead.
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| 13 MR. KURTZ: The light and communication for Beaver 14 2 comes off the Black diesel.
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| 15 MR. GRADA: We have a third on-site non-safety 16 related diesel generator to pick up emergency lighting and -
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| 17 -
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| 18 MR. EBERSOLE: Well, is it on an isolated set of 19 circuits that are not part of the general network and is 20 therefore not involved in total AC failure?
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| 21 Do you invoke the f act that it's not a part of the 22 total AC failure?
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| 23 MR. GRADA: It has battery back-up. Just a 24 minute. There is battery, and it's off the Black diesel.
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| 25 MR. EBERSOLE: So you declare that the Black ACE FEDERAL REPORTERS, INC.
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| 220 04 04 216 marysimons 1 diesel is not a party to total AC power failure.
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| 2 MR. GRADA: Well, by definition it's a loss of, 3 you know, all on-site AC. So, I imagine you would have to 4 assume the sLmultaneous f ailure of three diesel generators.
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| 5 MR. EBERSOLE: I think the rationale there would 6 be, yes, it could be, you know, except it would have to be 7 on its own private network and not a part of a cascade or 8 something. And probably have to have whatever, separa te 9 fuel -- you know wha t I mean.
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| 10 MR. GRADA: It's independent of the energency 11 diesel generators.
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| g'3 12 MR. EBERSOLE: In a general context, how can you L) 13 claim it's not a part of the total AC power failure 14 picture?
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| 15 MR. GRADA: Well, I would assume when the staff 16 issues the -- you know, the resolution of Unresolved Safety 17 Issue 844, that they are going to tell you what you have to 18 assume. You know, I don'.t know, for example, at Beaver 1 19 and 2 that we would have to consider losses of four diesel 20 generators, you know, all four between two plants.
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| 21 MR. EBERSOLE: This Black diesel, where does it 22 get its cooling water?
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| 23 MR. SCHUSTER: It's an air-cooled --
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| 24 MR. EBERSOLE: Oh, it's an air cooled. Good,
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| (]
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| ej 25 great this way.
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| . merysimons 1 MR. GRADA: All of its support equipment --
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| 2 MR. EBERSOLE: It doesn't have any dependencies on '
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| 3 other pumps and things.
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| 4 MR. GRADA: Notning off its substation.
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| 5 MR. EBERSOLE: Thank you.
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| 6 MR. GRADA: I was asked to address a couple of 7 other questions that have come up in the last day or so.
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| 8 MR. KURTZ: I'd like first to point out that those 9 lights, light and communication, is battery backed up 10 also. I don' t know if that came across.
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| 11 MR. GRA DA: The first question, what is the worst rx 12 loss of two batteries, and the answei- is, the No. I and 2 U
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| 13 batteries which are the 1,700 amp hour and principle power 14 sources for the AE --
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| 15 MR. EBERSOLE: If you lose those two, if that's 16 the worst two, what happens?
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| 17 MR. GRADA: Well, you would lose --
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| 18 MR. EB ERSOLE : Can you control aux feedwater and 19 circuit breaker functions, and so forth?
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| 20 MR. GRA DA: We can control aux feedwater without 21 DC power. That was one of the things that I read in NUREG-22 1032 --
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| 23 MR. EBERSOLE: You can?
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| 24 MR. GRADA: --
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| that I didn't understand because in 25 six hours you are losing aux feedwater due to a loss of ACE-FEDERAL REPORTERS, INC.
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| 220 04 04 218 marysimons 1 DC. I didn't understand that.
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| 2 MR. EBERSOLE : Well, isn't it true that aux 3 feedwater, turbine-driven aux feed is dependent on DC?
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| 4 MR. GRADA: No, sir.
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| 5 MR. EBERSOLE: It is not? You don' t need DC to 6 run the aux feed pump?
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| 7 MR. GRADA: No, sir.
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| 8 M R. REMICK: Where would you control that flow, 9 down in the compartment?
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| 10 MR. GRADA: Right at the pump dischargers .
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| 11 MR. EBERSOLE: How do you know what's going on?
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| rg 12 How do you know you are pumping water if you don' t have any
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| (_/
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| 13 DC?
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| 14 MR. GRADA: How do we know that we -- we would be 15 able to interpret through the level indication in the steam 16 generators.
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| 17 MR. EBERSOLE: Does that involve electrical --
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| 18 MR. GRADA: And we would also have aux feedwater
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| , 19 flow instrumentation available. Under a blackout 20 condition, you still have, you know, a minimum -- as I said 21 -- of four hours of DC and your DC power backs up your 22 solid-state inverters which supply your vital 23 instrumenta tion.
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| 24 MR. EBERSOLE: But you don' t need DC specifically
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| (^)T 25 to run the aux feed pumps.
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| ' ACE-FEDERAL REPORTERS, INC.
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| 202 147 3700 Nationwide Coverase 2 336-6646
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| 220 04 04 219 mrrysimons 1 MR. GRADA: Not the turbine driven, and the motor 2 driven, in the absence of DC you can manually cycle the 3 breakers yourself.
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| 4 MR. EBERSOLE: Sure. All right. Thank you.
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| 5 MR. GRADA: Okay, the second question was, do the 6 4 kv penetration breakers and back-up have separate DC 7 power supply. The answer to that is, yes.
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| 8 MR. EBERSOLE: Are they qualified? For instance, 9 like on the main coolant pumps , the circuit breakers are 10 protecting penetrations on those. What's the breakers that 11 protect those penetrations, where are they and what trips
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| ,7 12 them?
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| ~.)
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| 13 MR. GRADA : I'm not familiar with the electrical 14 protection of the 4 6.v --
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| 15 MR. EBERSOLE: Well, generally they would be on
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| ~
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| 16 non-lE boards.
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| 17 MR. GRADA: Yes. Well, yes, they are that. And 18 they would have typically over-current , under-voltage type 19 protection. As far as the qualifications of it, you know, 20 it's a non-lE breaker.
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| 21 MR. EBERSOLE: Does the tripping function come 22 from qualified batteries?
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| 23 MR. GRADA: Yes, sir.
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| ,c3 24 MR. EBERSOLE: Even though it's a non-lE board?
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| V 25 MR. GRADA: Oh, the tripping function. No, I was ACE-FEDERAL REPORTERS, INC.
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| 202 347 ThTe3 PJhtstrw'@faverage CTLN
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| 1 220 04 04 220 marysimons 1 relating to DC. It would come off of batteries 5 and 6 2 which are non-safety related.
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| 3 MR. EBERSOLE: So the electrical over-current 4 protection of the main coolant pump penetrations is derived 5 from non-lE batteries, right?
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| 6 MR. GRADA: I would like to verify that.
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| 7 MR. KURTZ: We can get that information for you 8 later.
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| 9 MR. EBERSOLE : It doesn' t matter a lot except if 10 you are going to have a LOCA with an earthquake.
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| 11 (Laughter)
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| ?-
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| 12 MR. EBERSOLE: In which case you are in trouble.
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| 13 MR. GRADA: But typically you don't run your 14 safety-related battery supplies into non-safety related --
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| 15 MR. EB ERSOLE: Sure.
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| 16 MR. GRADA: The third question was, under what 17 conditions would emergency air lock be used. That would 18 only be in the event that the normal air lock wasn' t 19 available for normal egress or, you know, going in or out 20 of the containment for an emergency condition.
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| 21 And number of reactor trips that Beaver 1 has had 22 this year, the number is eight. Seven of them have been 23 through maintaining and testing equipment. So we are 24 looking especially hard at maintenance and testing.
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| (J~)
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| 25 One other item I wanted to add, something Mr.
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| e^220 04 04 221 O
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| mnrysimons 1 Sieber said earlier when we were talking about how 2 maintenance people wouldn't be working on the wrong piece 3 of equipment.
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| 4 The maintenance people are required to walk down 5 their clearance before they begin work on that component.
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| 6 MR. KERR: Excuse me. I want to make sure I 7 understood what you said about trips. You say you have had 8 eight this year?
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| 9 MR. GRADA: That is correct.
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| 10 MR. KERR: Seven of which were associated with 11 maintenance activities.
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| 12 MR. GRADA: Principally, NCR is doing maintenance 13 surveillance procedures on protection equipment, recorders, 14 solid state inverters.
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| 15 MR. KERR: So if, for example, you somehow could 16 do maintenance when the plant was shut down, you would have 17 avoided seven of these, perhaps.
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| 18 MR. GRADA: Well, most of these are mandated by 19 the technical specifications.
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| 20 MR. KERR: I recognize that.
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| 21 MR. GRADA: Yes, sir, that is correct.
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| 22 MR. REMIC K: That's one reason why I think the 23 maintenance training programs once they are fully 24 implemented probably will have more effect on plant
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| (~}-
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| s-25 reliability than things lixe improved operator licensing ACE-FEDERAL REPORTERS, INC.
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| itM 1J"F MAA Matinniatule Inver2ap Mll[h/t6d[s . . _
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| 220 04 04 222 marysimons 1 training.
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| 2 MR. KERR: That assumes that the maintenance 3 training will prevent spurious trips due to maintenance.
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| 4 MR. REMICK: I'm assuming that, yes.
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| 5 MR. KERR: I really am skeptical that that's the 6 case because I don' t think people are trained to back into l
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| 7 things or untrained to back into things, or to bump against 8 things. That is what happens in a good many cases.
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| 9 MR. REMIC K: It's truly the accidental thing, 10 that's correct. But if it's a case that they haven' t 11 performed that f unction before , if their training isn' t
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| <~ 12 truly performance based, there is a
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| * great chance they are V;
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| 13 going to make an error.
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| 14 MR. GRADA: They have designed the reactor 15 protection system to fail safe and it constantly reminds us 16 that it's doing tha t.
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| 17 (Laughter) 18 MR. EBERSOLE: These trips, they might be trips 19 that are real trips, safety challenges, and they might be 1
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| 20 just spurious trips in which there was nothing wrong except l 21 somebody touched the wrong conduit.
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| 22 MR. GRADA: In no case was there an actual need 23 for a trip.
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| 24 MR. EBERSOLE: An actual need for a trip. So they (v~')
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| 25 are all spurious. Can you give me some sort of a round-ACE-FEDERAL REPORTERS, INC.
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| r0220 04 04 223 (j
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| merysimons 1 house number for the monetary cost of --
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| 2 MR. GRADA: For the what?
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| 3 MR. EBERSOLE: Per trip, the recovery time and the 4 loss of power availability.
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| 5 MR. GRADA: Are we talking about recovery time to 6 establish normal steam generator levels?
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| 7 MR. EBERSOLE: Getting back on line again at full 8 power.
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| 9 MR. GRADA: Oh, getting back on line. About eight 10 hours right now. We used to be able to do two or three 11 start-ups per shift but we have slowed down and made the 12 procedures very comprehensive. So it's about eight hours
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| {~
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| 13 now.
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| 14 MR. EBERSOLE: What would be the monetary cost of 15 a trip, then, on the average?
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| 16 MR. GRADA: The average what?
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| 17 MR. EBERSOLE: The monetary cost of a trip, on the 18 average.
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| 19 MR. SIEBER: This is Jack Sieber.
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| 20 If eight hours is a good time which is a pretty 21 decen't recovery time, that:'s about $70,000.
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| 22 MR. EBERSOLE: How much?
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| 23 MR. SIEBER: $70,000.
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| 24 MR. EBERSOLE: $70,000 per trFin- '
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| [}
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| 25 MR. SIEBER: Right. i l
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| l i
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| ACE-FEDERAL REPORTERS, INC. j cr.msan - - o
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| 220 04 04 224 marysimons 1 MRs EBERSOLE: Thank you.
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| 2 MR. KURTZ: Mr. Chairman, do you prefer we go on 3 to the next speaker?
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| . 4 MR. WYLIE: Yes.
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| 5 MR. KURTZ: The next speaker will be Mr. J. Hultz.
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| 6 (Slide presentation) 7 MR. HULTZ: Good afternoon. I'm J. Hultz, deputy 8 project manager for Construction Liaison Group Duquesne 9 Light. My presentation will be on leak before break 10 applications on Beaver Valley Unit 2.
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| 11 This is otherwise known as alternate pipe rupture f- 12 protection. .
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| (
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| 13 (Slide) 14 The alternate pipe rupture protection applications 15 on Unit 2 are three-fold. The first such application is on 16 the primary coolant loop.
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| 17 This required a schedule exemption to GDC No. 4 18 and has resulted in the elimination of nine rupture 19 restraints and associated impingement shields. ,
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| 20 The second application is in the area of arbitrary 21 intermediate pipe breaks, and this requires an alternate 22 approach to SRP 362, Neb. 3-1. This has resulted in the 23 elimination of 127 rupture restraints in associated jet r^ 24 impalement shields.
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| (>)
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| 25 The last application is on the balance of piping AdE-FEDERAL REPORTERS, INC.
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| 202 347 3700 N h
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| 220 04 04 225 marysimons 1 not covered by the two previous applications. We refer to 2 this program as our whipjet program, and this would result 3 in the elimination of an additional 136 rupture restraints 4 in associated jet i pingement shields.
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| 5 The basic thrust of my presentation today will be 6 on the whipjet program. Briefly, the points to be 7 emphasized concerning the whipjet program are, whipjet is 8 based on the principles of prevention and detection rather 9 than mitigation.
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| 10 The whipjet program is composed of two main 11 activities, determination of applicability to a specific 12 pipe or piping system and implementation of leak before 13 breck approach after we have determined its applicability.
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| 14 During the determination of applicability phase, 15 we would determine the extent that conditions are 16 acceptable for applying fracture mechanics. This involves 17 review of stress corrosion, water hammer fatigue, and 18 component support failure.
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| 19 During the implementation of the leak before break 20 phase, we will analyze the breaks to show that large flaws 21 are stable and that large flaws follow leak before break 22 patterns, and that leaks can be detected.
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| 23 This involves review of leak before break 24 scenarios , leakage detection scenarios , and specific cost-25 benefit analyses.
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| ACE-FEDERAL REPORTERS, INC.
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| '_)arysimons1 m If the above conditions are not satisfied, then we 2 would revert to conventional methods as outlined in MEB 3-1 3 and whether or not the whipjet program is implemented, the 4 EQ or environmental qualification design basis for the 5 plant will not change.
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| 6 A brief summary of the events to date can be 7 -summarized as follows: Since early 1970s, Westinghouse has 8 conducted extensive R&D efforts on fracture mechanics. The 9 Westinghouse A-2 Owner's Group ef fort has resulted in NRC 10 letter 8404 which endorses leak before break approach to 11 resolution of Issue A-2.
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| fs 12 NUREG-0161 endorses leak before break approaches d 13 as an alternative to postulating pipe ruptures. Duquesne 14 Light has been granted relief to the arbitrary intermediate 15 pipe break requirement in May 1985 and we were granted a 16 schedular exemption to GDC No. 4, and on primary loop on 17 October 11, 1985, 18 With regard specifically to whipjet, the following 19 status is provided: Duquesne met with NRR on August 27, 20 1985 to initially present our program. We supplied and 21 filed a general description to NRR on September 6,1985.
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| 22 Duquesne and its consultants met with the ACRS 23 subcommittee on September 24, 1985 to present the basis for 24 our whipj et program. On October 10, 1985, Duquesne filed 25 the detailed technical program description with NRR.
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| ACE-FEDERAL REPORTERS, INC.
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| )
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| l 220 04 04 227 mnrysimons 1 What we hope to accomplish is, we want the NRC to 2 provide concurrence with the program on or before December 3 1985. Duquesne will proceed with the whipjet program and 4 file tests and analyses with the Commission by December 5 1986.
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| 6 The NRC will review the results and either concur 7 with the results, which will allow licensing of the plant 8 without restraints installed, or provide schedular relief 9 for ultimate installation of the restraints.
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| 10 This review and subsequent action is scheduled to 11 occur in early 1987.
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| ,~) 12 In summary, the application of whipjet results in V
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| 13 decreased radiation exposure to the plant staff, which is a 14 net safety benefit, improved plant accessibility for 15 operation and maintenance, and decreased cost for 16 construction and operation of the plant.
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| 17 We are currently waiting for NRC concurrence to 18 our whipjet program and the program to be successful 19 requires prompt attention by the NRC and approval by 20 December 1985.
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| 21 Whipjet will result in the elimination of a 22 majority of the 137 balance of plant rupture restraints and 23 jet impingement shields, covering approximately 690 gs 24 breaks. Whipjet may not apply to all situations and where i
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| 25 it does not, then standard practice will be implemented.
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| ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 .NationwideCoveg _ 800-336-6646
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| 220 04 04 228 mnrysimons 1 However, this would require a phase-in or 2 schedular approach over several refuelings to complete 3 restraint installation. l l
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| 4 That completes my formal presentation. '
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| 5 MR. WYLIE: Thank you. Any questions?
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| 6 MR. CAREY: Yes, I would like to make a comment 7 about this whipjet program. We feel it is an important 8 program and that we will be developing information that 9 will certainly be valuable to the entire industry.
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| 10 But we are not in the research business and we are 11 doing this program because we feel that it is cost-
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| : n. 12 e f f ec tive. But if we can' t get some type of a resolution
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| () 13 by no later than the first quarter of 1986, since we are 14 totally committed to making our existing fuel load 15 schedule, that we would just abandon this program, put in 16 these pipe whip restraints and forget about it.
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| 17 MR. KERR: Does the NRC staf f have any comment?
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| 18 What is the current position?
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| 19 MR. KNIGHTON: Let me respond. Yes, we did have a 20 meeting and they presented what they would propose to do.
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| 21 Staf f did advise them of what it would appear to the staff 22 today to be a rather difficult task because you now get 23 into areas where you have dif ferent materials than we have p 24 been currently looking at under GDC-4.
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| V 25 We really couldn' t give them any real confidence ACE FEDERAL REPORTERS, INC.
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| _ KNXfP-Hia_ ___ _ _ __ StMEt'b@me~3 GNEC"3
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| 220 04 04 229 mrarysimons 1 that we can meet the tight schedule they have. So I think 2 what we did commit to was to try to get back to you on the 3 program which you submitted, you know, as to whether it has 4 all the pieces in it. That, I think, is our next step.
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| 5 You have it in and the staff is looking at it.
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| 6 MR. CAREY: Well, as I see it, that is the next 7 step. But the final step is if we can receive the 8 schedular exemption so that any f urther delays will not 9 interfere with our fuel load, then we would have no choice 10 but to install these whip restraints to satisfy the 11 existing. criteria.
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| g-) 12 On that basis we certainly would not proceed with V
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| 13 the program to its completion.
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| 14 MR. KNIGHTON: Okay. But now, I thought you made 15 a comment that you needed the staff's position by the first 16 quarter?
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| 17 MR. CAREY: No, no. I needed the schedular 18 exemption issues by the first quarter.
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| 19 MR. KNIGHTON: Of '867 20 MR. CAREY: That's correct, the first quarter of 21 '86.
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| 22 MR. KNIGHTON: I was not aware of that in the 23 meeting that we attended. I would find it, you know, a
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| <s 24 very dif ficult thing for the staf f to meet in the first t
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| . 25 quarter of '86. So, you might want to come back and talk ACE-FEDERAL REPORTERS, INC.
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| 202 3FAE rsem2'4Fsite, N
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| 220 04 04 230 marysimons 1 to the staf f on that particular issue.
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| 2 MR. SINGH: Let me add tha t, you know, the meeting 3 that took place with the applicant and ACRS, the staff 4 wanted some guidance from ACRS also, you know, what's their 5 feeling to this program.
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| 6 I don' t know if the staf f received any guldmaca 7 from SERS.
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| 8 MR. KERR: When was the meeting with the ACRS?
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| 9 MR. SINGH: I think it was in September, September 10 26.
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| 11 MR. KERR: Was that a subcommittee or a full f3 12 committee meeting?
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| V 13 MR. SINGH: It was a subcommittee. It was 14 basically for whipjet program only, and I think for three 15 plants, Beaver Valley and Vogel has got some other two 16 plants.
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| 17 MR. KERR: Did you ask the ACRS for comments? I 'm 18 just trying to take back a message to the committee if 19 there has been some breakdown in communication.
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| 20 MR. SINGH: Yes. I'm not following that one too 21 much because Mr. Bosnak, he is the one who is in charge of 22 following it. But I was in the meeting and I just heard 23 that he wanted some sort of feel from the ACRS people. I
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| (^)
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| wi 24 don' t think that he has heard anything f rom the ACRS.
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| 25 MR. KURTZ: The subcommittee endorsed fully the ACE-FEDERAL REPORTERS, INC.
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| 202:347-3700 NationwidtCozerage _ _8004 36-6646
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| 220 04 04 231 mr.rysimons 1 presentation. We had Mr. Clyde make the presentation on 2 the philosophy, and I believe Mr. Ebersole was there.
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| 3 MR. EBERSOLE: Yes.
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| 4 MR. KURTZ: And the subcommittee totally endorsed 5 it.
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| 6 MR. EBERSOLE : Yes, they endorsed the whole 7 program.
| |
| 8 One of the fuzzy parts of this though is, what 9 about extrapolating the notion of this leak before break 10 back into the secondary and tertiary systems where the OA 11 is not near so high as in the primary piping. What is the w 12 staff's thought about that? Is that an ongoing effort?
| |
| 13 MR. KNIGHTON: I really can't answer you too well 14 on that. It's my understanding that that was one of their i5 conc 5rns.
| |
| 16 MR. EBERSOLE : I thought it was well supported as 17 long as you stick into the primary loop.
| |
| 18 MR. KERR: Let me try to pursue it, though. I 19 think usually if the staff wants some sort of formal 20 response from the committee, that this normally comes from 21 the committee in the form of a letter and not from a 22 subcommittee.
| |
| 23 So if tt.e staf f does want something from the r's 24 committee , there should be some communication.
| |
| (_)
| |
| 25 MR. KNIGHTON: It was just an information ACE-FEDERAL REPORTERS, INC.
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| R4237-3700 Nationwide CoGe~3 800-336-6646
| |
| | |
| ,_9220 04 04 232 I I
| |
| ''' arysimons m 1 meeting. We'll take that message home.
| |
| 2 MR. HERNAN: This is Ron Hernan with the staff.
| |
| 3 I'd like to clarify things a little bit.
| |
| 4 We did present the program that we are pursuing on 5 rulemaking to the subcommittee . We did not formally ask 6 for a letter to give us specific guidance or to endorse.
| |
| 7 MR. EBERSOLE: Right.
| |
| 8 MR. HERNAN: But as the applicant has stated, I 9 think the subcommittee did -- in spirit at least -- endorse 10 the direction we are headed.
| |
| 11 MR. EBERSOLE: I thought it was a well received 7- 12 information meeting.
| |
| (J 13 MR. HERNAN: I'm not sure how that fits in with 14 Duquesne's request, but we would hope to have Mr. Bosnak 15 come to the full committe = meeting and try to clarify this.
| |
| 16 M R. KERR: Okay, thank you.
| |
| 17 MR. KURTZ: We have a couple things we would like 18 to wrap up.
| |
| 19 MR. KERR: Before you wrap up, I have a couple of 20 questions. Let me ask them and they may be something you 21 can answer very briefly.
| |
| 22 Number one, in the course of looking at station 23 blackout you did conclude, I think from what was said, that 24 the likelihood of loss of all AC was low, a
| |
| 25 Was any ef fort made to calculate the frequency or ACE-FEDERAL REPORTERS, INC.
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| 202 347 3700 Nationwide Coverage 800 336-6646
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| | |
| 9220 04 04 233
| |
| (~)#
| |
| That's the first
| |
| ''ccrysimons 1 did you just assume it was very low?
| |
| 2 question.
| |
| 3 The second one is, do you have as part of your 4 emergency operation procedures a procedure for feed and 5 bleed, or bleed and feed as it is called?
| |
| 6 MR. GRADA: I'll take the second question first.
| |
| 7 In the what they call the critical safety function status 8 trees, if you get into what's called a " red path," which is 9 your highest level type problem, if you get in the red path 10 for core cooling which is defined as your core exit 11 thermocouple indication be it in excess of 1200 degrees or 12 level indication below a specific level, accompanied with 13 thermocouples in excess of 700 degrees, that puts you into 14 a what they call function restoration procedure.
| |
| 15 And that's where you would enter the bleed and 16 feed mode.
| |
| 17 MR. KERR: So I think the answer is, yes.
| |
| 18 MR. GRADA: And loss of heat sink also.
| |
| 19 MR. KERR: That is part of your emergency - you 20 do have something in your emergency procedures that would 21 lead to there then in an extreme emergency situation.
| |
| 22 MR. GRADA: That is correct.
| |
| 23 MR. KERR: Thank you.
| |
| 24 MR. EB ERSOLE: One little question about the PORVs O 25 which you qualified to safety grade. Did you also qualify ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwidc Coverage 800 336-6646
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| | |
| 220 04 04 234 m rysimons 1 the block valve?
| |
| 2 MR. GRADA: Block valves have an automatic closure 3 if you are below the P-ll setpoint which is hpproximately 4 2000 pounds and the valves automatically go closed.
| |
| 5 MR. EBERSOLE : Well, that was the point I was 6 coming to. If you have bleed-feed in and you have 7 automatic closure and they are not qualified --
| |
| 8 MR. GRADA: That's only in auto. The operator can 9 override that.
| |
| 10 MR. EBERSOLE: What's that?
| |
| 11 MR. GRA DA: The operator can override it.
| |
| (, 12 MR. EBERSOLE: Oh, okay. .
| |
| The operator can U
| |
| 13 override it?
| |
| 14 MR. GRADA: That's correct.
| |
| 15 MR. EBERSOLE: Is it environmentally qualified for 16 the environment which bleed-feed will produce?
| |
| 17 MR. KURTZ: We think so. We are trying to 18 determine the facts of that. But we believe it i- But in 19 a few minutes we'll know for sure.
| |
| 20 MR. EBERSOLE: I see. So now you can tell me that 21 you can bleed feed and -- and make it hot and wet, and damp 22 and so forth, and these solenoid-operated valves will 23 continue to f unction; is that right?
| |
| (~') 24 MR. KURTZ: That's correct.
| |
| t
| |
| \.J 25 MR. GRA DA: And addressing the first question, the ACE-FEDERAL REPORTERS, INC.
| |
| 202-147 -17CO Nationwide _ Coverage 800-336-6646
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| | |
| . 9220 04.04 235
| |
| )
| |
| merysimons 1 _ probability of a blackout, we had an individual _take a look 2 .at it and we looked at outage rates .e,mong the utilities 3 that are tied into ECAR and compared ith those companies 4 which represent about 98,000 megawatts in nine states or 5 parts of those states.
| |
| 6 They had averaged like 38 hours per hundred miles 7 of transmission line and we at Duquesne Light were 8 approximately eleven.
| |
| 9 So you can draw on that. Again, I think it's 10 important to recognize that any of these six 345 kv lines 11 that just about leave - the plant, you know, in all 12 directions --
| |
| ' O 13 MR. KERR: I'm not trying to urge you to make the 14 calculation if you haven't made it. I was just curious as 15 to whether you had made it.
| |
| 16 MR. GRADA: Well, the number that he came up with 17 was like beyond ice age --
| |
| 18 (Laughter 19 MR. GRADA: -- type probabilities and that's why 20 we didn't' want to mention it.
| |
| 21 That's due to normal outage-type maintenance. I 22 mean, we haven't had severe weather type problems within 23 our area.
| |
| 24 MR. MARTIN: We feel comfortably assured -- this 0 25 'is Roger Martin -- we feel comfortably assured that the ACE-FEDERAL REPORTERS, INC.
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| 202-347-3700 Nationwide Coverage 800 336 6646
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| | |
| 220 04 04 236 merysimons 1 occurrence is very remote , having the other company inter-2 connections within the maximum of 15 to 20 miles from the 3 Beaver Valley site.
| |
| 4 MR. KERR: I like things that give me warm 5 feelings, and I'm not responsible for a utility. But if I 6 were, I believe I would give more thought to the 7 availability of electric power than almost any other one 8 thing.
| |
| 9 MR. MARTIN: Yes, we recognize that.
| |
| 10 MR. KERR: Because there are so many things you 11 lose -- and I guess you have. I'm skeptical when I hear 7
| |
| 12 numbers that say it's about the frequency of the last ice U
| |
| 13 age because that says to me somebody did a calculation 14 which assumed that a lot of things are independent.
| |
| 15 MR. MARTIN: That's why we didn't present that 16 number.
| |
| 17 MR. KERR: And we've learned that that's not going 18 to occur. Again, it may not be worth the effort to try to 19 calculate it. I was just curious.
| |
| 20 MR. GRADA: Well, the number that he came up with 21 for the loss of one 345 kv line, based on historic records, 22 was ten to the minus fourth.
| |
| 23 Again, we have six of those lines connected to our
| |
| (~N 24 switch yard and 33 8 kv. Any one of those lines --
| |
| G 25 MR. KERR: He knows, I presume, that there was a ACE-FEDERAL REPORTERS, INC.
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| 202447c3700 Nationwide Coverage 800-336-6646
| |
| | |
| J_ - - >
| |
| 237
| |
| ,,9220 04 04 m2rysimons 1 tornado what was it, Quad Cities, that took out five 2 lines. So it does not make sense to assume that lines that 3 close together are independent because a tornado can 4 destroy them pretty readily.
| |
| 5 But again, that's enough. I was just curious.
| |
| 6 MR. KURTZ: We can go on to some of these other 7 issues here. One of the questions that's left from the 8 tour was the date of manuf acture of the reactor vessel, and 9 it began manufacture in 1971. It was shipped in 1978, and 10 it was built to 1972 code addenda, 11 We had a request for emergency procedure. We 12 would like to bring that procedure to the f ull committee 13 with us.
| |
| 14 MR. EBERSOLE: That will be fine. Thank you.
| |
| 15 MR. KURTZ: Roger Martin has some information on 16 the containment liner he would like to go over very l
| |
| l 17 briefly.
| |
| l l 18 MR. MARTIN: Is that viewgraph available on the i
| |
| 19 containment liner?
| |
| 20 Our support behind the scenes here has provided us l 21 with this. I believe, Mr. Ebersole, your question was i
| |
| l 22 about possible buckling of the containment liner.
| |
| 23 MR. EBERSOLE: Yes.
| |
| 73 24 MR. MARTIN: We have done an analysis assuming k-) 25 that the minimum spray temperature was 45 degrees l
| |
| ACE-FEDERAL REPORTERS, INC.
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| i 202-347-3700 Nationwide Coverage 800-33M
| |
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| +9220 04 04 238
| |
| '"mrrysimons 1 Fahrenheit, that the maximum initial atmospheric
| |
| .2 temperature in the containment was 105 degrees, also 3 assuming that the spray causes the atmosphere to go down to 4 45 degrees Fahrenheit, assuming no metal or no heat source 5 is in the containment to take away heat and no operator 6 action.
| |
| 7 The results are a minimum of 8.1 PSI attained. -
| |
| 8 Therefore, we have calculated the stress to be one-half the 9 buckling stress of the metal in the containment liner.
| |
| 10 MR. EB ERSOLE: Even if it were not supported to 11 .the concrete?
| |
| 12 MR. MARTIN: Yes.
| |
| 13 MR. EBERSOLE: Oh, well, gee.
| |
| 14 MR. MARTIN: This is the ultimate -- it's the 15 given strength of the material, the metal itself.
| |
| 16 MR. EB ERSOLE: It is fastened to the concrete, 17 isn't it? Or is it? Or does it float?
| |
| 18 MR. MARTIN: The concrete is placed around the 19 containment liner.
| |
| 20 MR. EBERSOLE: Is it anchored to it?
| |
| 21 MR. MARTIN: There are studs there.
| |
| 22 MR. MARTIN: It's studded to the containment
| |
| ~
| |
| 23 itself.
| |
| 24 MR. MARTIN: It's studded to the concrete.
| |
| O 25 MR. EBERSOLE: And the concrete will support it.
| |
| ACE-FEDERAL REPORTERS, INC.
| |
| 202-347-3700 Nationwide Coverage 800 316-6646
| |
| | |
| 1 i
| |
| ,.220 9
| |
| 04 04 239 merysimons 1 MR. MARTIN: Yes.
| |
| I 2 MR. EBERSOLE: Oh, well, thank you. !
| |
| 3 MR. MARTIN: You're welcome.
| |
| 4 MR. KURTZ: With that, I'd like to turn the 5 microphone over to Mr. Jack Carey.
| |
| 6 MR. CAREY: I'd like to thank you gentlemen for 7 listening to the story of Beaver Valley.
| |
| 8 I would like to note that all of the presentations
| |
| -9 today have been made by Duquesne Light Company personnel.
| |
| 10 We believe that certainly we do have the experience and a 11 suf ficient number of knowledgeable and trained personnel to 12 successfully start up and operate the Beaver Valley No. 2 0_ 13 unit.
| |
| 14 MR. WYLIE: Well, I'd like to thank the applicant 15 for his presentation this afternoon and this morning, and 16 ask the subcommittee if they have any other questions.
| |
| 17 MR. EBERSOLE: I have no further questions.
| |
| 18 MR. KERR: I have none.
| |
| 19 MR. REMICK: I don't have a question, but I have a 20 comment. I wish to compliment you for the arrangements for 21 this meeting today. I think somebody thought out very 22 carefully the needs and took care with microphones.
| |
| 23 So, certainly I think it's been a very ef fective 24 subcommittee meeting because somebody paid a lot of 25 attention to details on microphones and projection. It was ACE-FEDERAL REPORTERS, INC.
| |
| 202 347-3700 Nationwide Coverage 80 4 336-6646 ,
| |
| | |
| l l
| |
| 9220 04 04 240 l marysimons 1 very easy from our standpoint. 1 2 MR. EBERSOLE: I'd like to compliment you on the 3 electric feed pumps and the 90-percent by-pass. ,
| |
| 4 (Laughter) 5 M R. WYLIE: Well, we have scheduled on November 8 -
| |
| 6 - that's a Friday -- three hours in the afternoon, 7 beginning at 2: 30, for the full committee to review the 8 license and the applicant to make a presentation to the 9 full committee.
| |
| 10 We will be discussing with you over the phone 11 between now and Monday the agenda for that meeting. We 12 have spent seven hours here today. We've got three hours O 13 allotted, so we have to do some scheduling.
| |
| 14 MR. KERR: The English language is so redundant 15 t"at you can do that by removing every other word.
| |
| 16 (Laughter)?
| |
| 17 MR. WYLIE: So, we would like to thank you, and 18 I'll now call th'e meeting adjourned. Thank you.
| |
| 19 (Whereupon, at 3: 25 p.m. , the meeting of the 20 subcommittee was adjourned.)
| |
| 21 22 23 24
| |
| -( 25 ACE-FEDERAL REPORTERS, INC.
| |
| 202-347-3700 Nationwide Coverage 800-336-6646
| |
| | |
| i
| |
| \
| |
| CERTIFICATE OF OFFICIAL REPORTER .
| |
| (
| |
| V This is' to certify that the attached proceedings before the UNITED STATES NUCLEAR REGULATORY COMMISSION in the matter of:
| |
| NAME OF. PROCEEDING: ADVISORY COMMITTEE ON REACTOR SAFEGUARDS SUBCOMMITTEE ON BEAVER VALLEY POWER STATION, UNIT 2 DOCKET NO.:
| |
| PLACE: PITTSBURGH, PENNSYLVANIA DATE: FRIDAY, NOVEMBER 1, 1985 were held as herein appears, and that this is the original transcript thereof for the file of the United States Nuclear Regulatory Commission.
| |
| (sigt)
| |
| (TYPED)
| |
| MARY SIMONS Official Reporter Ace-Federal Reporters, Inc.
| |
| Reporter's Affiliation T
| |
| 4+
| |
| O
| |
| - - - - , . , - - , . , . , -. , -, , , , . - ,, ,_,.,.m. -- - - . , . - - . . , - . . , . . - , - -
| |
| | |
| AGENDA BEAVER VALLEY UNIT NO. 2 e PITTSBURGH, PA NOVEMBER 1,1985 8:30 Opening Remarks C. Wylie, Chairman ACRS Subcommittee APPLICANT.P_RESENTATION 3:40 Overview of Plant Layout J. J. Carey 9:00 Design Differences R. E. Martin 9:10 Construction Status anc Plant R. J. Swiderski Startup Schedule 9:25 Organization and Management e Management Philosophy J. J. Carey e Corporate and Nuclear Organization J. Sieber e Plant Staffing T. Jones 10:10 Emergency Operating Procedures F. D. Schuster 10:30 BREAK NRC STAFF _ PRESENTATION 10:45 Major Differing Technical Issues 8. K. Singh and Schedule for Resolution 11:00 Construction Experience E. Wenzinger 11:45 Backfit Items and Resolution 8. K. Singh 12:00 Significant Confirmatory Issues B. K. Singh and Licensing Conditions 12:15 LUNCH to 1:15 APPLICANT P_RESENTATION_
| |
| 1:15 Quality Assurance C. E. Ewing e Overview of Policy and Organization e Operational Quality Assurance O o Quality Control Problems Experienced During Construction and Resolution
| |
| | |
| 1 AGENDA l BEAVER VALLEY UNIT NO. 2 PITTSBURGH, PA g/ NOVEMBER 1,1985 (continued) f i
| |
| 2:00 Training T. Burns e Simulator e Initial Operator Training Program o Requalification Training Program o Training for Non-Licensed Personnel 2:45 BREAK 3:00 Decay Heat Removal / Cold Shutdown R. Fedin I
| |
| 3:20 Emergency / Alternate Shutdown Panels E. Eilmann 3:40 Station Blackout K. D. Grada 4:00 Alternative Pipe Rupture Protection J. A. Hultz )
| |
| 4:30 SUBCOMMITTEE DISCUSSION ACRS 5:00 ADJOURN E
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| p.:+..
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| |
| : 3. , u,.t .g n,/ j W.,.c. M. ;,@C;%_Ls4%ueuw.w-.'- .n. ;- i. --. -
| |
| gu nnn p p -f. p+v'' +y :. -
| |
| .u wen;@m,>*y.a3;pe;,c.! j:p W; ~- ^
| |
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| |
| 4 q
| |
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| |
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| |
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| |
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| |
| . %e "'
| |
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| +
| |
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| |
| - ^ ~ +
| |
| wc __ __; we,. (, ,-
| |
| | |
| i Table 1.4 (Continued) p j Issue SER section (38) Vibration of instruments and controls on diesel generators 9.5.4.1 i (39) Surveillance of lube oil level in the diesel generator 9.5.6 rocker arm lube oil reservoir (40) Solid waste process control program 11.4.2 (41) TMI Action Plan items (a) 111. D.1.1 13.5.2 l
| |
| i (b) II.K.1.5 and II.K.1.10 15.9.2, 15.9.3 (c) II.K.3.5 15.9.9 (d) II.K.3.17 15.9.11 (e) II.K.3.31 15.9.14 (42) Plant-specific dropped rod analysis 15.4.3 (43) Steam generator tube rupture 15.6.3
| |
| ~
| |
| (44) Quality assuranco program 17.4
| |
| (%,
| |
| V Table 1.5 License condition item License condition SER section (1) Emergency response capability, RG 1.97, Rev. 2 requirements 7.5.2.1 l
| |
| p J V
| |
| Peaver Valley 2 SER l-21
| |
| _ _ _ _ _ _ -i
| |
| | |
| ,/-~m
| |
| ~.)
| |
| NRR STAFF PRESENTATION TO THE l ACRS
| |
| | |
| ==SUBJECT:==
| |
| BEAVER VALLEY POWER STATION, UNIT 2 DATE: NOVEMBER 1, 1985 Ox-PRESENTER: BRAJ K. SINGH PRESENTER'S TITLE / BRANCH / DIVISION: PROJECT MANAGER, LICENSING BRANCH N0, 3 DIVISION OF LICENSING PRESENTER'S NRC TELEPHONE NUMBER: 492-8423 SUBCOMMITTEE: BEAVER VALLEY
| |
| (~J
| |
| ~
| |
| | |
| c~
| |
| }{]j LICENSING OVERVIEW CONSTRUCTION PERMIT ISSUED MAY 3, 1974 FSAR DOCKETED MAY 18, 1983
| |
| . ENVIRONMENTAL REPORT DOCKETED MAY 18, 1983 DES ISSUED DECEMBER 1984 O 1 FES ISSUED SEPTEMBER 1985
| |
| .l SER ISSUED OCTOBER 1985 FUEL LOAD APRIL 1987 11 OPEN ITEMS 44 CONFIRMATORY ITEMS O -*
| |
| 1 LICENSE CONDITION
| |
| | |
| O ITEMS FOR DISCllSSION
| |
| : 1. OPEN ISSUES AND ESTIMATED RESOLilTION DATE
| |
| : 2. SIGNIFICANT BACKFIT ISSUES
| |
| : 3. SIGNIFICANT CONFIRMATORY ISSUES O 4. LICENSE CONDITION ITEM 1
| |
| O
| |
| | |
| m m OPEN ISS!!ES j J j ESTIMATED ISSllE SER SECTION RESOLUTION DATE i
| |
| > .l 1, PRESERVICE/ INSERVICE 3,9,6 12/31/86 TESTING 2 PilMP AND VALVE LEAK 3,9,6 3/31/86 TESTING
| |
| : 3. INADEQUATE CORE COOLING 4,4,7 3/31/86 (g INSTRUMENTATION (ITEM II F.2 0F NUREG-0737)
| |
| : 4. PRESERVICE/ INSERVICE 5.2.4.3, 12/31/86 INSPECTION PROGRAM 5,4,2,2, 6,6
| |
| : 5. SAFE AND ALTERNATE 9,5.1 12/31/86 SHUTDOWN 6, MANAGEMENT AND 13,1 MO RESPONSE ORGANIZATION FROM APPL.iCANT
| |
| : 7. CROSS-TRAINING PROGRAM 13,2,1,2 6/30/86 O
| |
| 8 EMERGENCY PREPAREDNESS 13,3,3 12/31/86 PLAN
| |
| | |
| , L)
| |
| ESLIMATED ISSUE SER SECTION RESOLUTION DTD,
| |
| : 9. INITIAL TEST PROGRAM 14 3/31/86
| |
| : 10. CONTROL ROOM DESIGN 18,1 7/31/86 REVIEW 11 SAFETY PARAMETER 18,'2 7/31/86
| |
| ,o DISPLAY SYSTEM wi V(D
| |
| | |
| SIGNIFICANT BACKFIT ISSllES
| |
| : 1. STEAM GENERATOR LEVEL CONTROL AND PROTECTION
| |
| : 2. FIRE SUPPRESSION IN THE CABLE SPREADING ROOM 6
| |
| O l
| |
| l O
| |
| | |
| SIGNIFICANT CONFIRMATORY ISSUES
| |
| : 1. S0ll-STRUCTilRE INTERACTION ANALYSIS
| |
| ~
| |
| : 2. SEISMIC AND DYNAMIC QUALIFICATION OF MECHANICAL AND ELECTRICAL EQUIPMENT l
| |
| 3, PUMP AND VALVE OPERABILITY ASSURANCE 4, ENVIRONMENTAL QUAllFICATION OF MECHANICAL AND ELECTRICAL EQUIPMENT ,
| |
| ' '^ ^""
| |
| O 5- ^"^''8'8 " ' ""'"' 8''8"'' ' ^ 8
| |
| : 6. STEAM GENERATOR TUBE RUPTURE
| |
| : 7. QUALITY ASSURANCE PROGRAM O
| |
| | |
| LICENSE CONDITION ITEM LICENSE CONDITION SER SECTION (1) EMERGENCY RESPONSE CAPABILITY, RG 1.97, 7,5.2.1 REV 2 REQUIREMENTS Il0 0
| |
| O
| |
| | |
| 1 fw Table 1.3 Backfit issues b
| |
| Issue SER section Status" (1) Snow and ice load 2.3.1 C i (2) Underestimation of atmospheric dispersion C conditions (X/Q) at exclusion area boundary and consequences of radioactive release 2.3.4,.15.4.8
| |
| ! (3) Potential for flooding from probable maximum precipitation and Peggs Run 2.4.2, 2.4.10 C (4) Steam generator level control and protection 7.3.3.12 A (5) Motor-operated accumulator isolation valve 8.3.1.12 C (6) Spent fuel pool maximum heat load 9.1.3 C l
| |
| l (7) Fire suppression in the cable spreading room 9.5.1.6 A l
| |
| l (8) Class 1E power for lighting and communication l systems 9.5.2.1 C (9) Application of GDC 5 to communication systems 9.5.2.1 C O cio) aaaiic ti tion systems er coc 2 d coc 4 to co #eic -
| |
| 9.5.2 C (11) Application of GDC 4 to lighting systems 9.5.3 C (12) Illumination levels in excess of SRP criteria 9.5.3 C F (13) Application of RG 1.26 to areas excluded by i
| |
| RG 1.26 9.5.4-9.5.8 C (14) Air dryers for emergency diesel generator 9.5.6 C (15) Alarm for rocker are lube oil reservoir 9.5.7 C I
| |
| l (16) Diesel lube oil fill procedure 9.5.7 C
| |
| *A - Issues were discussed in appeal meetings and resolutions are addressed in i the SER, C - Closed in SER.
| |
| O -
| |
| 1 Beaver Valley 2 SER 1-18 I i
| |
| i.
| |
| | |
| Table 1.4 Confirmatory issues Issue SER section (1) Operating procedures for continuous communication links 2.2.2
| |
| : g. g (2) Differential settlements of buried pipes 2.5.4.5 (3) Internally generated missiles (outside containment) 3.5.1.1 (4) Internally generated missiles (inside contair. ment) 3.5.1.2 (5) Turbine missiles 3.5.1.3 (6) Analysis of pipe-break protection outs.ide containment 3.6.1 (7) FSAR drawings of break locations 3.6.2 (8) Results of jet impingement effects 3.6.2 (9) Soil-structure interaction analysis 3.7.3 (10) Design documentation of ASME Code components 3.9.3.1 (11) Item II.D.1 of NUREG-0737 3.9.3.2
| |
| /
| |
| (12) Seismic and dynamic qualification of mechanical and electrical equipment 3.10.1 (13) Pump and valve operability assurance 3.10.2 (14) Environmental qualification of mechanical and electrical equipment 3.11 (15) Peak pellet design basis 4.2.1 (16) Discrepancies in the FSAR 4.2.2 (17) Rod bowing analysis 4.2.3.1(6)
| |
| (18) Fuel rod internal pressure 4.2.3.1(8)
| |
| (19) Predicted cladding collapse time 4.2.3.2(2)
| |
| (20) Use of the square-root of-the-sum of-the-squares method for seismic and loss-of-coolant-accident load calculation 4.2.3.3(4)
| |
| (21) Analysis of combined loss-of-coolant-accident and 4.2.3.3(4) seismic loads (22) Natural circulation test 5.4.7.5 8eaver Valley 2 SER 1-19
| |
| | |
| p Table 1.4 (Continued)
| |
| 'O Issue SER section (23) Reactor coolant system high point vents 5.4.12 (24) Blowdown mass and energy release analysis methodology 6.2.1.3 (25) Contairment sump 50% blockage assumption 6.2.2 (26) Design modification of automatic reactor trip using shunt coil trip attachment 7.2.2.3 (27) Automatic opening of service water system valves MOV 113C and 113D 7.3.3.10 (28) IE Bulletin 80-06 concerns 7.3.3.13 (29) NUPEG-0737 Item II.F.1, accident monitoring instrumentation positions 7.5.2.2 (30) Bypass and inoperative status panel 7.5.2.4 (31) Revision of the FSAR--cold leg accumulator motor- .
| |
| operated valve position indication 7.6.2.4 (32) Control system failure caused by malfunctions of common power source or instrument line 7.7.2.3 (33) Ccnfirmatory site visit (a) Independence of offsite power circuits between the switchyard and Class 1E system 8.2.2.3 (b) Confirmation of the protective bypass 8.3.1.2 (c) Verification of DG start and load tests 8.3.1.8 (d) DG load capability qualification test 8. 3.1. 9 (e) Margin qualification test 8.3.1.10 (f) Electrical interconnection between redundant Class 1E buses P.3.1.13 (g) Verification of electrical independence between power supplies to controls in control room and remote locations 8.3.3.5 (34) Voltage analysis--verification of test results 8.3.1.1 (35) Documentation of description and analysis of compliance with GDC 50 8.3.3.7.1 (36) Completion of plant-specific core damage estimate procedure before fuel load 9.3.2.2 f) (37) Training program for the operation and maintenance of the V diesel generators 9.5.4.1
| |
| .y Beaver Valley 2 SER 1-20
| |
| | |
| o ON REACTOR SAFEGUARDS i
| |
| Subcommittee Meeting Nov.1,1985 l
| |
| iO
| |
| ( l BEAVER 'VALLEY POWER STATION UNIT 2 l
| |
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| |
| J.J. CAREY VICE PRESIDENT NUCLEAR GROUP SITE CHARACTERISTICS
| |
| | |
| ; O O #
| |
| l NORTH AMERICAN ELECTRIC RELIABILITY COUNCIL f
| |
| 0 , s, l
| |
| i 7 s @
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| ! < NPCC i
| |
| /l '
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| - '\ MAAC WSCC ECAR
| |
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| l SPP j-l ~h ERCOTsk__
| |
| l 1 ECAR MAIN SERC EAST CENTRAL AREA RELIABILITY MID-AMERICA INTERPOOL NETWORK SOUTHEASTERN ELECTRIC RELIABILITY COORDINATION AGREEMENT '
| |
| j MAPP 1 ERCOT MID-CONTINENT AREA POWER POOL SPP ELECTRIC RELIABILITY COUNCIL SOUTHWEST POWER POOL O HEAST POWER COORDINATING WSCC MAAC COUNCIL WESTERN SYSTEMS COORDINATING MID-ATLANTIC AREA COUNCIL COUNCIL
| |
| | |
| CAPCO POWER POOL e
| |
| i Cleveland Electric Illuminating Co.
| |
| 4 Duquesne Light Co. .
| |
| Ohio Edison Co.
| |
| O Pennsylvania Power Co.
| |
| l Toledo Edison Co.
| |
| O
| |
| | |
| Duquesne Light Company Service Area 9 .
| |
| LAWRENCE
| |
| )
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| 4 BUTLER 'f[
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| o - x m z y -
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| [ ARMSTRONG
| |
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| BV#1 vs BV#2 MAJOR DIFFERENCES l
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| |
| ! NUCLEAR CONSTRUCTION I
| |
| ! PLANT START-UP .
| |
| 1 j i
| |
| | |
| O O e BEAVER VALLEY POWER STATION - UNIT 2 CONSTRUCTION PROGRESS AS OF SEPTEMBER 30,1985 100 -
| |
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| ACTUAL 10 - 0 0 0 0 PLANNED 1976 l 1977 l 1978 l 1979 l 1980 l 1981 l 1982 l 1983 l 1984 l 1985 l 1986 l 1987 l TIME
| |
| | |
| O O #
| |
| i BEAVER VALLEY - UNIT 2 BUILDING / AREA BUILDING BUILDING COMPLETE REACTOR 87.2%
| |
| TURBINE 91.9 %
| |
| CONDENSATE POLISHING 90.2 %
| |
| YARD 87.5 %
| |
| COOLING TOWER '
| |
| PUMPHOUSE 94.2 % l AUXILIARY 91.8 %
| |
| MAIN STEAM &
| |
| CABLE VAULT 88.6 %
| |
| ESF 85.8 %
| |
| FUEL & DECONTAMINATION 87.6 %
| |
| WASTE HANDLING 83.3 %
| |
| CONTROL 83.0 %
| |
| DIESEL GENERATOR 89.7 %
| |
| SERVICE 91.3 %
| |
| NOTE: DATA IS THRU SEPTEMBER 30,1985
| |
| | |
| O O O l
| |
| i l MECHANICAL COMMODITIES INSTALLATION STATUS AS OF SEPTEMBER 30,1985 ,
| |
| ESTIMATE AT ACTUAL COMMODITY UNIT COMPLETION TO DATE i
| |
| (QUANTITY) (QUANTITY)
| |
| : SMALL BORE PIPE LF 189,000 170,134 90%
| |
| ; SMALL BORE HANGERS EA 24,000 19,469 81%
| |
| I LARGE BORE PIPE LF 191,150 190,880 99%
| |
| i LARGE BORE HANGERS EA 12,300 11,674 95%
| |
| INSTRUMENTS EA 3150 2023 64%
| |
| SEISMIC INSTRUMENT SUPPORTS EA 10,100 6,359 63%
| |
| STAINLESS STEEL TUBING LF 75,000 63,817 85%
| |
| COPPER TUBING LF 43,000 34,564 80%
| |
| | |
| -o o O l
| |
| ELECTRICAL COMMODITIES j INSTALLATION STATUS AS OF SEPTEMBER 30,1985 i
| |
| ESTIMATE AT ACTUAL l COMMODITY UNIT PERCENT
| |
| ' COMPLETION TO DATE (QUANTITY) COMPLETE i (QUANTITY) 1 CONDUlT LF 738,600 640,783 87%
| |
| CONTROL & INSTRUMENTION CABLE LF 5,040,800 4.120,995 82%
| |
| POWER SERVICE CABLE LF 813,300 615.237 76%
| |
| CABLE TRAY LF 65,830 80,353 92%
| |
| i i
| |
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| |
| - Def EEL OtminaTOR .. ______s BEAVER VALLEY POWER STATION - UNIT 2 PROJECT MILESTONES SCHEDULE
| |
| | |
| p - .
| |
| - - - - - . - - - - -x . - _ _ - . _ - - - - - . . . . . , .. .
| |
| o e 0 GENERAL MANAGER NUCLEAR OPERATIONS T.D. JONES
| |
| _ .1- I DIRECTOR PLANT MANAGER PLANNING AND TECH SERVI ES SCHEDULING W.S. LACEY R.J. DRUGA ll J.C. SOMMERS
| |
| * OPERATIONS
| |
| * CHEMISTRY
| |
| * PLANNING
| |
| * MAINTENANCE
| |
| * PROCEREMENT/
| |
| * OUTAGE
| |
| * TESTING STORES MANAGEMENT
| |
| * ADVISORY ENGR.
| |
| l i
| |
| | |
| O o e TECHNICAL SERVICES l
| |
| ; MANAGER j
| |
| TECHNICAL SERVICES l R.J. DRUGA I I
| |
| ! PLANT SAFETY CHEMISTRY MANA ENT-l REVIEW i
| |
| 4 TECHNICAL OPERATING &
| |
| : ADVISORY MAINTENANCE ENGINEERING PROCEDURES j
| |
| i
| |
| | |
| O O e l
| |
| i l GENERAL MANAGER NUCLEAR OPERATIONS l
| |
| i T.D. JONES
| |
| ! I I MANAGER DIRECTOR PLANT MANAGER TECH SERVICES ^
| |
| SCHEDULING W.S. LACEY R.J. DRUGA J.C. SOMMERS s OPERATIONS
| |
| * CHEMISTRY
| |
| * PLANNING
| |
| * MAINTENANCE
| |
| * PROCEREMENT/
| |
| * OUTAGE
| |
| * TESTING STORES MANAGEMENT
| |
| * ADVISORY ENGR.
| |
| i
| |
| | |
| O e e >
| |
| DIRECTOR '
| |
| PLANNING AND OUTAGE MGT.
| |
| J.C. SUMMERS PLANNING MAINTENANCE AND INFORMATION OUTAGE SCHEDULING MANAGEMENT MANAGEMENT SUPERVISOR SUPERVISOR SUPERVISOR l'_
| |
| | |
| ; o o e l
| |
| l l
| |
| I NUCLEAR OPERATIONS j 470 EMPLOYEES (531 AUTHORIZED)
| |
| * 40 SRO LICENSES f
| |
| 37 RO LICENSES
| |
| * 183 COLLEGE DEGREES l
| |
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| |
| ORGANIZATION & MANAGEMENT
| |
| | |
| e i
| |
| !, O O .
| |
| i ll t
| |
| Duquesne Lisht l
| |
| d rp a
| |
| ! J.J. CAREY l
| |
| ! VICE PRESIDENT
| |
| ; NUCLEAR GROUP l
| |
| 1 l
| |
| i MANAGEMENT PHILOSOPHY i
| |
| l
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| O e e j DUQUESNE LIGHT COMPANY :
| |
| * 28 YEARS NUCLEAR OPERATING EXPERIENCE
| |
| * STAFF ON SITE .
| |
| * AMPLE HUMAN RESOURCES
| |
| ~
| |
| * MINIMAL DEPENDENCE ON
| |
| ! CONSULTANTS
| |
| \'
| |
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| |
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| |
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| |
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| |
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| |
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| |
| a A V R r E e P v O a
| |
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| |
| l
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| | |
| e
| |
| ; O O i
| |
| BOARD NUCLEAR OF "
| |
| REVIEW l DIRECTORS COMMITTEE I
| |
| l i
| |
| CHAIRMAN OF BOARD
| |
| ! CEO VICE PRESIDENT i NUCLEAR GROUP l
| |
| i I 1 7 I
| |
| l SENIOl QUALITY NUCLEAR i l MANAGER l ASSURANCE CONSTRUCTION UNIT DIVISION
| |
| ( _ _ _BV-1T___j OPERATING ORGANIZATION l -
| |
| l I
| |
| | |
| li l l1 Ill1) e N
| |
| G O I
| |
| RNI T AR C T I
| |
| EED LEN RN UI CNA UI TU S
| |
| NGN N E O C
| |
| R RS O RE OG1 -
| |
| AE T ECI I
| |
| N AV LIVN E NB C RU SA UE M NS S
| |
| RN AO T EITI I
| |
| L AN C RU UE NP O
| |
| O p
| |
| | |
| O o O NUCLEAR OPERATIONS
| |
| * PLANT OPERATIONS
| |
| * PLANT MAINTENANCE
| |
| * PLANT TESTING
| |
| * PLANT CHEMISTRY
| |
| * OUTAGE PLANNING
| |
| * PROCUREMENT AND STORES e
| |
| I
| |
| | |
| o o
| |
| * 1 NUCLEAR OPERATIONS l 470 EMPLOYEES
| |
| ! =
| |
| t 67 NRC OPERATING LICENSES 183 COLLEGE DEGREES i
| |
| i l t I
| |
| l i 1
| |
| | |
| l i
| |
| i NUCLEAR ENGINEERING AND CONSTRUCTION UNIT i
| |
| * 81 EMPLOYEES l (140 AUTHORIZED) l
| |
| * 66 COLLEGE DEGREES l
| |
| l 1
| |
| | |
| O o e i
| |
| GENERAL MANAGER NUCLEAR l
| |
| J.D. SIEBER I NUCLEAR RADIOLOGICAL ADMINISTRATIVE SERVICES SAFETY CONTROL DEPARTMENT DEPARTMENT DEPARTMENT W.J. ROY K.D. GRADA J.A. KOSMAL BUDGET AND NUCLEAR FUEL CONTRACTS TRAINING DEPARTMENT DEPARTMENT A.I. DOUGHERTY A.J. MORABITO l
| |
| :i i
| |
| | |
| o o e RADIOLOGICAL CONTROL .
| |
| o RADIOLOGICAL OPERATIONS o DOSIMETRY AND BIOAsNAY o EFFLUENT CONTROL' o ENVIRONMENTAL MONITORING o RADIOLOGICAL ENGINEERING INDUSTRIAL SAFETY'
| |
| ~
| |
| o
| |
| | |
| I: o o e i
| |
| i NUCLEAR SAFETY 1
| |
| o LICENSING l o ISEG 1
| |
| i o ORC COORDINATION o FIRE PROTECTION i
| |
| t
| |
| | |
| O O O l
| |
| NUCLEAR TRAINING l
| |
| l o OPERATIONS TRAINING
| |
| ! o TECHNICAL AND CRAFT TRAINING
| |
| ! o PROGRAM DEVELOPMENT o EMERGENCY PLANNING o SIMULATOR TRAINING
| |
| | |
| O o o NUCLEAR SERVICES UNIT
| |
| * 483 INDIVIDUALS
| |
| !
| |
| * 138 COLLEGE DEGREES 6 NRC OPERATING LICENSES O O O
| |
| | |
| O e ,
| |
| l MANAGER QUALITY i
| |
| ASSURANCE l
| |
| UNIT C.E. EWING
| |
| ' OA OPERATIONS QA ENGINEERING INSERVICE QUALITY OPERATIONS AND INSPECTION CONTROL PROCUREMENT D.C. HUNKELE W.H. SIKORSKl S.C. FENNER C.R. DAVIS e
| |
| 9
| |
| - - ==
| |
| | |
| QUALITY ASSURANCE UNIT l
| |
| * 61 l
| |
| EMPLOYEES (100 AUTH)
| |
| !
| |
| * 250 CONTRACT PERSONNEL
| |
| * 58 COLLEGE DEGREES
| |
| !
| |
| * 2 SRO LICENSES l
| |
| I l
| |
| 1
| |
| | |
| o o e T.D. JONES GENERAL MANAGER I
| |
| i NUCLEAR OPERATIONS
| |
| ! OPERATIONS STAFFING I
| |
| ___ l
| |
| | |
| O O e GENERAL MANAGER NUCLEAR OPERATIONS i
| |
| T.D. JONES I I DIRECTOR PLANT MANAGER I G AND TECH SERVI ES SCHEDULING l
| |
| W.S. LACEY R.J. DRUGA J.C. SOMMERS
| |
| ;
| |
| * OPERATIONS
| |
| * CHEMISTRY
| |
| * PLANNING i
| |
| e MAINTENANCE
| |
| * PROCEREMENT/
| |
| * OUTAGE
| |
| * TESTING STORES MANAGEMENT
| |
| * ADVISORY ENGR.
| |
| | |
| O e e i
| |
| PLANT MANAGER W.S. LACEY INSTRUMENT TESTING AND MAINTEN- AND OPERATIONS ANCE PLANT PER-CONTROL FORMANCE K.D. GRADA R.L. HANSEN H.R. CALDWELL T.G. ZYRA l
| |
| 1
| |
| | |
| O e e l PLANT OPERATIONS SITE OPERATIONS DIRECTOR K.D. GRADA j
| |
| I
| |
| }
| |
| i UNIT 1 UNIT 2 j OPERATIONS SHIFT OPERATIONS SUPPORT COORD. OPERATIONS SUPPORT COORD.
| |
| LR. FREELAND F.D. SCHUSTER 1
| |
| OPERATIONS OPERATIONS SUPPORT STAFF SUPPORT STAFF i
| |
| 1 1
| |
| rw-
| |
| | |
| , o e e 1
| |
| I SHIFT COMPLIMENT
| |
| ~
| |
| NUCLEAR SHIFT SUPERVISOR d STA UNIT 1 , , UNIT 2 NUCLEAR SHIFT SHIFT NUCLEAR SHIFT OPERATING OPERATING OPERATING FOREMAN FOREMAN FOREMAN NUCLEAR CONTROL NUCLEAR CONTROL OPERATOR OPERATOR
| |
| [ (RO) (2) (RO) (2)
| |
| NUCLEAR NUCLEAR OPERATOR OPERATOR (4) (3)
| |
| | |
| O O e PLANT MANAGER W.S. LACEY i
| |
| I INSTRUMENT TESTING AND MAINTEN- AND PLANT PER-OPERATIONS ANCE CONTROL FORMANCE K.D. GRADA R.L HANSEN H.R. CALDWELL T.G. ZYRA 1
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| l I
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| i i
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| PLANT MAINTENANCE SITE MAINTENANCE DIRECTOR l R.L. HANSEN l
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| ! I I SENIOR SENIOR MAINTENANCE MECHANICAL ELECTRICAL SUPPORT MAINTENANCE MAINTENANCE COORDINATOR SUPERVISOR SUPERVISOR
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| !
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| * 6 ENGINEERS
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| * 5 ENGINEERS
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| * 3 ENGINEERS l
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| * 10 FOREMEN
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| * 5 FOREMEN
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| * 72 MECHANICS
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| * 30 ELEC-TRICIANS ,
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| ! + 43 LABORERS r _ - - -
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| o o o i
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| ! INSTRUMENT & CONTROL 1
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| SITE l
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| i 1&C DIRECTOR H.R.CALDWELL 1
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| i I I&C l&C I&C COMPUTER SUPPORT ;
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| CALIBRATION SUPERVISOR I
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| SUPERVISOR MAINTENANCE SUPERVISOR i
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| 1
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| * 2 ENGINEERS
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| * 2 ENGINEERS
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| * 4 ENGINEERS
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| * 2 ENGINEERS
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| * 4 FOREMEN
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| * 5 FOREMEN
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| * 4 SPECIALISTS
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| + 48 l&C TECHNICIANS 4
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| 1 1
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| O O 8 l
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| l l
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| l PLANT l MANAGER l
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| 1 W.S. LACEY l
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| }
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| i INSTRUMENT TESTING AND l MAINTEN- AND PLANT PER-OPERATIONS ANCE 1
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| I CONTROL FORMANCE K.D. GRADA R.L. HANSEN H.R. CALDWELL T.G. ZYRA i
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| a l
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| )
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| 1 I
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| o *
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| * i TESTING AND PLANT PERFORMANCE SITE TESTING 1 AND PLANT PERFORMANCE DIRECTOR t
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| j T.G. ZYRA l l TEST TEST TEST i
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| SUPERVISOR SUPERVISOR SUPERVISOR (SURVEILLANCE) (PERFORMANCE)
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| OE ONS) 2
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| !
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| * 10 ENGINEERS
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| * 11 ENGINEERS
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| * 8 ENGINEERS
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| {
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| l l
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| i 4
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| ! O e e I
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| FRED SCHUSTER TECHNICAL ADVISORY ENGINEER l
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| ! EMERGENCY OPERATING PROCEDURES I
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| t
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| PGP TOPICS
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| * INITIAL EOP DEVELOPMENT
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| !
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| * ADMIN. CONTROLS FOLLOWING INITIAL IMPLEMENTATION
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| * TRAINING PROGRAM
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| '
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| * COMPARISON BETWEEN BV-2 AND ERG REFERENCE PLANT
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| i O o e i
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| i ,
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| I j
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| COORDINATION BV-1/BV-2 EOP's 1
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| PGP BVPS-1 I I - PGP BVPS-2 - ,
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| i I INPUT I DEVELOPMENT j' DEVELOPMENT I I >
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| INPUT I BVPS-1 EOP DRAFT I BVPS-2 EOP DRAFT DEVELOPMENT DEVELOPMENT REVIEW I y 4 l
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| ; t
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| \
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| BVPS-1 TABLE TOP BVPS-2 EOP j WRITER INPUT VERIFICATION BVPS-2 EOP 4 l EXTERNAL REVIEW lI 4
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| 1 l
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| 1
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| l Il 1 e l R
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| E NP O N P. EO I
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| 2 T U E ER S PA ER R 2MO
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| - POC 2MO
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| - 2K H k SMC VEIF SMC SCT PO-PON V
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| B I R PON V I VM K B C I
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| B C E B L A
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| - V W
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| I T RN 1NP 1 OO TIT S- ER SA PL A Y P MO VMC VUID
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| _ BON I BML IA C SV II
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| _ R
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| _ D R
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| l BVPS-1 I INPUT I ' BVPS-2 EOP
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| : COMMENT INCORP. I I COMMENT INCORP.
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| 1 l 1f 1I l ! BVPS-2 i BN1 TABLE TOP EOP TRAINING VALIDATION
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| : u u i
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| l' BVPS-1 BVPS-2 EOP ISSUE EOP TRAINING I V a
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| : BVPS-2 i EOPISSUE i
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| I l
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| ),
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| 1
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| o e O l
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| 1 VERIFICATION
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| * TECHNICALLY CORRECT
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| * WRITTEN TO REFLECT PGP
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| | |
| O O O VALIDATION .
| |
| * USABLE
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| * OPERATIONALLY CORRECT
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| * CAPABLE OF DIRECTING THE OPERATING CREW
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| O O e VALIDATION METHODS
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| * TABLE TOP
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| * WALK-THROUGH ON BV-2 CONTROL BOARD MOCKUP
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| * BV-1 SIMULATOR
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| ! O O #
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| l G. L. BEATTY LEAD LICENSING ENGINEER SERITEMS
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| | |
| Table 1.2 Open issues Issue SER section (1) Preservice/ inservice testing 3.9.6 (2) Pump and valve leak testing 3.9.6 (3) Inadequate core cooling instrumentation (Item II.F.2 of NUREG-0737) 4.4.7 (4) Preservice/ inservice inspcction program 5.2.4.3, 5.4.2.2, 6.6 (5) Safe and alternate shutdown 9.5.1 (6) Management and organization 13.1 (7) Cross-training program 13.2.1.2 (8) Emergency preparedness plan 13.3.3 (9) Initial test program 14 (10) Control room design review 18.1 (11) Safety parameter display system 8 18.2
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| ,ry C/
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| 8eaver Valley 2 SER
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| | |
| l Table 1.3 Backfit issues Issue SER section Status *
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| (1) Snow and ice load 2.3.1 C (2) Underestimation of atmospheric dispersion C conditions (X/Q) at exclusion area boundary and consequences of radioactive release 2.3.4, 15.4.8 (3) Potential for flooding from probable maximum precipitation and Peggs Run 2.4.2, 2.4.10 C (4) Steam generator level control and protection 7.3.3.12 A (5) Motor-operated accumulator isolation valve 8.3.1.12 C (6) Spent fuel pool maximum heat load 9.1. 3 C (7) Fire suppression in the cable spreading room 9.5.1.6 A (8) Class 1E power for lighting and communication systems 9.5.2.1 C (9) Appitcation of GDC 5 to communication systems 9.5.2.1 C q (10) Application of GDC 2 and GDC 4 to communica-l / tion systems 9.5.2 C (11) Application of GDC 4 to lighting systems 9.5.3 C (12) Illumination levels in excess of SRP criteria 9.5.3 C (13) Application of RG 1.26 to areas excluded by RG 1.26 9.5.4-9.5.8 C-(14) Air dryers for emergency diesel generator 9.5.6 C (15) Alann for rocker arm lube oil reservoir 9.5.7 C (16) Diesel lube oil fill procedure 9.5.7 C
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| *A - Issues were discussed in appeal meetings and resolutions are addressed in the SER.
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| C - Closed in SER.
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| O Beaver Valley 2 SER
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| | |
| Table 1.4 Confirmatory issues Issue SER section (1) Operating procedures for continuous communication links 2.2.2 (2) Differential settlements of buried pipes 2.5.4.5 (3) Internally generated missiles (outside containment) 3.5.1.1 (4) Internally generated missiles (inside containment) 3.5.1.2 (5) Turbine missiles 3.5.1.3 (6) Analysis of pipe-break protection outside containment 3.6.1
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| ,(7) FSAR drawings of break locations 3.6.2 (8) Results of jet impingement effects 3.6.2 '
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| (9) Soil-structure interaction analysis 3.7.3 (10) Design documentation of ASME Code components 3.9.3.1 (11) Item II.D.1 of NUREG-0737 3.9.3.2 (12) Seismic and dynamic qualification of mechanical and
| |
| * O electrical equipment 3.10.1 (13) Pump and valve operability assurance 3.10.2 (14) Environmental qualification of mechanical and electrical equipment 3.11 (15) Peak pellet design basis 4.2.1 (16) Discrepancies in the FSAR 4.2.2 (17) Rod bowing analysis 4.2.3.1(6)
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| (18) Fuel rod internal pressure 4.2.3.1(8)
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| (19) Predicted cladding collapse time 4.2.3.2(2)
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| (20) Use of the square-root-of-the-sum-of-the-squares method for seismic and loss-of-coolant-accident load calculation 4.2.3.3(4)
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| (21) Analysis of combined loss-of-coolant-accident and 4.2.3.3(4) seismic loads (22) Natural circulation test 5.4.7.5 Beaver Valley 2 SER
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| Table 1.4 (Continued) ,
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| l9
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| ) Issue SER section (23) Reactor coolant system high point vents 5.4.12 (24) Blowdown mass and energy release analysis methedology 6.2.1.3 I
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| (25) Containment sump 50% blockage assumption 6.2.2 (26) Design modification of automatic reactor trip using shunt coil trip attachment 7.2.2.3 (27) Automatic opening of service water system valves MOV 113C and 1130 . 7.3.3.10 (28) IE Bulletin 80-06 concerns ,
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| 7.'3.3.13 (29) NUREG-0737 Item II.F.1, accident monitoring instrumentation positions ,
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| 7.5.2.2 (30) Bypass and inoperative stc'tus panel 7.5.2.4 (31) Revision of the FSAR--cold leg accumulator motor- ~
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| operated valve position indication " 7.6.2.4 j] (32) Control system failure caused by malf nctions'of _
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| U common power source or instrument line 7.7.2..'
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| l (33) Confirmatory site visit l (a) Independence of offsite power circuits between l the switchyard and Class 1E system , 8.2.2.3
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| [ (b) Confirmation of the protective bypas's 8.3.1.2 l (c) Verification of DG start and load tests 8.3.1.8 l
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| (d) DG load capability qualification test 8.3.1.9 (e) Margin qualification test 8.3.1.10 (f) Electrical interconnection between redundant Class 1E buses 8.3.1.13 (g) Verification of electrical independence between power supplies to controls in control room and remote locations 8.'J.3.5 (34) Voltage analysis- verification of test results 8.3.1.1 (35) Documentation of description and analysis of compliance with GDC 50 8.3.3.7.1 (36) Completion of plant-specific core damage estimate procedure before-fuel load 9.3.2.2 A (37) Training progra::t for the operation and maintenance of the h diesel generators 9.5.4.1 Beaver Valley 2 SER
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| | |
| 1 Table 1.4 (Continued)
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| O\
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| (s / Issue SER section (38) Vibration of instruments and controls on diesel generators 9.5.4.1 (39) Surveillance of lube oil level in the diesel generator 9.5.6 rocker arm lube oil reservoir (40) Solid waste process control program 11.4.2 (41) TMI Action Plan items (a) III.D.1.1 13.5.2 (b) II.K.1.5 and II.K.1.10 15.9.2, 15.9.3 (c) II.K.3.5 15.9.9 (d) II.K.3.17 15.9.11 (e) II.K.3.31 15.9.14 (42) Plant-specific dropped rod analysis 15.4.3 (43) Steam generator tube rupture 15.6.3 (44) Quality assurance program 17.4 O
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| Table 1.5 License condition item License condition SER section (1) Emergency response capability, RG 1.97, Rev. 2 requirements 7. 5. 2.1 i
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| l O
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| Beaver Valley 2 SER'
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| i l
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| i 1
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| C. E. EWING i MANAGER: QUALITY ASSURANCE i
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| ; QA/QC I
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| J
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| ^
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| ~
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| i O O e-i i
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| DUQUESNE LIGHT COMPANY '
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| ; QUALITY ASSURANCE PROGRAM
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| ; COMMITMENTS 1
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| : 1. DESIGN & CONSTRUCTION QUALITY l ASSURANCE PROGRAM 10 CFR 50, APPENDIX B REGULATORY GUIDE 1.28
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| : 2. OPERATIONS QUALITY ASSURANCE PROGRAM 10 CFR 50, APPENDIX B REGULATORY GUIDE 1.33 .
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| ANSI N45.2 SERIES
| |
| _ - - _ _ . _ - - . - _ - - _ _a
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| l O O e' i
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| DUQUESNE LIGHT COMPANY NUCLEAR GROUP QUALITY ASSURANCE UNIT l
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| QUALITY
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| ; ASSURANCE l . UNIT MANAGER OPERATIONS ENGINEERING & SITE OPERATIONS PROCUREMENT PRE-SERVICE &
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| QUALITY IN-SERVICE QUALITY QUALITY ASSURANCE QUAllW INSPECTION CONTROL CONTROL DIRECTOR ASSURANCE DIRECTOR DIRECTOR DIRECTOR DIRECTOR VENDOR SITE SURVEILLANCE NTROL
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| ! O O e-i 1
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| l I
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| 1
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| (
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| NUCLEAR GROUP VICE PRESIDENT
| |
| \
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| QUALITY ASSURANCE i MANAGER QA OUALITY ENGINEERING CONTROL ,
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| i PROCUREMENT J
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| INSERVICE QA INSPECTION OPERATIONS 4
| |
| i
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| :l
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| | |
| e DUQUESNE LIGHT COMPANY NUCLEAR GROUP QUALITY ASSURANCE UNIT EXPERIENCE OF PERSONNEL NUCLEARINDUSTRY DUQU SNE LIGHT COMPANY EXPERIENCE 570 MAN YEARS REACTOR OPERATOR EXPERIENCE 30 MAN YEARS REGISTERED PROFESSIONAL -
| |
| ENGINEER 31 MAN YEARS
| |
| | |
| ! O O #~
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| l DUQUESNE LIGHT COMPANY NUCLEAR GROUP l QUALITY ASSURANCE UNIT EDUCATIONAL ACCOMPLISHMENTS MASTER DEGREES 2 BACHELOR DEGREES 40 l ASSOCIATE DEGREES 16
| |
| ! WORKING TOWARDS
| |
| ! DEGREE 8 l
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| i
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| __________________________._____1_____________________.__ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
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| : O O #-
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| i i
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| BEAVER VALLEY 1 SALP REPORT 12/1/82 12/1/81 THRU THRU FU,NCTIONAL AREAS 3/31/84 11/30/82 2 2 PLANT OPERATIONS 1 1 RADIOLOGICAL CONTROLS
| |
| ; - RADIATION PROTECTION
| |
| - RADIOACTIVE WASTE MANAGEMENT l
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| - TRANSPORTATION i - EFFLUENT CONTROL 1 2 MAINTENANCE 2 2 i SURVEILLANCE (INCLUDING INSERVICE l
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| AND PREOPERATION TESTING) 2 2 FIRE PROTECTION 1 2 EMERGENCY PREPARATION 1 1 SECURITY AND SAFEGUARDS 2 2 REFUELING / OUTAGE ACTIVITIES 1 1 LICENSING ACTIVITIES
| |
| | |
| k O O #'
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| i
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| . BEAVER VALLEY 2 SALP REPORT 4/1/84 12/1/82 12/1/81 FUNCTIONAL AREAS THRU 3/31/85 THRU 3/31/84 THRU 11/30/82 SOILS AND FOUNDATIONS - -
| |
| 1 CONTAINMENT AND OTHER SAFETY-RELATED STRUCTURES 1 2 1 PIPING SYSTEMS & SUPPORTS 2 3 2 SAFETY-RELATED COMPONENTS 1 1 1 SUPPORT SYSTEMS 1 1 2 ELECTRICAL POWER' SUPPLY AND DISTRIBUTION 2 3 1
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| | |
| b
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| .O O O' BEAVER VALLEY 2 SALP REPORT (con't) 4/1/84 12/1/82 12/1/81 FUNCTIONAL AREAS THRU 3/31/85 THRU 3/31/84 THRU 11/30/82 INSTRUMENTATION-AND
| |
| . CONTROL SYSTEMS 2 2 -
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| i LICENSING ACTIVITIES 2 2 2
| |
| ! STORAGE OF SAFETY-RELATED 4
| |
| COMPONENTS 2 1 3 ENGRG./ CONSTRUCTION INTERFACE 2 3 2 PREOPERATIONAL/STARTUP i TESTING 2 - -
| |
| QUALITY ASSURANCE AND ADMINISTRATIVE CONTROLS - -
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| I I
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| l o e 0-I EFFECTIVE TRAINING PROGRAM ESSENTIAL FOR ACHIEVING EXCELLENCE OF NUCLEAR OPERATIONS I
| |
| ~
| |
| I .
| |
| | |
| O O O-t TRAINING PROGRAMS
| |
| : GENERAL EMPLOYEE TRAINING (INPO STANDARDIZATION PROGRAM)
| |
| * OPERATOR TRAINING LICENSED AND NON-LICENSED
| |
| * SHIFT TECHNICAL ADVISOR RADIATION TECHNICIAN
| |
| * TECHNICAL PERSONNEL
| |
| * MAINTENANCE TRAINING
| |
| = EMERGENCY PREPAREDNESS
| |
| * FIRE BRIGADE
| |
| * ALCOHOL AND DRUG AWARENESS
| |
| | |
| o o 0 -
| |
| )
| |
| INPO ACCREDITATION SCHEDULE i SELF EVALUATION REPORT AND JOB ANALYSIS
| |
| * JULY 1984
| |
| - LICENSED OPERATOR TRAINING i
| |
| - NON-LICENSED OPERATOR TRAINING
| |
| - LICENSED OPERATOR REQUAL
| |
| ',
| |
| * JULY 1985
| |
| - SHIFT TECHNICAL ADVISOR
| |
| - RADIATION PROTECTION TECHNICIAN
| |
| - CHEMIST
| |
| - 1&C TECHNICIAN l
| |
| * MAY 1986 1 - MECHANICAL MAINTENANCE l - ELECTRICAL MAINTENANCE
| |
| ! - TECH. STAFF & MANAGERS l
| |
| | |
| 9 0 e-
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| ~
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| S.A.T. - SYSTEMATIC APPROACH
| |
| ; TO TRAINING
| |
| * ANALYSIS F DESIGN E
| |
| E i
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| D DEVELOPMENT '
| |
| B
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| : A C
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| l K IMPLEMENTATION l .
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| 4 EVALUATION -
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| l l
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| w...has6 m.me,-.-e,m4.-' .- .%h.,e +am -..uwa..vam a .s me2 -b.G.-hw .,##%*A_ _ _ _ .%. ma..h4 0 # # '
| |
| TRAINING DEVELOPMENT NEW TRAINING SUB-SECTION TO SUPPORT THE S.A.T. EFFORT
| |
| | |
| O O O-THERMODYNAMICS
| |
| * EVALUATED BY A.C.E.
| |
| * RECOMMENDED FOR 3 CREDITS l
| |
| l l
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| 1 I
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| w v' ' ~
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| | |
| O o e-LICENSED OPERATOR PHASES OF TRAINING PHASE 4 SIMULATOR TRAINING U
| |
| PHASE 5 ,
| |
| ON-SHIFT TRAINING U
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| i PHASE 6 j LICENSE REVIEW SERIES l
| |
| :l
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| | |
| lI 0
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| - G
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| - N I
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| S
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| - N E
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| O e O-TRAINING
| |
| | |
| ==SUMMARY==
| |
| | |
| l
| |
| * THEORY
| |
| * SECONDARY SYSTEMS
| |
| - SIMULATOR ,
| |
| - ON-SHIFT
| |
| , o PRIMARY SYSTEMS
| |
| - SIMULATOR
| |
| - ON-SHIFT
| |
| * CONTROL SYSTEMS
| |
| - SIMULATOR l
| |
| i
| |
| * ACCIDENT ANALYSIS / MITIGATING CORE DAMAGE
| |
| - Simulator
| |
| - 3 MONTHS ON-SHIFT
| |
| * LICENSE REVIEW
| |
| - SIMULATOR
| |
| * NRC EXAM
| |
| | |
| LICENSED OPERATOR PHASES OF TRAINING PHASE 1 ACADEMIC TRAINING PHASE 2 PLANT SYSTEMS /
| |
| INSTRUCTION & STUDY v
| |
| PHASE 3 QUALIFICATION STANDARDS CHECK-OFFS V
| |
| | |
| n , - w - ., e ... s - .-
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| o o 4
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| e' a
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| L i UNIT ll CROSS TRAINING ,
| |
| ; NUREG 1021 l SYSTEM DIFFERENCE ANALYSIS 1
| |
| I
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| )
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| b _
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| | |
| a-==e-+anhwe-.e- .-5---Ew w wre -_am.=. _ . cL*-4 --**-a -e8--*E- 4 .h-O o e' LICENSE RETRAINING PROGRAM 24 MONTHS 2 ONE YEAR CYCLES PROGRAM 1983 - 1985 l 1 l
| |
| f _ _
| |
| | |
| LICENSED RETRAINING PROGRAM l PHASES OF TRAINING 1
| |
| ;
| |
| * PHASE 1 I
| |
| - ANNUAL WRITTEN EXAMINATIONS l
| |
| * PHASE 2
| |
| - FORMAL CLASSROOM TRAINING
| |
| * PHASE 3 i - PLANT MANIPULATION TRAINING l (SIMULATOR) l
| |
| * PHASE 4
| |
| - INDIVIDUAL STUDY l
| |
| !
| |
| * PHASE 5 I - PERFORMANCE EVALUATION
| |
| | |
| O O O-l j
| |
| TRAINING USES i
| |
| * LICENSED OPERATOR TRAINING ~
| |
| * ENGINEER TRAINING i INITIAUCROSS
| |
| * SHIFT TECHNICAL ADVISOR
| |
| ! INITIAURETRAINING
| |
| )
| |
| * LICENSED CERTIFICATION
| |
| * LICENSED UPGRADE
| |
| * NON-LICENSED OPERATOR l
| |
| l
| |
| * LICENSED RETRAINING
| |
| * INSTRUCTOR CERTIFICATION l
| |
| i l
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| )
| |
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| 1 O o O-l
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| ! GENERAL EMPLOYEE TRAINING i
| |
| STATION ORIENTATION
| |
| ~
| |
| * RADIATION WORKER (INPO
| |
| ! STANDARDIZATION PROGRAM)
| |
| * GENERAL EMPLOYEE REFRESHER 1
| |
| l l
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| | |
| O o O' l RADIATION TECHNICIAN
| |
| ! TRAINING PROGRAM j
| |
| }
| |
| ACADEMIC TRAINING RADIATION PROTECTION FUNDAMENTALS / THEORY v
| |
| lN PLANT APPLICATION I
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| OF j RADIOLOGICAL PROTECTION i
| |
| | |
| O o g.
| |
| l MAINTENANCETRAINING l
| |
| f BASIC TRAINING CATAGORIES '
| |
| * MAINTENANCE ORIENTATION l ''
| |
| * GENERAL MAINTENANCE
| |
| !
| |
| * SPECIFIC MAINTENANCE 1
| |
| % me-.
| |
| | |
| o o O-
| |
| )
| |
| i l
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| ! MAINTENANCE TRAINING l
| |
| * INSTRUMENT AND CONTROL
| |
| * MECHANICAL
| |
| * ELECTRICAL
| |
| : O O #
| |
| i - -
| |
| h
| |
| ; R. W. FED &!
| |
| l SENIOR PROJECT ENGINEER l
| |
| i
| |
| ! DECAY HEAT REMOVAL ;
| |
| COLD SHUTDOWN
| |
| | |
| o o o a .
| |
| 4 BVPS-2 SAFE SHUTDOWN DESIGN t .
| |
| l
| |
| * DESIGN BASIS IS HOT STANDBY
| |
| * UPGRADED PLANT DESIGN TO COLD l SHUTDOWN CAPABILITY FOLLOWING
| |
| , SAFE SHUTDOWN EARTHQUAKE LOSS OF OFFSITE POWER l SINGLE ACTIVE FAILURE l
| |
| * ADEQUATE TO ACHIEVE BOTH HOT STANDBY l AND COLD SHUTDOWN a
| |
| | |
| O O #
| |
| i i cold SHUTDOWN DESIGN
| |
| ! MODIFICATIONS
| |
| * NINETEEN SPECIFIC CHANGES IMPLEMENTED BETWEEN 1978-1984
| |
| * TWO TYPES OF IMPLEMENTATION
| |
| : 1. SAFETY GRADE CAPABILITY TO ACCOMMODATE DESIGN BASIS EVENTS
| |
| : 2. NON-SAFETY GRADE CAPABILITY FOR ANTICIPATED ABNORMAL EVENTS
| |
| | |
| EXAMPLES OF COLD SHUTDOWN DESIGN MODIFICATIONS
| |
| * UPGRADE PRESSURIZER PORV TO SAFETY GRADE
| |
| * INCREASE STEAM GENERATOR PORV CAPACITY AND UPGRADE TO SAFETY GRADE
| |
| * RELOCATE RESIDUAL HEAT REMOVAL COMPONENTS AND INSTRUMENTATION ABOVE CONTAINMENT !
| |
| FLOOD LEVELS
| |
| * PROVIDE REACTOR VESSEL HEAD VENT AND LETDOWN
| |
| * PROVIDE ALTERNATE POWER SUPPLY CAPABILITY TO SEVERAL COMPONENTS AND SYSTEMS
| |
| * PROVIDE ADDITIONAL BACKUP AUXILIARY FEEDWATER SYSTEM WATER SOURCE
| |
| | |
| O O e 4
| |
| f KEY FUNCTIONS TO ACHIEVE
| |
| : SAFE SHUTDOWN
| |
| * HEAT. REMOVAL j
| |
| * REACTIVITY CONTROL
| |
| * INVENTORY CONTROL '
| |
| * PRESSURE CONTROL l
| |
| l
| |
| _ - - - - - - --_17'
| |
| | |
| O O e BEAVER VALLEY UNIT 2 MEETS l GENERAL DESIGN CRITERIA 34 OF
| |
| ! 10CFR 50, APPENDIX A 1
| |
| l
| |
| | |
| 1 O O e 4
| |
| ! RESIDUAL HEAT REMOVAL SYSTEM
| |
| :x!-
| |
| FCV l JB 2 o ,= 2x =
| |
| <=.
| |
| RCS HEAT LOOP A HR EXCHANGERS p p 22 o syy $m "
| |
| t #C FCV J
| |
| | |
| I l
| |
| 1 l EMERGENCY CODE COOLING SYSTEM CONT.
| |
| H DERS R -
| |
| n y =
| |
| l ~
| |
| UOSS PUMPS l RWST M A RCS U
| |
| M '
| |
| n _
| |
| l v -
| |
| HHSI PUMPS -
| |
| 1 r1 r J L J L RCS
| |
| ; LHSI 1 P 1r PUMPS d L dL "N r CONT.
| |
| "N ; SPRAY
| |
| : HEADERS SUMP RSS PUMPS
| |
| | |
| O o e l BEAVER VALLEY UNIT 2 l MEETS
| |
| ! GENERAL DESIGN CRITERIA 34
| |
| ; OF l 10CFR 50, APPENDIX A
| |
| | |
| O O
| |
| * l l
| |
| l ERVIN T. EILMANN i SENIOR PROJECT ENGINEER l
| |
| ! EMERGENCY / ALTERNATE SHUTDOWN PANELS i
| |
| i
| |
| | |
| EMERGENCY SHUTDOWN PANEL (GDC-19)
| |
| * LOSS OF CONTROL ROOM HABITABILITY
| |
| * COLD SHUTDOWN CAPABILITY
| |
| * PURPLE & ORANGE TRAINS
| |
| * ELECTRICALLY INDEPENDENT FROM CR i
| |
| | |
| l O O e l
| |
| 1 i
| |
| CONTROL BUILDING / CABLE TUNNEL FLOOR ARRANGEMENT i
| |
| s CONTROL ROOM 735-6 CABLE SPREADING ROOM 725-6 1
| |
| l I 712-6 CABLE TUNNEL
| |
| { INST. & RELAY ROOM i 707-6
| |
| ~
| |
| l i
| |
| s 1
| |
| I i
| |
| 1
| |
| | |
| ; ALTERNATE SHUTDOWN CAPABILITIES
| |
| ! MAIN AUXILIARY I CONTROL SHUTDOWN BOARD PANEL 4 >
| |
| ^^ ^ ^
| |
| SWITCH GEAR j : .
| |
| ! EMERGENCY I SHUTDOWN l PANEL 4
| |
| [
| |
| I--_-____ _ . - . _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ____
| |
| | |
| ALTERNATE SHUTDOWN PANEL REQUIRED FOR FIRE AREAS:
| |
| o CONTROL ROOM o CABLE SPREADING ROOM o CABLE TUNNEL l o INSTRUMENTATION & RELAY ROOM
| |
| * WEST COMMUNICATION ROOM l .
| |
| 1
| |
| | |
| 1 O O .
| |
| : ALTERNATE SHUTDOWN CAPABILITY AUXILIARY ELDGJCABLE TUNNEL ALTERNATE SHUTDOWN PANEL ROOM %
| |
| PERSONNEL ACCESS TUNNEL /
| |
| ^
| |
| NEL
| |
| \ ,___.
| |
| MAIN CONTROL BOARD ; ORANGE TRAIN l l f _,
| |
| ! I I MAIN CONTROL ROOM r O GE TRAINS I I
| |
| , - __________/ ,
| |
| i ____________/
| |
| J i CABLE I SPREADING CABLE TUNNEL j ROOM i
| |
| i
| |
| ! J 4
| |
| f
| |
| * NSSS PROCESS RACK IN
| |
| {- ' INSTRUMENTATION AND RELAY ROOM EMERGENCY SHUTDOWN PANEL IN WEST
| |
| : COMMUNICATION ROOM
| |
| | |
| l o o e .
| |
| EMERGENCY SQUAD ROOM LOCATION BVPS UNIT 1 TURBINE BUILDING i
| |
| l EMERGENCY SQUAD ROOM l STAIRS TO i
| |
| HALLWAY h '
| |
| ACCESS TUNNEL '
| |
| \
| |
| l BVPS UNIT 1 l BVPS UNIT 2 CONTROL ROOM I COh! TROL ROOM
| |
| ! - I i !
| |
| i I
| |
| I _
| |
| I I
| |
| I I
| |
| I I
| |
| I I
| |
| I I
| |
| I BVPS UNIT 1 SERVICE BUILDING r
| |
| | |
| 8 O e CABLE SPREADING ROOM / CABLE TUNNEL AREA DRAWING V
| |
| . _ PERSONNEL ACCESS TUNNEL EL 722-6 CABLE SPREADING ROOM EL 725-6 .
| |
| \ lil 8 . CABLE TUNNEL E PORT FIRE EXTINGUISHER (CO 2-20 LBS. (PRELIM. LOCATION)
| |
| E HOSE RACK (APPROX. LOCATION) s FIRE ALARM BELL (APPROX. LOCATION)
| |
| E FIRE HORN l -
| |
| | |
| i l
| |
| ALTERNATE SHUTDOWN PANEL l
| |
| * FIRE IN AREAS (CB-1, CB-2, CB-6, CT-1, CR)
| |
| * COLD SHUTDOWN CAPABILITIES l
| |
| * ORANGE TRAIN l
| |
| * ELECTRICALLY INDEPENDENT 3
| |
| i i
| |
| 4
| |
| | |
| o o O l
| |
| K.D. GRADA MANAGER NUCLEAR SAFETY OFFSITE/ONSITE AC/DC POWER SYSTEMS STATION BLACKOUT
| |
| | |
| FOLLOW-UP ACTIONS 8
| |
| EQUIPMENT IN PULL-TO-LOCK LOCAL D/G STARTING ISOLATION OF RCP SEAL COOLING f
| |
| S/G ISOLATION i -
| |
| ISOLATING AUXILIARY STEAM i
| |
| VENTING HYOROGEN l
| |
| i SHEDDING DC LOADS DEPRESSURIZATION OF S/G TO 240 psig 4
| |
| \
| |
| . 6606S i
| |
| | |
| DESIGN FEATURES O -
| |
| STEAM GENERATOR POWER OPERATED 4
| |
| RELIEF VALVES I
| |
| - TURBINE DRIVEN AUXILIARY FEEDWATER PUMP :
| |
| j -
| |
| FLYWHEELS ON THE RCPs 25% DESIGN MARGIN ON STATION BATTERIES FLOATING RING SEALS O -
| |
| SYSTEM CROSS TIES PEAKING UNITS SIX 345 KV anel SEVEN 138 KV LINES CORGSED NUCLEAR-COAL COMPLEX GENERATING CAPACITY OF 4000 MW(e)
| |
| O L6065
| |
| | |
| t
| |
| , PRIMARY ACTIONS REACTOR TRIP l
| |
| TURBINE TRIP REHEAT STEAM and MSIV ISOLATION i
| |
| G WRATOR TW i l l
| |
| 1 RCS ISOLATION l
| |
| i AFW FLOW l <
| |
| i l
| |
| I I
| |
| 1 i
| |
| 66069 l i
| |
| | |
| J.A. HULTZ DEPUTY PROJECT MANAGER l
| |
| ALTERNATE PIPE RUPTURE PROTECTION
| |
| | |
| O e LARGE DETECTABLE FLAWS SHOULD NOT EXIST e FLAWS DO NOT GROW TO THRU-WALL CRACKS O
| |
| 1 0
| |
| j
| |
| | |
| 9 1
| |
| e REMOVAL OF SNUBBERS AND SHIELDS DOES NOT COMPROMISE PLANT SAFETY O
| |
| O
| |
| | |
| g EVENTS TO DATE e WESTINGHOUSE R&D e A-2 OWNERS GROUP O . CRGR A-2 (84-04) e NRC APPROVAL OF AIPB AND GDC-4 EXEMPTION
| |
| * DLC MEETINGS WITH NRR AND ACRS ON WHIPJET O
| |
| | |
| ,/
| |
| l 9
| |
| )
| |
| IF APPROVAL]IS NOT GRANTED FOR WHIPJET PROGRAM BY FEB.1987, DLC WOULD INSTALL PROTECTIVE DEVICES ON A SCHEDULAR BASIS OVER SEVERAL REFUELING OUTAGES.
| |
| l l
| |
| O E
| |
| o r
| |
| | |
| ==SUMMARY==
| |
| | |
| 8
| |
| 't e DECREASED WORKER EXPOSURE i
| |
| e IMPROVED ACCESSIBILITY O e DECREASED CONSTRUCTION AND O&M COSTS 4
| |
| F e DLC AWAITING WHIPJET APPROVAL
| |
| ]
| |
| 4 9
| |
| | |
| O O e 4 LEAK BEFORE BREAK SCOPE ARBITRARY-INTERMEDIATE-127 BALANCE OF PLANT-136 i
| |
| PRIMARY d SYSTEM-9 RUPTURE RESTRAINTS
| |
| . THE NUMBERS REFER TO THE NUMBER OF RESTRAINTS u
| |
| | |
| PLANT HIGRLIGHTS FSAR DESCRIPTION REFERENCE NSSS: 3 loop PWR; 2,660 MWt; 836 MWe net Page 1.1-1 Sect ion 1.1 Engineered Safety Features design based on 2,780 MWt Page 1.1-1 Sect ion 1.1 Containment design based on 2,713 MWt Page 1.1-1 Sect ion 1.1 Subatmospheric containment (9.5 psia) Page 1.1-1 Sect ion 1.1 Site: 509 acres on south bank of Ohio River; minimum Page 1.2-2 exclusion radius = 1,500 f t.; distance to nearest resi- Sect ion 1.2.2 dence = 2,300 ft.; low population zone area distance = 3.6 miles; population center distance = 17 miles Containment: steel-lined reinforced concrete cylinders Page 1.2-2 with hemispherical done and flat base Sect ion 1.2.3 Cooling tower: natural draft hyperbolic with reinforced Page 1.2-2 r~N concrete shell Sect ion 1.2.3
| |
| < a
| |
| \' ,f Steam Generators: Westinghouse, vertical, U-tube enits Page 1.2-3 with inconel tubes. Integral dryers to provide steam with Sect ion 1.2.3 moisture < 1/4%
| |
| Reactor Coolant Pumps: Westinghouse, vertical, single- Page 1.2-3 stage, centrifugal pumps of the shaf t-seal type Sect ion 1.2.4 Reactor control by soluble boron and control rods Page 1.2-4 Sect ion 1.2.5 Charcoal beds and HEPA filters to control the release of Page 1.2-5 rad ioact ivity Sect ion 1.2.6 Storage for 1,059 spent fuel assemblies Page 1.2-6 Sect ion 1.2.7 Turbine: 1,800 rps, 888MW, tandem-compound, four flow. Page 1.2-6 single reheat unit with provisions fo r s ix s t ages of fe ed- Sect ion 1.2.8.1 water heating Generator: direct-driven, three phase, 60Hz, 22kV, 1,800 Page 1.2-7 rps hydrogen inner-cooled, synchronous generator rated at Sect ion 1.2.8.1 1,026 HVA at 0.90 power factor
| |
| ,, Page 1 of 7 (v)
| |
| | |
| FSAR DESCRIPTION REFERENCE O Turbine bypass steam dump to handle up to 90% of full steam flow Page 1.2-8 Sect ion 1.2.8.6 1
| |
| Circulating water system: pumped, closed-loop system Page 1.2-8 i utilizing an air-cooled, natural draf t hyperbolic cooling Sect ion 1.2.8.7 tower )
| |
| ~
| |
| __ ESF system: 1. Containment Page 1.2-9
| |
| : 2. Emergency core cooling Sect ion 1.2.10
| |
| : 3. Quench and recirculation spray
| |
| : 4. Supplement al leak collect ion and release system
| |
| : 5. Pos t-DBA hydrogen control system
| |
| : 6. Containment isolation
| |
| : 7. Habitability system for control room Main Steam System: 797 psia, 11.61 x 106 lbs/hr, 518'F Table 1.3-1 Page 14 of 20 Full flow condensate polishing demineralizer Table 1,3-1 Page 15 of 20 Hafnium control rods Tab le 1.3-2 Page 2 of 19 No thermal s1reves in the reactor coolant loop branch Tabic 1.3-2 nozzles to simplify the nozzle design Page 2 of 19 E')
| |
| '/
| |
| (_- Steam generator integral flow restriction Tab le 1.3-2 Page 3 of 19 Two-train dedicated residual heat removat system Table 1.3-2 Page 3 of 19 Safety grade approach to cold shutdown Table 1.3-2 Page 3 of 19 Reactor vessel head vent Table 1.3-2 Page 4 of 19 Auxiliary feedwater cavitating venturies Tab le 1.3-2 Page 4 of 19 Improved quench spray nozzle design Table 1.3-2 Page 4 of 19 No Boron Injection Tank Tab le 1,3-2 Page 4 of 19 Automatic transfer to recirculation on Safety Injection Table 1.3-2 Signal Page 4 of 19
| |
| ~s Page 2 of 7 I )
| |
| \..J
| |
| | |
| FSAR DESCRIPTION REFERENCE 9 Positive displacement NaOH pumps for quench spray system Tab le 1.3-2 Page 5 of 19 Alternata shutdown panel in auxiliary builJng (Appendix Table 1.3-2 R) Page 6 of 19 Safety parameter display system Table 1.3-2 Page 6 of 19 Reactor coolant system cold overpressure protection Tab le 1.3-2 Page 6 of 19 Upgraded fuel transfer system Tab le 1.3-2 Page 7 of 19 Refrigerant-type air dryer with desiccant filter bypass Table 1.3-2 on containment instrument air Page 10 of 19 ,
| |
| On-line pH and Na conductivity monitors for each steam Table 1.3-2 gene ra to r - Page 10 of 19 Filtration and exhaust system for gaseous waste storage and Table 1,3-2 cask washdown area Page 12 of 19 Gland seal steam exhaust ventilation system to filter and Table 1,3-2 monitor non-condensable gases prior to discharge Page 12 of 19
| |
| /'' Fuel oil storage for seven days of full load operation Table 1.3-2 C)' Page 12 of 19 Motor-driven start-up feedwater pump Table 1.3-2 Page 15 of 19 Two (2) motor-driven and one (1) turbine-driven auxiliary v s51 1.3-2 feedvater pumps Page 15 of 19 N-1 loop accident analysis Table 1.3-2 Page 19 ofl9 Duquesne 1.ight Company will build a plant simulator Table 1.10-1 (BVPS-1 specific) Page 1 of 6 Emergency air lock in Containment Building is a subassen- Page 3.8-9 bly of equipment hatch Sect ion 3 .8 .1.1.3 . 2 Fuel assemblies: 17x17 rod array; 264 rods / assembly; 24 Page 4.2-9 guide tubes; one thimble port; Zircaloy-4 clad; bottom Sect ion 4.2.2 nozzle-top nozzle Type 304 stainless steel; inconel grid straps
| |
| - Page 3 of 7
| |
| | |
| , FSAR DESCRIPTION REFERENCE BVPS-2 fuel enrichment:
| |
| 9 3.1%, 2.6%, 2.1%
| |
| Hafnium control rods (48); 149 lbs. each Tab le 4.1-1 Page 4 of 4 Tab le 4.3-1 Page 2 of 2 Dedicated residual heat removal system inside containment Page 5.4-30 Sect ion 5.4.7 Pressuriser PORV's safety grade and used to achieve cold Page 5.4-54 shutdown Sect ion 5.4.13.2 BVPS-2 approach to cold shutdown Appendix 5 A Containment subatmospheric (9-12 psia); design 45 psig; Page 6.2-2 LOCA 44.6 psig Sect ion 6.2.1.1.2 Refueling Water Storage Tank volume increase (BVPS Page 6.2-4 850,000 gal, BVPS 441,100 gal) Sect io n 6 . 2 .1.1. 3 .1 Each quench spray pump can deliver 3000 spa Page 6.2-46 Sectiun 6.2.2.2.1 Recirculation spray pumps (4): 3500 spa, outside Table 6.2-37 f.)
| |
| \_ / Low head safety injection pumps (2): dedicated 3000 spa Page 6.3 $
| |
| each; used only for initial LOCA (page 6.3-6 first and Sect ion last paragraphs) 6.3.2.2 Supplementary leak collection system: two 30,000 cfm Page 6.5-7 normal fans; two 43,000 cfm emergency bus fana; four Sect ion 29,500 cfm filters; two 13,000 cfm charging pump fans 6.5.3.2 Commitment to Reg. Guide 1.97, Revision 2 Page 7.5-1 Sect ion 7.5 Automatic changeover from injection phase to recircula- Page 7.6-6 t ion phase Sect ion 7.6.5 Interconnection of BVPS-2 to Mans. field, Hanna, and Sammis Page 8.1-1 on 345kV (enhances reliability and svallability) Sect ion 8.1.3 Main transformer 21.5kV - 36'skV; rated at 945 MVA; each Page 8.1-2 138kV bus supplies a 138k57 - 4.36kV - 4.36kV trans former Sect ion 8.1.4 Heat tracing alarma displayed on alarm CRT in control Page 8.3-7 room (See Chapter 7 for more detail) Sect ion 8.3.1.1.3 Page 4 of 7 0
| |
| | |
| FSAR DESCRIPTION REFERENCE Swing IE loads (i.e. , 3 pumps available): charging /HHSI Page 8.3-7 Pump, se rvice water pump, primary component cooling water Sect ion pump 8.3.1.1.4 Interlocked swing loads on 480V emergency bus (2N or 2P) Page 8.3-8 cont ainment air recirculation fan (drops out on CIB);
| |
| 480V "C" Sect ion service water pump fan (trips if not running on 8.3.1.1.4 SIS); residual heat removal suction valves (2RHS-MOV702A and 2RHWS701B) (drops out on SIS)
| |
| Each piece of safety related equipment contains an Page 8.3-12 asterisk as part of its mark number Sect ion 8.3.1.1.9 Onsite Emergency Power: two 4160 V, three phase, 60 Hz Page 8.3-32 diesel-generators, manufactured by Colt Industries; meet Sect ion intent of Branch Technical Positions ICSB 7 and 8; diesel 8.3.L.l.15 generator unit ratings are as fo llows :
| |
| Continuous duty: (8760 hrs.) 4238 kW 2000 hrs. 4535 kW 160 hrs. 4662 kW 30 min. 5086 kW Standby service water system (alternate intake structure): Page 9.2-11 provides heat sink if intake structure is disabled Sect io n 9.2.1.2 k_j} Total demineralized water shared between BVPS-1 and Page 9.2-28 BVPS-2 is 1.2 million gallons (BVPS-2 has 600,000 gal. Sect ion storage tank [ primary plant]; 140,000 gal, secondary 9.2.3.1 plant)
| |
| Separate condensate polishing air system for condensate Page 9.3-5 polishing building only Sect io n 9.3.1.2 Safe shutdown: Chemical and volume control system Page 9.3-39 capable of safety grade cold shutdown (refueling water Sect ion storage tank is source of borated water) 9.3.4.1.7 Boric Acid Tanks (2) sised for cold shutdown (12,500 gal Page 9.3-50 e ach)
| |
| Sect ion 9.3.4.2.4 Control Room KVAC: Control room pressurization initiated Page 9.4-3 on detection of chlorine Sect ion 9.4.1.1 Page 5 of 7 m
| |
| O
| |
| | |
| a FSAR DESCRIPTION REFERENCE D Gland Seal Steam Exhaust Ventilation System: two 100%
| |
| capacity charcoal and HEPA filters to reduce pot ent ial of turbine radioactive release Page 9.4-61 Sect ion 9.4.15.2 Condensate Polishing Building Ventilation: contains its Figure 9.4-17 own HEPA filters to minimize discharge of radiation to environment Fire protection system meets intent of Branch Technical Page 9.5-1 Position CMEB 9.5-1 Sect ion 9.5.1.1 Alternate shutdown capability (Appendix R) Page 9.5-6 Sect io n 9.5.1.2.4 Steam Dump: turbine by pass system up to 90% full load Page 10.1-1 steam te condenser Sect ion 10.1 Turbine: 888 MWe, 1800 rpm Table 10.1-1 Page 1 of 3 Turbine Control System: step load increase 10%; ramp Page 10.2-4 load 5%/ min. over a range of 15% to 100%; no reactor trip Sect ion on turbine trip below 10% 10.2.2.1.1 Steam Generator Safety Valves: sized to pass steam flow Page 10.3-3 f''T for load rejection without reactor trip Sect ion 10.3.*2 O Circulating Water Flow Path: from cooling tower base by Page 10.4-13 gravity to condenser inlet (siphon ef fect) (vacuum prime Sect io n system) to pump house to cooling tower fill 10.4.5.2 Condensate Polishing System: five filter /demineralizers; Page 10.4-19 designed for full condensate flow; not for full-t ime Sect ion operation; used to maintain chemistry 10.4.6.2.1 Primary Plant Demineralized Water Storage Tank (140,000 Page 10.4-38 gal.) with connection to Demineralized Water Storage Tank Sect ion (600,000 gal.) 10.4.9.2 Hafnium control rode utilised (reduces tritium source Page 11.1-5 i from Ag-In-Cd) Sect ion 11.1.3.2.2 Gaseous waste system processes for BVPS-2; decay and Page 11.3-1 discharge ut ilizes BVPS-1 sys tems Sect ion 11.3 Air ejector charcoal delay beds accept effluent from Page 11.3-5 BVPS-1 and BVPS-2 Sect ion 11.3.2.2 Page 6 of 7 77
| |
| %]
| |
| | |
| FSAR DESCRIPTION REFERENCE Digital radiation monitoring system (CRT, printer in Page 11.5-15 Sect ion control room) 11.5.2.6.I Digital radiation monitoring system central processor Page 11.5-18 functions and data files (trend, etc.) Sect ion 11.5.2.7 l r3
| |
| 's Page 7 of 7
| |
| | |
| ADVISORY COMMITTEE ON REACTOR SAFEGUARDS i
| |
| i J. J. CAREY John J. Carey is Vice President of Duquesne Light Company's (DLC) Nuclear l Group. DLC is a public utility incorporated under the laws of the Common-wealtn of Pennsylvania and is engaged in the generation, transmi ssion, distribution, and sale of electricity in the city of Pittsburgh and munici-palities in Allegheny and Beaver Counties, Pennsylvania. Mr. Carey is responsible for all nuclear activities. These activities include management; O* administration of operation, maintenance, fuel, engineering, and capitol improvements; and construction at BVPS-2.
| |
| A native of Anbridge, PA, he graduated from the University of Pittsburgh with a B.S. degree in Electrical Engineering in 1956. Mr. Carey began his utility career in 1958 as a Test Engineer in the Power Stations Department. In 1960 he becane Chief Electrician at Phillips Power Station in the Power Stations Department. He was appointed Electrical Maintenance Engineer in 1963, and in 1966 ne becane Superintendent of Elrana Power Station. In 1971 he was appointed Superintendent of BVPS-1 and then becane Technic al Assistant, Nuclear, in 1974. In 1979 he becane Director of Nuclear Operations and was appointed Vice President, Nuclear Division, in 1981. He assuned his present position as Vice President, Nuclear Group, in 1983.
| |
| Mr. Carey is a registered Professional Engineer in the State of Pennsylvania.
| |
| Jack and his wife Joyce have two children and live in Anbridge, PA.
| |
| O
| |
| | |
| ADVISORY COMMITTEE ON REACTOR SAFEGUARDS R. E. MARTIN Roger E. Martin is Manager of Duquesne Light Company's (DLC) Engineering Department. DLC is a public utility incorporated under the laws of the Commonwealth of Pennsylvanta and is engaged in the generation, transmission, distribution, and sale of electricity in the city of Pittsburgh and munici- ,
| |
| palities in Allegheny and Beaver Counties, Pennsylvani a. Mr. Martin is responsible to the Vice President of the Nuclear Group for the adequacy of engineering and design of BVPS-2.
| |
| A native of Springfiald, OH, he graduated from Bucknell University with a B.S. degree in Mechanical Engineering in 1949. Mr. Martin began his utility career in 1949 as an Engineer in the coal fired generator stations. In 1972 he was named Nuclear Engineer in the Engineering and Construction Division, and became Director of Nuclear Engineering in 1981. He assuned his present
| |
| ! position as Manager of Engineering in 1984.
| |
| Mr. Martin is a member of ASME, Anerican Nuclear Society, and Atomic Indus-trial Forum. He is a register Professional Engineer in the State of Pennsyl-vania. Roger and his wife Joyce have two children and live in Gibsonia, PA.
| |
| O
| |
| | |
| +
| |
| l i
| |
| ADVISORY COMMITTEE ON REACTOR SAFEGUARDS !
| |
| i R. J. SWIDERSKI
| |
| {:
| |
| l j Richard J. Swiderski is Manager, Nuclear Construction, of Duquesne Light
| |
| ; Company's (DLC) huclear Construction Department. DLC is a public utility incorporated under the laws of the Commonwealtn of Pennsylvania and is engaged in the generation, transmission, distribution, and sale of electric-ity in the city of Pittsburgh and municipalities in Allegneny and Beaver Counties, Pennsylvania. Mr. Swiderski is responsible for site construction activities, the startup and test program, and construction modifications for BVPS-2, and assigned maintenance and construction proof-testing for BVPS-1.
| |
| A native of Pittsburgh, PA, he attended the University of Pittsburgh and Point Park College studying mechanical and electrical engineering. Mr.
| |
| Swiderski began his utility career in 1958 in the Substations and Shops Department. In 1963 he was assigned as Automatic Controlman in the Substa-tions and Shops Department. In 1972 he was assigned as Construction Inspector in the General Construction Department, and in 1973 he becane Chief Construc-tion Inspector at BVPS-1. He assuned his present position as Manager in 1982.
| |
| Mr. Swiderski is a member of the EEI Construction Committee and Labor Rela-tions Subconmittee. He served in the Army fran 1961 to 1963. He left the Army as a Specialist E5. Rich and his wife Rose have three children and live in North Hills, Pittsburgh, PA.
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| O
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| g-ADVISORY COMMITTEE ON REACTOR SAFEGUARDS J. D. SIEBER John D. Sieber is Senior Manager of BVPS-1 and General Manager of Nuclear i Services Unit of Duquesne Light Company's (DLC) Nuclear Group. DLC is a public utility incorporated under the laws of the Commonwealth of Pennsyl-vania and is engaged in the generation, transmission, distribution, and sale of electricity in the city of Pittsburgh and municipalities in Allegheny and '
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| Beaver Counties, Pennsyl vania. Mr. Sieber is responsible for operation, maintenance, and modifications of BVPS-1 and for radiological control, secur-ity, nuclear safety, personnel and industrial relations, records, budget, and fuel management for BVPS-1 and for BVPS-2 when BVPS-2 becomes commercial.
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| A native of Pittsburgh, PA, he graduated from Carnegie-Mellon University with a B.S. degree in Mechanical Engineering in 1961. He has completed special courses in Nuclear Physics at Purdue University and Nuclear Safety at Massa-chusettes Institute of Technology. Mr. Sieber began his utility career in 1961 as a Test Engineer at the Shippingport Atomic Power Station. He has l
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| held the positions of Instrument Engineer, Nuclear Training Engineer, Care Analysis Engineer, Superintendent of Licensing, and Manager of Nuclear Safety and Licensing. He asstrued his present position as Senior Manager on January 1, 1985.
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| Mr. Sieber served in the Army from 1961 to 1963. He left the Anny as First Lieutenant, Signal Corps. Jack and his wife Carol have two children and live in Franklin Park, PA.
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| g-ADVISORY COMMITTEE ON REACTOR SAFEGUARDS l
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| l E.F.KURTZ !
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| l Eugene F. Kurtz, Jr., is Man ger of Duquesne Light Company's (DLC) Regulatory Af f airs Department. DLC is a public utility incorporated under the laws of the Commonwealth of Pennsylvania and is ecgaged in the generation, transmis-sion, distributien, and sale of electricity in the city of Pittsburgh and i municipalities in Allegheny and Beaver Counties, Pennsylvania. Mr. Kurtz is O resPensible ror eeveioPi n9. 4 P,ementin9. end meieteinin9 t8e totei re9uie-tory progra for BVPS-2 to assure the project's empliance in all regulatory aspects.
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| A native of Pittsburgh, PA, he graduated from Penn State in 1968 with an ;
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| Associate degree in Electrical Engineering, from Point Park College in 1973 with a B.S. degree in Electrical Engineering Technology, and from Carnegie-Mellon in 1980 with an M.S. degree in Nuclear Engineering. Mr. Kurtz began his utility career in 1970 as an Associate Engineer in the Power Stations Department. In 1973 he becue a Nuclear Shif t Foreman in the Nuclear Divi-sion, and in 1976 he was appointed Senior Quality Assurance Engineer. In j 1980 he becue Supervising Engineer, Nuclear, in the Engineering and Con-struction Division. He asstsned his present position as Manager, Regulatory Affairs, in 1982. I i
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| l Mr. Kurtz is a member of the American Nuclear Society and held an Operator's License on BVPS-1 in 1976. He served in the Army from 1968 to 1970. Gene
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| $ and his wife Chris have one child and live in Scott Township, PA.
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| g-ADVISORY COMMITTEE ON REACTOR SAFEGUARDS W.S. LACEY W. Steven Lacey is Plant Manager of Duquesne Light Company's (DLC) Nuclear Group. DLC is a public utility incorporated under the laws of the Common-wealth of Pennsylvania and is engaged in the generation, transmi ssion, distribution, and sale cf electricity in the city of Pittsburgh and munici-palities in Allegheny and Beaver Counties, Pennsylvania. Mr. Lacey is responsible for all operative, mair.tenance, and testing activities at BVPS-1 and -2 and assures the stations are operated in accordance with Technical Specifications and applicable regulations and procedures.
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| A native of Pittsburgh, PA, he graduated fron Allegheny Community College with an Associates degree in Electrical Engineering in 1971 and Cornell University with a B.S. degree in Electrical Engineering in 1973. Mr. Lacey began his utility career in 1973 as a Test Engineer in 'he Nuclear Group. In 1974 he was naned Nuclear Operating Foreman at BVPS-1 and becane Nuclear Shift Supervisor in 1977. In 1980 he becane Technical Advisory Engineer, and in 1982 he was assigned to the Chief Engineer position at BVPS-1. He assuned his present position as Plant Manager in 1983.
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| Mr. Lacey served in the Navy (Submarine Service, Nuclear) from 1963 to 1969.
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| l He left the Navy as an E-6 Electrician. Steve and his wife Susan have two children and live in Moon Township, PA.
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| ADVISORY COMMITTEE ON REACTOR SAFEGUARDS T.D. JONES Thomas D. Jones, II, is General Manager of Duquesne Light Company's (DLC)
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| Nuclear Operations Unit. DLC is a public utility incorporated under the laws of the Commonwealth of Pennsylvania and is engaged in the generation, trans-mission, distribution, and sale of electricity in the city of Pittsburgh and municipalities in Allegheny and Beaver Counties, Pennsylvania. Mr. Jones is l responsible for operation, maintenance, and testing of BVPS-1 and -2. f l I I
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| A native of Western Pennsylvania, he graduated from Lehigh University with a B.S. degree in Mechanical Engineering in 1960. Mr. Jones began his utility ,
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| career in 1960 as an Engineer in the Power Stations Department. In 1970 he was named Maintenance Supervisor in the Shippingport Atomic Power Station and j becane Superintendent in 1974. He asstsned his present position as General Manager in 1984.
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| Mr. Jones is a member of the EEI Nuclear Operators Committee. Tom and his wife Anita have three children and live in Sewickley, PA.
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| #~-a ADVISORY COMMITTEE ON REACTOR SAFEGUARDS F.D.SCHUSTER is Technical Advisory Engineer of Duquesne Light Company's Fred D. Schuster OLC is a public utility incorporated under the (DLC) Nuclear Sta-t-Up Group.
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| laws of the Commonwealth of Pennsylvania and is engaged in the generation, transmission, distribution, and sale of electricity in the city of Pittsburgh Mr.
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| and municipalities in Allegheny and Beaver Counties, Pennsyl vani a.
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| O Schuster is responsible for shift operating personnel and generation of operating procedures and manuals.
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| A native of Youngstown, OH, Mr. Schuster began his utility career in 1970 as In a Station Operating Forenan at the Shippingport Atomic Power Station.
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| 1975 he was naned Nuclear Shif t Supervisor at BVPS-1 and transferred to the He assuned his present position as Technical BVPS-2 Start-Up Group in 1978.
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| Advisor Engineer in 1984.
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| He left Mr. Schuster served in the Navy (Nuclear Progran) from 1960 to 1967.
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| the Navy as an ET-1 responsible for the Reactor Control Division of the Submarine "Seawolf." Fred and his wife Linda have two children and live in Liberty Township, OH.
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| ADVISORY COMMITTEE ON REACTOR SAFEGUARDS G.L.BEATTY Gary L. Beatty is Lead Licensing Engineer 'of Duquesne Light Company's (DLC)
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| Regulatory Aff airs Department. OLC is a public utility incorporated under the laws of the Commonwealth of Pennsylvania and is engaged in the genera-tion, transmission, oistribution, and sale of electricity in the city of Pittsburgh and municipalities in Allegheny and Beaver Counties, Pennsylvania.
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| O Mr. Beett, is respeesibie for the Primers iete.rfece w4th saa eerin2 the safety review.
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| A native of Pittsburgh, PA, he graduated from Carnegie-Mellon University with a B.S. degree in Electrical Engineering in 1975. Mr. Beatty began his utility career in 1975 as an Engineer in the Quality Assurance Department.
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| He assumed his present position as Lead Licensing Engineer in 1982.
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| Gary and his wife Kathy live in Hookstown, PA.
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| ADVISORY COMMITTEE ON REACTOR SAFEGUARDS C. E. EWING C. Eugene Ewing is Manager of Duquesne Light Company's (DLC) Quality Assur-ance Unit. OLC is a public utility incorporated under the laws of the Commonwealth of Pennsylvania and is engaged in the generation, transmission, distribution, and sale of electricity in the city of Pittsburgh and munici-palities in Allegheny and Beaver Counties, Pennsylvania. Mr. Ewing is O resPees4=>e rer t"e o#e>4t> ^>ser #ce me o# '4t> ce tre' oeP rt e"ts <er both BVPS-1 and -2. ,
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| A native of Elkton, MD, he graduated from Lehigh University with a B.S.
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| degree in Mechanical Engineering in 1959, and a M.S. degree in Business Administration fran Robert Morris College in 1985. Mr. Ewing began his utility career in 1959 _s a Test Engineer at the Shippingport Atomic Power St ation. In 1976 he was naned Senior Quality Assurance Engineer in - the Quality Assurance Department, and he becane Quality Assurance Supervisor in 1977. He asstrued his present position as Manager in 1981.
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| Mr. Ewing is a member of ASME and ASQC. Gene and his wife Blanche have t'iree children and live in Moon Township, PA.
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| g-l ADVISORY COMMITTEE ON REACTOR SAFEGUARDS T.W. BURNS Thomas W. Burns is Director Operations Tra'ining of Duquesne Light Company's (DLC) Nuclear Training Department. DLC is a public utility incorporated under the laws of the Commonwealth of Pennsylvania and is engaged in the generation, transmission, distribution, and sale of electricity in the city of Pittsburgh and municipalities in Allegheny ana Beaver Counties, Pennsyl-vania. Mr. Burns is responsible for the development, conduct, and adminis-tration of the nuclear license training and license retraining progres to provide skilled operating personnel for BVPS-2 in a safe, efficient, economi-cal manner.
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| A native of Pittsburgh, PA, he attended Penn State University in the Credit Acquisition Progra for SR0s. Mr. Burns began his utility career in 1971 as a Station Operator at Shippingport Atomic Power Station in the Power Stations Department. In 1972 he was need Operator at BVPS-1. He becue Operating Forenan in 1973 and licensed SR0 in 1975. In 1977 he becue a training instructor in the Training Department. He assumed his present position as Director Operations Training in 1985.
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| r He served in the Navy fran 1965 to 1971 in the Nuclear Progre. He left the !
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| Navy as an EM-2. Tom and his wife Armandina have two children and live in l Brighton Township, PA.
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| On-a ADVISORY COMMITTEE ON REACTOR SAFEGUARDS R. W. FEDIN Ronald W. Fedin is Sr. Project Engineer of Duquesne Light Company's (DLC)
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| Regulatory Affairs Department. DLC is a public utility incorporated under the laws of the Commonwealth of Pennsylvania and is engaged in the genera-tion, t ar smission, distribution, and sale of electricity in the city of l Pittsburgh and municipalities in Allegheny and Beaver Counties, Pennsylvania.
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| Mr. Fedin is responsible for the nuclear safety activities associated with licensing the BVPS-2 Technical Specifications.
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| A nati.'e of Berwick, PA, he graduated from Penn State University with a B.S.
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| degree in Nuclear Engineering in 1975 and an M.B.A. degree from Western New England College in 1981. Mr. Fedin began his career in 1975 as a Operations Engineer for General Electric at the S3G prototype reactor. In 1977 he began working for Combustion Engineering as Design Engineer in the Reactor Coolant Systen Department, later moving on to the Licensing Department. He assuned his present position with DLC as Sr. Project Engineer in 1982.
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| Mr. Fedin is a member of the ASME. Ron and his wife Karen have three children and live in Coraopolis, PA.
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| g-ADVISORY COMMITTEE ON REACTOR SAFEGUARDS l
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| l E. T. ElLMANN Ervin T. Eilmann is Lead Licensing Support Services Engineer of Duquesne Light Company's (DLC) Regulatory Aff airs Department. DLC is a public utility incorporated under the laws of the Commonwealth of Pennsylvania and is engaged in the generation, transmission, distribution, and sale of electric- ;
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| ity in the city of Pittsburgh and municipalities in Allegheny and Beaver '
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| Counties, Pennsylvania. Mr. Eilmann is responsible for technical and admin-O istrative supervision of the Licensing Support Services Section which '
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| includes such activities as environmental protection, equipment qual i fic a-tion, fire protection, nuclear safety, permits, and licensing scheduling and planning.
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| A native of Cleveland, OH, he graduated from Valparaiso University with a B.S. degree in Civil Engineering in 1974, and an M.S. degree in Civil Engi-neering from Akron University in 1984. Mr. Eilmann began his utility career in 1974 as an Associate Engineer in the Mechanical Engineering Department of Ohio Edison Company. In 1976 he was named Engineer on the Erie Nuclear Plant Project. In 1982 he was loaned to DLC and assumed his present position as Lead Licensing Support Services Engineer.
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| Mr. Eilmann is a registered Professional Engineer in the State of Ohio. Erv and his wife Linda have one child and live in Beaver, PA.
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| #~-a ADVISORY COMMITTEE ON REACTOR SAFEGUARDS l
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| l K.D.GRADA Kenneth D. Grada is Manager, Nuclear Safety, of Duquesne Light Company's (DLC) Nuclear Group. OLC is a public utility incorporated under the laws of the Commonwealth of Pennsylvania and is engaged in the generation, transmis-sion, distribution, and sale of electricity in the city of Pittsburgh and municipalities in Allegheny and Beaver Counties, Pennsylvania. Mr. Grada is responsible for interfacing with the NRC on licensing and safety issues, fire protection, and independent safety evaluation group.
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| A native of Pittsburgh, PA, he atter.ded U.S. Maritime Acadeny, Penn State University, and Rennsaylaer Polytechnic Institute in the Mechanical and Electrical Engineering prograns. Mr. Grada began his utility career in 1969 in the High Tension Meter and Test Lab. In 1970 he becane a Radiation Technician at Shippingport Power Station. In 1971 he becane Nuclear Station Operator at Shippingport Power Station. In 1972 he was appointed Operating l
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| Foreman at BVPS-1 and to Shift Supervisor in 1974. In 1981 he was appointed Superintendant of Licensing at BVPS-1. He assuned his present position as Manager Nuclear Safety in 1983.
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| l He served in the Anny from 1967 to 1969. He left the Army as Staff Sergeant.
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| ( Ken and his wife Linda have two children and live in Pittsburgh, PA.
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| ADVISORY COMMITTEE ON REACTOR SAFEGUARDS 1
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| J.A.HULTZ James A. Hultz is Deputy Project Manager of Duquesne Light Company's (0LC)
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| Construction Liaison Group of the Project Controls Department. OLC is a )
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| public utility incorporated under the laws of the Commonwealth of Pennsyl-vania and is engaged in the generation, transmission, distribution, and sale of electricity in the city of Pittsburgh and municipalities in Allegheny and Beaver Counties, Pennsylvania. Mr. Hultz is responsible for construction and engineering interfaces on BVPS-2.
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| A native of Bethel Park, PA, he graduated fron Penn State University with a ,
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| B.S. degree in Nuclear Engineering in 1971. Mr. Hultz began his utility career in 1971 as a Junior Engineer in the Nuclear Engineering Department of Ohio Edison Company. In 1972 he becane an Associate Engineer in the Nuclear Engineering Department. In 1975 he was pronoted to Engineer and in 1978 he becane the General Project Engineer for the Erie Nuclear Project. In 1982 he was loaned to DLC as Deputy Project Manager for Engineering and Licensing in the Nuclear Construction Division. He asstaned his present position as Deputy Project Manager in 1984.
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| Mr. Hultz is a member of the Anerican Nuclear Society and is a register Professional Engineer in the States of Ohio and Pennsylvania. Jay and his wife Linda have two children and live in Beaver, PA.
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