ML20237J394
| ML20237J394 | |
| Person / Time | |
|---|---|
| Site: | North Anna  |
| Issue date: | 07/24/1987 |
| From: | Engle L Office of Nuclear Reactor Regulation |
| To: | Miraglia F, Murley T, Sniezek J NRC |
| Shared Package | |
| ML20235W119 | List:
|
| References | |
| FOIA-87-461 NUDOCS 8708260145 | |
| Download: ML20237J394 (62) | |
Text
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gi. kg UNITED STATES NUCLEAR REGULATORY COMMISSION ;
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3 - 'la WASHINGTON, D, C. 20555
%,a...+/ July 24, 1987 i
- Docket No. 50-338 l MEMORANDUM FOR
- T. Murley* J. Partlow R. Capra , W. Troskoski J. Sniezek* F. Congel W. Butler ';
F. Miraglia* J. Roe V. Nerses R. Starostecki* S. Black
- J. Stolz S. Varga* B. Boger* Er Adensam D. Crutchfield* G. Lainas* L. Rubenstein '
L. Shao* F. Schroeder B. J. Youngblood "CURoss1*Ety G. Holahan A. Thadani J.'Richards*on W. Lanning R. Cooper THRU:
Lester S. Rubenstein, Director Project Directorate II-2
[ ,
Division of Reactor Projects-I/II
-w FROM: Leon B. Engle, Project Manager Project Directorate II-2 Division of Reactor Projects-I/II
SUBJECT:
DAILY HIGHLIGHT, NORTH ANNA UNIT 1 As of Thursday, July 23, 1987, the licensee has formalized the eddy current inspection of the steam generator (SG) "C" as follows:
- 1. The standard bobbin probe examination required by Technical Specifications (TSs) will be completed for the hot leg side and also for the cold leg side. Cold leg side inspection is not required by TSs.
- 2. An 8x1 nrobe examination for more accurate flaw characterization will j be conducted from the hot leg tube sheet, over the U-bend and all the way to the cold leg tube sheet, t
- 3. Every indication detected by 8x1 probe will be verified b pancake coil probe (RPC) and also profiled (profilometry)y the rotating
- 4. Defective tubes will be plugged.
For SG's "A" and "B", the inspection is tentatively scheduled as follows:
- 1. A standard bobbin probe examination will be conducted full length on all tubes not inspected in the Spring 1987 outage.
- 2. A 100% 8x1 probe inspection will follow on cold leg side tubes through the 7th tube support plate.
- 3. RPC probe inspection and profilometry verification will follow, as required.
- 4. Defective tubes will be plugged.
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Reportable Event Number 00677 Unevaluated Information ,
Facility : NORTH ANNA Date Notified : 05/14/87 Unit : 1 Time Notified : 17:17 Resion : 2 Date of Event : 05/14/87 Vendor : WEST, WEST,B&W Time of Event : 17:08 Operations O f f i c 6' r : Dick dolliffe Classification : 10 CFR:50.72 NRC Notified BY : BOWLING Catesory 1 :
Rad Release : No Catesory 2:
Cause : Mechanical Failure Catesory 3:
Component : STEAM GEN TUBES Catesory 4 :
PLANT IN MODE 6 WITH THE CORE DEFUELED - IT HAS BEEN DETERMINED BY EDDY CURRENT TESTING THAT GREATER THAN 1% OF THE INITIAL SAMPLE GROUP OF THE Tube CF 2 OF 0 SGs (#A & B) ARE DEFECTIVE. LER TO FOLLOW. LICENSEE PLANS TO ED CURRENT TEST ALL TUBES OF ALL 3 SGs. LICENSEE INFORMED RI. NOTIFIED R2DO ,
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l i I rtable Event number 09315 acility : NORTH ANNA Date Notified : 07/15/87 { Time Notified : 07:04 l Unit : 1 Region : 2 Date of Event : 07/15/87 4 Vendor : WESTiWEST Time of Event : 06:54 operations Officerfr TOM SILKO Classification : Alert NRC Notified By : MARSHALL Category 1 : SCRAM Rad Release : Yes Category 2 : ESF Actuation Cause : Mechanical Failure Category 3 : S/G TUBE RUPTURE Component : S/G TUBE Category 4 : s l EVENT DESCRIPTION : l RX AT 100%. AN UNUSUAL EVENT WAS DECLARED AT 0639 HRS AND AN ALERT WAS DECLARED AT 0654 HRS DUE TO A 'C' S/G TUBE LEAK. THE S/G TUBE LEAK WAS
'C' BLOW DOWN LINE. A ,
4 DETERMINED BY LOW PZR PRESSURE AND HIGH ACTIVITY IN l SAFETY INJECTION OCCURRED ON LOW PZR PRESSURE. AT THE TIME OF THE EVENT I REPORT THE UNIT WAS AT ZERO PERCENT POWER. A SMALL RAD RELEASE OCCURRED VIA THE CONDENSER AIR EJECTOR EXHAUST AND THE AFW PUMP TERRY TURBINE EXHAUST PATHS. INITIAL INDICATIONS PLACE THE RELEASE AMOUNTS AT APPROX 1.3% l OF THE TS LIMIT. THE NRC ENTERED THE STANDBY RESPONSE MODE AT 0715 HRS. A COMMISSIONERS ASSISTANCE BRIEFING WAS CONDUCTED AT 0900 HRS.'*** UPDATE AT I 5-D *** TOTAL RELEASE AS OF 1218 WAS 2. 65 E-1 Ci (Xe-133 EQ) => 0.62% T.S. OPERATORS j
- QTS. RELEASE WAS MOSTLY TRITIUM AND Xe. ADDITIONAL INFORMATION: I C '3ERVED LOW PRZ PRESS AND. LEVEL IN CONJUNCTION WITH " ALERT" CONDITION ON THE SG BLOWDOWN MONITOR AND MANUALLY SCRAMMED THE PLANT. SI APPARENTLY OCCURRED AFTER SCRAM. SJAE EXHAUST WAS EVENTUALLY ROUTED TO CONTAINMENT. *** UPDATE o AT 1241 *** UNIT WENT ON RHR AT 1216. NRC RETURNED TO NORMAL MODE FROM STANDBY AT 1241. *** UPDATE AT 1338. UNIT IS IN COLD SHUTDOWN. ALERT WAS TERMINATED AT 1331.
I
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- UNIT 1 STEAM GENERATOR TUBE RUPTURE EVENT ON JULY 15, 1987 At approximately 6:35 a.e. on July 15, 1987, North Anna Unit I was manually j tripped from 100% power due to indications of a steam generator tube rupture !
in the "C" steam generator. Approximately twenty seconds later, the safety injection system automatically initiated.
~ .,
At 6:39 a.m., a " Notification of Unusual Event" was declared after indications of the tube rupture -(primary to secondary leakage exceeding one gallon per i minute) in "C" Steam Generator were evaluated by control room personnel. I Initial notifications to NRC and offsite agencies were completed by 6:51 a.m. { By 6:54 a.m., the event was upgraded to an " Alert" classification at the ! direction of the Interim Station Emergency Manager. Notifications to the NRC and offsite agencies that were required as a result of the upgraded l classification were compacted by 7:02 a.m. All maj or plant equipment ) I functioned properly, and the unit was stabilized in accordance with Station ! Emergency Operating Procedures. In addition. Emergency Plan Implementing ] Procedures respective to an " Alert" classification were implemented to augment - the onshift staff. By 7:28 a.m., an accountability of all station personnel had been conducted. By 7:57 a.m., the Technical Support Center and Operational Support Center were fully manned and activated. By 9:15 a.m., the Local Emergency Operations Facility was fully manned and activated. The initial indications available to the operators were from the main steamline radiation monitors which went into alert at approximately 6:30 a.m. on July 15, 1987. Subsequently, pressurizer pressure and level began to decrease rapidly. Pressurizer pressure decreased (after the manual reactor trip) to approximately 1730 psig which is below the safety injection setpoint of 1765 psig. Pressurizer level decreased from its 100% power program level of approximately 65% to offscale low prior to recovery. The , maximum primary to secondary leak rate has been estimated to be 637 spm. The re-establishment of pressurizer level and isolation of the ruptured "C" steam generator was completed under Station Emergency Operating Procedures (EP-0 and EP-3, Revision 1). Cooldown and depressurization of the RCS was initiated at 7:10 a.m. in accordance with Station Emergency Operating Procedure ES-3.1, Revision 1 and proceeded routinely. At 11:09 a.m., the RCS was cooled down to below 350 degrees F, and Unit I was placed in Mode 4. Hot Shutdown. At 1:33 p.m., the RCS was cooled down to less than 200 degrees F. and the unit was placed in Mode 5, Cold Shutdown. Plant conditions were stable and the emergency was terminated at 1:36 p.m., at which time termination notifications were made to the NRC and offsite agencies. During the course of the event, effluents released from "C" Steam Generator prior to its isolation occurred through the Condenser Air Ejector and Auxiliary Feedwater Pump Turbine exhaust. However, the release was determined to be very small. Isotopic analyses performed on samples drawn from these pathways are as follows: Contribution from Condenser Air Ejector gaseous activity was 0.44% of Technical Specification limits and Iodine activity was Fe2.4 - 9 7-W, l Spy l [ _ _ _ _ - . _ _ _ _ - _ _ _
_ _ . - - - - - - - ~- 1 l [!.1# 1ess than detectable. Contribution from the Auxiliary Feedwater Pump Turbine i was 0.175% of Technical Specification limits, for a total release of 0.62% of Technical Specification limitt. Information Contacts:' M* L' Bowlins (703-894-5151) or R. .J. (804-273-2908), - Hardwick l I ( l 4 t I I l I 1 l l I I e- - 8, ~~ee, J
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w . . ._ . , . J'- _ UNIT'1, STEAM GENERATOR TUBE RUPTURE SEQUENCE OF EVENTS 2",. July 15 1987 1
.m. .
0630 'C' St'am e Generator Feedflow begins to decrease slightly , (compared to 'A' and 'B') Steam flow remained relatively I constant 0630 Pressurizer Pressure began decreasing 0630 Pressurizer Level began decreasing ! 0630 Received Annunciator alarm en Main Steam Rad Monitors. Main 'A' and 'B' Steamline NRC Rad Monitors vera in Alert and the "C" Steam line NRC Rad Monitor was in High alarm (i.e.. HI-HI alarm) 0633 Letdown isolated and charging pump suction realigned to Refueling 1
. Water Storage Tank, A unit ramp down of ~2%/ minute was i initiated.
l 0635:04 Manual Reactor Trip l
'0635:06 Manual Turbine Trip !
1 0635:07 Pressurizer Low Pressure Reactor Trip Signal 0635 Auxiliary Feed Water Pump 3A, 3B Breakers closed 0635:24 Pressurizer Low Pressure Safety Injection ('B' Charging Pump. A,B Low Head Safety Injection Pump breakers closed) i 0635:24 Feed Water Pump Breakers Open ! p 0635125 Feed Water Pump Breakers open 0644 Lov Head Safety injection Pumps Shut Down C650 Feed to 'C' Steam Gent.rator isolated and level still increasing 0654 'C' Steam Generator ;ompletely isolated 0657 Plant Conditions 'C' Steam Generator Level '60% NR l 'A' Steam Generator Level 'O NR i
'B' Steam Generator Level 'O NR Pressurizer Level '5%
Pressurizer Pressure Increasing E6IN - 7 7- We / B/ is-
m P,
/
.- 0701 f
S cured Prcasuriter Hsetor (Pressurize pressure increasing and Pressurizer Level 10-15%) ,_. .__m--------~
0704 'B' Charging. Pump Shut Down' -- - -- ~~ ~ ~ ~ ~ ~ ~ ~: ~ ' 0704 Open 1 Pressurizer Power Operated Ralief Valve to reduce pressure IAW EP-3. Relief VelvePressurizer Closed. 'C' Pressure reduced 40 PSIC and Power Operated Steam Generator level increase stopped 0710 Transitioned to ES 3.1 " POST-STEAM GENERATOR TUBE RU C00LDOWN USING BACKFILL" 0713:21 Reactor Cooling Pump 'C' Shut Down 0713:22 Reactor Cooling Pump 'B' Shur Down 0715 Supt. Operations and SRO-ON-Call arrived in Control Room 0720 . Station Manager arrived in Control Room 0730 Asst. Station Manager arrived in Control Room 0739 Station Manager assumes Station Emergency Manager Position i 0757 TSC activated 0915 e LEOF activated 1108 Entered Mode 4 1218 Placed RHR in service 1330 i Enter Mode 5 1335 Terminated Emergency 1 . l
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% gT-p$$'Fifollowing.chronologyswasMWToisopport:thetinvesti .
h k s 4f th typewriter + attached ::co :the Cont recons truc tedifrom :the ; print gfry" eouts My
' , /jW@.2 Support 94Eter vents' ' Recorder dDranets)e: alarm n
<driva~ AV %y V.1.WRoom -recorders.,p.10and s i
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< significance (n
.Selectedsdata was: transmitted'from-the v
-.explicitlycor !issch.datuminn it . identified na taub-svarious : records
" chronology;can. implicitly, .a;sub event en nin:the esequenca "t or < d saccuracy<andestiactiveness of.be .integratad with other.an ;
synchronies:for: time 202 thOnce the -
.c data ent. was tra
- for . synchronism t wes a 'various data 1 sources.,
- tha . Automatic 'Pa sa ; review -wes : perform
.eaveral that:make:it actions ersadily : including comparabl .fsedwater r Lo-Lo:8I. isol :The .51 actiones:incorporat'Th Aecorder ' legged :8I sti.06
.at10639.: e overiall 33:24:8051 ation records.- tand normal. %'$equence charging: cf $ isolation
-ita . scan :Tates. %eHooever 'the , alarmthetearlier! typewriter enReactor-Hanu vents
- the :P-250 l l
. ogged :81 cycles, swhicheequates P-250' Post 2 ripareview.lossediS1 to 106::35:40.'86
- Trip:hte caused :the!P-250:to alter .
- initiated.
.gpm generators, 18y:06r34 impproxima r21, ethe The '.ERFC u l:
'ERFC power tely d ' feed:
- 16 tdata '. taeconds flow:to set. collected at s
the 6:34:_14 sateam
~
asf tre 04at'06 and tfand :fl er:the : reactor trip;had baan ,manu.: e c'~ rasched .a tatable sbutata: befora~06:34:14 .
. low set:charging level.ows
. flow:are IBy 06134 34. tall: flows hed da sabout traduced ally' "to 82.'56 600EBE-
- E J. chronology 'It will us
. appears :that ;81 occurre:d ,at or 2sli h e'06 34:14.
g tly
.:Forara .as<automatie :follows: laitia tion .of :
Safety: Injection. -the clock cob
. RECORDER arisons y,d
- P-250
.IRF Computer.(ERFC) computer (Alars er) 06:35:24:405;Typewrit' Sequence:of!R
, . . 06:35:41- -
06:34:14
-Por: Reactor 3 Manual: Trip tha cl :, -
m - . , yp
' RECORDER
. = -
- ock comparisons.ars.as ?followat
' TIME.
'P-250 computer (Alarm 06:35:04't Typewriter):Sequance 4 ~
! y :RRy Computer;(RRPC) 548.
06:35:24 - 06t33:56
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.0631 0632 tinit:1 CRO.ebserved;the pressurizer level apidly. decreasing r
.U-2 210 : recalled'the:Shitt :
n.r. ,
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'heceived:
Typewriter). CRO:took Pressurizer manus 1 control.cf charging low,pressureialarm4at . 2135:peig . ian(A arm l 0633 .
-shitt
. isolation ' Supervisor sentered-the control: \
I andAa: .CR0: Room and of directedletdown minuteinitiated:raalignaanc charginggumpinaction c ( 21:per: turbina:raspidown. Operator) 4 assumed 230P duttae :en %it ':1 Control :'B' Third CRC CRO. 20i3%.') > (Atarm ' Typewriter t :Make-up :comm n ,q ' . enced.; VCT;10w;1evol ealarm .oard) 0634 , p - ' ' , .
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.STA arrivad;in:the Control'hoon.
- Alansifypewriter: '
1
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Superintendent:of manuali tripped.. 'Operationswas notifindiand di1 Pre :
- 1 rected tha Unit to be 0633 ,
.At
.and': turbine direction 4 sad .ofinitiated 18hift 3P-0.- !$upervisor, 'U-1 CRO e reactor manually
.atapproximately the' tina *of the: manual 45% tend. trip.* pressurizer pressure eataapproxim .
%:a +a e y:2100:psig~
POST TEIP MIVIEWs : Initial Jvent . 06f35124 ' . Sx::Manuahtrip-(2)
"Iurbine: Trip sand P7 ~0.00rsec. - '"~V . ..
70.16 ' . . -
- Righ 1F. lux tRate : Trip 10;3 3
- Ex % nualterip (1)' r 0,60
~
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- 2460 , - -
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.M%r,MMapq@.
" Alarm ne evritert %Antitary:rud swat. N6 le Q 4 g
cinereasing((indiaates .that pocharging;pamp ps: stare.%rCt dM@'M . e.85Ik level:22:k j
/
yMMDoonpletedi)%%
- Qh *h asim m t uctiengehift
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' g'~ 0636.9 f,nw:+8EtrcMainifeedwater:Pumpe
- Trip '(06r3 gEymy +-
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I 1 cto:noted:
- pressurizer level .less :than:St.pressurizer:pressur,e:1ess .
- psis4and thanl170
'il". Charging: Pump;8 tart.Alars' Typewriters *
; tripped.
p: reakers 0537 . e
.Alars' Typewriters ;G-12.. breaker open.'"A",and ~4 '
0639 ,
.A' Notification cf' Unusual: ,
duties (Step '21 as of:27 tutoria'8tation
- 0) ' Emergency:ManagEvent-was ' Unit:2'SRO. assumed decla \
0640* ertand Initiated the EPIPta. o : Entered:EP-3:from' Step:23 of'.EPe0 0641 1
. Alarm:Typewritsr 'Tgyg 0642 i
4Alara: Typewriters'"C" s less .than :343*r. :P-12 : interlock . set. narrow: range.
- team Cenerator:1evel: increasing ,b a'ove 18%
0543* C I
- gsed '"C" 0644 Pfu Main:Sceam* Trip rValves .(Step 4 of:EP43). ~
c.- . Ops W M c^^'*"s
.5I and:Phaes;A raset. 1HSI pump's""A" 1
<and 13, :respectively of EP-3) .5CC d'"1"s 68*"4" shutdown. s (Steps 9, .10, ~
0645 ; s
'.increasing,.
Alarm'Typewritar '"C";$ team: Generator.at 25%-nar
)
0646* row.ranse and ! 06 6 'Suparvisor confirmed Steam(Shift . Generator " 0647 Generator
.ERFe,3
,Alara: typewriter: "# hh based 7np t/a.W.' -on '"C":$level continutifg'team re tinGenerator
'"C":S taam to -riss.). h u
- increasing. c.to w d o 0648 "A" Steam'Ceneratoriat 123% ge)4and (Narrow!R$j g
- ERFCt Oraphs levalsand: of pressurizer level sndIRC8 j1 incom.) s. pressure. u..
(Also noted -on -the sacrip :nhart . . in-the 'C: pressu ontrol 0649
.blocked.
Alarm-(Thelete Typewriters ??rassuriser LoiPress/8 team I y prior to *$tep 1 ow:S1 circuit on "A".and "A": steam dump valvas. 5 of:
' Typewriters 'tB" ' Steam -Generat (8tep'15 of15P43) iAlarsEP .3) .Con{ ;
065dg ; increasing.? Alarm' Typewriters:Presor : level tat ;251 (Harrow: Ran
~ -
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. , : Unit '1 CRO :noted: pressurizer." 'leve15eff
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,1 FROM e NO !ANNR TO .._REG s.., s..
07/20407 :07113 A..iP.,
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*1steriatocation':EmergencyiManagar
'"A1.ERT"#- upgraded seventeclassification to i
.TT - 4.5.6 d ' " .
mm - - i
. Alarm' Typewriters '".5" Main:Paad: Pump breakers: racked to test.and .
'"B"ISteam Canerators) : Steam: Generator!A"4 lpsig. ,
i
' 0555 Initiated:EPIP-3.0i,*503,4and.5.04-(CallDuc,1 Accountability,and Access control).
1 0557 ! 3 trip Chart
- EP43) . iAlara .RCS Temperature being maintainedist-480'F (Step 15 of Typewriter: j l
+
' Valves '"A" sand ""3" open . (step .18 inf 2P-3) .iPressuriser Spray controlist{
06S8f: 1 i Unit'.1 CRO-noted pressurizer: level on tacala sand . increasing. ) 0659 !
' Alma ' Typewriter: !
re-energised ' Source (Range Nuclear : Instruments manual'.y I undercompensa. ted,)(Intermediate : Range '. Nuclear .' Instruments >were - l ' 0700 Alarm'.Typewritdet
- Pressurizer: low: level heater: cut off el sared '(D, vel -
.at 15 Land increasing). :Prassuriser heaters. energized (833 JW).
i 0701 n Unit :1 CR0 manually de-energizas gressuriser heaters. t 0702
.. alert Notification
<classificati4m madatto the:$ tate / Local.0cvarnments and'NRO of upgr 0704 Opened one ' Pressurizer 'PORV te rreduce: pressure (Step 19.of .
. SRO IP-3) I obearvedspressura esduction-ef.approximately 40 psigjand: instructed {
CR0 toiter:
'Typewr. cloas:PORV,and spray-valves (Steps 18$and.19:of.EF-3). Alarm '
i
?Pressortser ;Ralief: Tank pressurs .15 paig.
- 5RO :noted '"C"; Steam Generator '. level '. increase estopped.
'SI reduction criteria met (Step :21.of :EP-3). "B" Charging Pump etocured (5eep:22 cf'EP .3),, .
, ^ initiated the : isolation of E!.'flowpath (Step .'24.cf 'EP-3) and
, established
- , 3 ethe normal charging 'flowpath (Step.25 -of :EP-3).
!( 0106 18 hut""A";and"!!" pressurizerispray valves.: : 0709 iAlarn: Typewriters s ip r (Evaluation :cf this ,antty .indicataa 'that normal .latdown I f restored :in o taccordance with Step ':29.of *EP-3. . l 0710 ; Alter. Typewriters
- EP.43) . e - 'Prassuriser t-hastar breakers eleasd (Step:31 of i
\s % u 9 9
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' 0711 > .A11rm' Typewriter: 64GdiMCC Md@MXMd%'" :QiNS h .
'g F T .h 12Pressurisarthe:ter:braskare c1 reed f(Stsp 31 of $ ' A; i
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Vy,i 1Q % W MMQRQU Q@j@ :Ma&.% M L Qlj? % yg;;i A pim& u f 3:f?$
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+ p 4 0713 U.'JAlars ' Type [ writers tsecured'"C" WeClQ and "! ..
0714 .Alara ' ggyggy.q:w. .
,;p:y,;m.gS-m:,m;y ( .ygmy. Q Typewriter: ' 28 pray 4 demand ?76%. -(fromtthis : time :forverd :RC8 ' l l
p ;preneure g.,+ m... .to maintained by manual <nontrol:of taprey and:bastersi)k. ; i t
'0715 .
g .7 . - . , . . w.q
;g,,,,
Superintendent ief . operation .and :8AO-on-Cal 14 arrived :in the co t 0718 ,
)
- Transitioned :to :ES :3il '"F08T-STEAM GENERATOR " TUB USINC; BACKFILL" (Step 42.of:Ep-3h ,
0720 i
' Station Managerrar'ived in the control Room.
r 1 C721 AlarW 7ypewriter: AFV' Feed Pump 3A .tc "C"' Steam Generstensecured. 0722 Alars' Typewriters .. Pressurizer: level 73% and : decreasing.
+ 0723 Alarm??ypewriter
-t
. (subesquently.AFW pumpe :are. tun . intermittently toasu Canarstor : feed -requirements. ) I 0725 . Alarm
- Typewriters :8 tarted '"5" Condensate:pumpe:now running). condensate pump '(Both !A". and "B" 1
4 0727 . f
- Began IRC8 .aeoidown ;in :accordance <with :58 '3.T. . . 1
. .c
'0730 : Assistant:
StationiManager . arrives in Contro1' Room and initiates transition:of'EFIPsLand communications:from: Control! Room to'TSC.
. 0739
' Station Manager.sesumeo18tation' Emergency Manager position.
0745 Alarm' Typewriter: Turbine en the turning. gear. 0756 ) Condeneer Air' Ejector manually. diverted;to containment. i 0757 Technical:8uppott Center < activated. 0810 Alarm Typewriter: Secured '!B" condensate : pump. 0820 , Corporate :Energency'Renponse Center . activated.
. 4 .
0845 , 4 Started 35":RER' pump-for system varm-up (Step 9 of 28 3.1). 0853 Alarm: Typewriter - [ Closed "A" 4FP.breakere.. -(Breakers .in test'tc 's permit opening'of: pump < discharge valve to use Condensata Tumpsifo food:to:Braam Generators.) . p 0857 Alarm' Typewriter: H
'MFF :to < atop iepraying irom '"8" Tamp reuetion rrelief' va ;
+
0900*' . . ,
- Loose: Parte. Monitoring '8ystem Alarm on .!C":. Steam Generator.
. = .
4 i 0915 ' .
'. spray local: Emergency offeite Facility, activated. _ Commenced;ud I
;to isapplement :RCS :dapretesurisation. '
, ,. ~.
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1215 Jin .accordance-with ": charging : pumps :1-OP-3i3.Placed and '"B"1NSI - sap in '" Pull-to-I.ock" '"A pt
- Secured '"A#:
Raaetor Coolant ' Pump. 1219 Pisced 3.1). :RRR:8ystem .in , service .to : continue :RC8 ' cool own (Step'9 of ES 1254 1312 Main Steam system secured inesccordance wich 1 OP . - ,.
'1330. ..Rastered. Air: Ejector exhaust .to normal. alignment .
+- "tntered Moder.5 1335 1336 ' Station,5aergency Manager terminated:the .
emersone Notified,Nucisar Regulatory Commission 'St tersinscion of amorgency:statua. , 1336 ate.and Local.0cvarnments of
' implemented Secovery organization.
l 9 t 1
- Approximate . Time ~ Ma.w.d f e Cf y $TA O 520 ob5wbdiDN (Ad[p
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Virginia Power North Anna Power Station Unit 1 Primary-to-Secondary Leak Event July 15,1987 l Preliminary Sequence of Events (Prior to 0630, unit 1 operating at 100N of full power) Time Event Description 0630 Re ivec,annuni:'ato a .orm tton on n 'at ne
.and , gcy'eam 10 rs d .
ine )!qd h c
,A e -
('o'>rs
.eam were
_ine Ln gng$rgagin "High Alarm" t fo18- 2 7- O f B//7 l
rssu$iSf
~
oe . rea "g !) moderE.e rate. Plo / ' actor boo 'ank~ 0633 Unit I letdown is isolated and clarging pump suction re-StYEa0nYan .f'k" f min.was ggggwn o
- h. g r$*n"d u[bIha$h psig.En[ A p ssEea't'f100
~
' hah. "In ectkckn
! n b k l e h e f l h s's" labkIO si"f*PZ8 Ou ,
. [Shl'Ikor 0650 t ile ,oC ."C"
- /olatepfeedwaterylog; "
3tgf{ghasdhir g PE s ergenEy op'eratklhS-
0654 "C" S/G completely isolated. ' { Emergencyromclass fg.ation
.o Wggy.
~
i 0657 Unit I conditions:
?
"{"/geve'ggR)R '
) )G E*~ 0% i evesk '
l 3 pressure increasing 1 l 1 l l i
i 0701 Secured P.ZR heat.er; PZ R . lre $s{e gnyg{ng am M y e1 1_ 0704 Pgpwer gpen clng(1)(80kkf".o {ce Nh ores- re l sure in a ance with pro-
$ Eh c osec ,,40 o 0 .e;ve kV in-2 crease s toppe/d.
0710 Transition ;o eme ge procedure for p _ R 0713 DC "k"eS or p lg(RCPIsecure lant t Pumps . 0757 Technica' Support Center activatec . 0800 girgj,ector aligned to con-
"abkity act$"ak5d Nc'e 4*bNN1 Odo 1218 Residual Heat Removal (RHR) ,
System placed in service. l Nc'e 5 OC$c hhuEo' n3" 1336 Event terminated. i
i NOTES ' No. automatic actuintion of pr:marv or seconc ary safety re lef Valves Tota radioactivity rel. ease , 0.265 C es d oss e Iva r e Xeno.n fr.e ease om tursine an air eject r) 0. p.f Technical Specifications imits (' nstan".aneous) I s l e
~ ~ - - _ - - _ _ _ _ _ _ _ .
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Virginia Power ' l North Anna Power Station Unit 1 Primary-to-Secondary Leak Event July 15,1987 l Preliminary Sequence of Events E , l (Prior to 0630, unit 1 operating at 100S of full power) Time Event Description a' .arr.n Receivet annunciato' gcytton 0630 _ine on Bain St o ,eam
. and "
Koniaprs.qd ine F y 1c'rs were un ! bleam Line
,A,ert onitpr bl-b was)in "High Alarm" alarm l e
t 6 m.
.y. .
,l 0631 Contrgl Room,0perator g(5ZR:$heI aid *' $$fe dec eag p". moderr.e ' rate.
@ I0g{(C act'orkooYanI 0633 Unit 1 letdown is is.olated and ciarging pump sucP. ion re-
- h. r"a fa $ h, ,
min. was ' j' g g g w n o I h,e r and u[bI!N psig,!in Ap ssNeat 00 ;
~
h fi $ "I ectkcn si PZR Ein0Y k le0eflis's"k" tla D , 6*
}}yyW'tGMr 0650 yolateri feedwater flo3 (p ."C" '
h./ e $lEcasin 'he - kg f$ h!p c).Ihr5!hi-E
~ .. ; #:I I l 0701 Secured P.ZR heat.er; PZ1 . PZR ee ,j_ Pressg e gnc(gsing anc , I d 0704 pen eng(1)yPypwer 00kkf;o reduce Nk ores- { sure in a dance with pro- j c osfc"f.h
, Olf; evehIkVin- ' J crease stopped.
o eme ge 1 0710 Transition"f;or p TR 4
- procedure _
DC #beS or lant ! 0713 Y figy(RCPIsecure Pumps . l 0757 Support Center Jegh ica 0800 ir jegtor aligned to con-
" 48MtyEmgggg0peradons
~
"8 * *
%'4NNJfd!$""
1218 Residual Heat Removal (RHR) System placed in service. Nhe SYdfc hhuk o*hnY 1336 Event terminated. I g
FR y l J NOTES
- automatic actuation of '
' No'marv pr or secontary safety i re ;ter Valves , e l "ota'5 0.26 Cradinact ossvity e rel. iva ,ase r e(sr. ease om l Xeno.n-L turune an air eject r) 0. 1 l l p.f Tech
.imits (nical Specifications instan'.aneous) ,
1 l 1 i e 9 4 s a
NAPS UFSAR 5.2-30 All parts of the reactor coolant pump in contact with the reactor coolant are austenitic stainless steel except for seals, bearings, and special parts. ) The portions of the steam-generator in contact with the reactor coolant water are weld overlay clad with austenitic stainless steel. The steam-generator tubesheet is weld clad with Inconel; and the heat-transfer tubes are made of Inconel. Table 5.2-20 summarizes the materials of construction of these components. The reactor coolant piping and fittings that make up the loops are austenitic stainless steel. All smaller piping that comprises part of the reactor coolant system boundary, such as the pressurizer surge line, spray and f relief lines, loop drains, and connecting lines to other systems are also austenitic stainless steel. All valves in the reactor coolant system that are in contact with the l coolant are constructed primarily of stainless steel. Other materials in contact with the coolant, such as materials for hard surfacing and packing, are special materials. I The welding materials used for joining the ferritic-base materials of the l l reactor coolant boundary conform to or are equivalent to ASME Material f Specifications SFA 5.1, 5.2, 5.5, 5.17, 5.18, and 5.20. They are tested and a qualified to the requirements of the ASME Code, Section III. The welding l materials used for joining the austenitie stainless steel base materials of the reactor coolant boundary conform to ASME Material Specifications SFA 5.4 and 5.9. They are tested and qualified according to the requirements { stipulated in Section 5.2.5. The welding materials used for joining nickel-chronium-iron alloy in similar base material combination and in dissimilar ferritic or austenitic base material combination of the reactor coolant boundary conform to ASME j Material Specifications SFA 5.11 and 5.14. They are tested and qualified to the requirements of ASME Code, Section III, and are used only in procedures that have been qualified to these same rules.
)
3l' ro u -e,- si B//7 _ ---- - - - - - - - - - - - - - - - - J
i i NAPS UFSAR 5.2-95 4 i Table 5.2-20 , REACTOR COOLANT PRESSURE BOUNDARY MATERIALS , i Component Type. ,- Rcactor vessel components Shell and head plates (other SA 533 Grade A. B, or C; Class 1 or;2 than core region) (vacuum treated) Shell, flange and nozzle forgings SA 508 Class 2 or 3 nozzle safe ends SA'182 Type F304 or F316 weld buildup j e-CRDM appurtenances - upper head SB 166 or 167 and SA 182 Type F304 i Instrumentation tube SB 166 or 167 and SA 182 Type F304,- appurtenances - lower head F304L, or F316 Closure studs, nuts, and washers SA 540 Class 3 Grade B23 or B24 Core support pads SB 166 with carbon less than 0.10% Monitor tubes and vent pipe SA 312 or 376 Type 304 or 316 or SB 167
~
Vessel supports, seal ledge SA 516 Grade 70 quenched and tempered or Nuk SA 533 Grade A, B, or-C; Class 1 or 2
-(vessel supports may be of weld metal buildup of equivalent strength)
Cladding Stainless steel weld metal analysis A-7 and Ni-Cr-Fe weld metal F-Number 43 i Heat lifting lugs SA 212 Grade B Steam-generator components Pressure plates SA 533 Grade A, B, or C; Class 1 or 2 l Pressure forgings SA 508 Class 2 or 3 Nozzle safe ends Stainless steel weld metal analysis A-7 Channel heads SA 216 Grade WCC or SA 533 Grade A, B, or ' C; Class 1 or 2 Tubes SB 163 Ni-Cr-Fe, annealed i Cladding Stainless steel weld metal analysis A-7 and Ni-Cr-Fe weld metal F-Number'43 Closure bolting SA 540
k*4 NAPS UFSAR 5.5-14 vary in depth by plus or minus 3/8 in, without affecting the weld. This is measured by a stainless steel dipstick. g-
. 1 5.5.1.4.2.4 Wald Cross-Section Configuration. The higher the current or I '
heat input and the lower the heat output, the greater the dilution of weld metal with base metal, causing a more round barrel-shaped configuration as compared to welding with less heat input and higher heat output. This would cut the amount of dilution to provide a more narrow barrel-shaped configuration. This is also a function of section thicknesses; the thinner the section, the more round the pattern that is produced. 5.5.1.4.3 Welder Qualification j i Welder qualification in accordance with ASME Code, Section IX, 1965, is required, using transverse side bend test specimens per Table Q.24.1. 5.5.2 STEAM CENERATOR l 5.5.2.1 Design Bases 1 Steam generator design data are given in Table 5.5-3. -The design j sustains transient conditions given in Section 5.2.1. Estimates of d radioactivity levels expected in the secondary side of the steam generators I during normal operation, and the bases for the estimates, are given in Chapter 11. The rupture of a steam-generator tube is discussed in Chapter 15. The internal moisture separation equipment is designed to ensure that moisture carryover does not exceed 0.25% by weight' under the following conditions: 1. Steady-state operation up to 100% of full-load steam flow, with water at the normal operating level. 2. Loading or unloading at a rate of 5% of full-power steam' flow per min in the range from 15% to 100% of full-load steam flow.
NAPS UFSAR 5.5-15 L 3. A step-load change of 10% of full power in the range from 15% to l'00% full-load steam flow. The steam-generator tubesheet complex meets the stress limitations and fatigue criteria specified in the ASME Code, Section III, as well asrgency eme condition limitations specified in Section 5.1. Codes and materials requirements of the steam-generator are given in Section 5.2 The steam generator design maximizes integrity against - hydrodynamic excitation and failure of the tubes for plant life. 3 The water chemistry in the necessary boron content reactor side is selected to provide the for reactivity control and to minimize the corrosion of reactor coolant system surf aces. given in Table 5.5-4. The water chemistry of the steam side is 5.5.2.2 Design Description The steam generator shown in Figure 5.5-3 is a vertical shc31 and U
-tube evaporator with integral moistuce separating equipment.
The reactor coolant flows through the inverted U-tubes, entering and leavingethrough nozzles th located in the hemispherical bottom head of the steam generator . The head is divided into inlet and outlet chambers by a vertical partition from the head to the tubesheet. plate extending Manways are provided for access to both sides of the divided head. Steam is generated on'the shell side and flows upward through the moisture separators to the outlet nozzle at th The unit is primarily carbon steel. e top of the vessel. plate are Inconel and the interior surfacesThe heat-transfer of the tubes and the divider reactor coolant channel heads and nozzles are clad with austenitic stainless of the tubesheet . The primary steel side is weld clad with Inconel. Feedwater flows from a feedring into the annulus formed eby and the sh ll tube bundl.a wrapper before entering the boiler section of th e steam generator. Subsequently, a water-steam into the steam drum section. mixture flows upward through the t b u e bundle and A set of centrifugal moisture located above the tube bundle, separators, ! removes most of the entrained water f rom the
. . . e i
NAPS UFSAR 5.5-16 ! e steam. Steam dryers increase the steam quality to a minimum of 99.75% (0.25% moisture). The moisture separators recirculate water that mixes with feedwater as it passes through the annulus formed by the shell and ' tube bundle i i wrapper. The steam drum has two bolted and gasketed access openings for inspection and maintenance of the dryers, which can be disassembled and removed through the opening. 5.5.2.3 Design Evaluation o 5.5.2.3.1 Forced Convection The limiting case for heat-transfer capability is the " nominal 100% ; design" case. The steam generator ef f ective heat-transfer coef ficient is i based on the coolant conditions of temperature and flow for this case, and 1 includes a conservative allowance for tube fouling. Enough tube area is <! selected to ensure that the full design heat removal rate is achieved. j 1 5.5.2.3.2 Natural-Circulation Flow j The steam generators that provide a heat sink are at a higher elevation l than the reactor, core, which is the heat source. Thus, natural circulation of { reactor coolant is ensured for the removal of decay heat. j 5.5.2.3.3 Tube and Tubesheet Stress Analyses i Tube and tubesheet stress analyses of the steam generator are given in Section 5.2. l Calculations confirm that the steam-generator tubesheet will withstand I the loading (which is quasistatic rather than a shock loading) caused by a loss of reactor coolant. 1 I O; t
5.5.2.3.4 Corrocion O , No significant general corrosion of the Inconel tubing is expected during the life of the unit. Corrosion tests show a worst-case rate of 15.0 mg/dm in the 2000-hr test under simulated reactor coolant chemistry conditions. The conversion of this rate to a 40-year plant life gives a corrosion loss of 1.3 x 10~ in., which is insignificant compared to the minimum wall thickness. Comparable tests with Inconel-600 exposed to simulated steam-generator water chemistry have shown equally low general corrosion rates. Testing to investigate the susceptibility of heat exchanger construction materials to stress corrosion in caustic and chloride aqueous solutions has indicated that Inconel-600 has excellent resistance to general and pitting-type corrosion in severe operating water conditions, hence its selection for ese in the steam generator. 5.5.2.3.5 Flow-Induced Vibration O In the design of Westinghouse steam generators, consideration has been given to the possibility of vibratory failure of tubes due to mechanical or flow-induced excitation. This consideration includes a detailed snalysis of the tube supporting system as well as an extensive research program with tube vibration model tests at the Westinghouse Research and Development ! Laboratories. The major cause of tube vibratory failure in heat exchanger components is that resulting from hydrodynamic excitation by the fluid outside the tube. Consideration is given by Westinghouse to the following three regions where the possibility of flow-induced vibration may exist:
- 1. At 2.
the entrance of downcomer feed to the tube bundle (cross flow). Along the straight sections of the tube (parallel flow). 3. In the curved tube section of the U-bend (cross flow). From the description of these regions, it is noted that two types of flow exist: cross flow and parallel flow. For the case of parallel flow, analysis
. NAPS UFSAR 5.5-18 is done to determine the vibratory deflections. The analysis of the steam-generator tubes indicates the flow velocities to be sufficiently below that required for damaging fatigue or impacting vibratory amplitudes.
Therefore, the support system is deemed adequate to preclude parallel-flow
~
excitation. For the case of cross-flow excitation, it is noted in the literature that several techniques for the analysis of the tube vibration exist. The design problem is to ascertain that the tube natural frequency is well above the vortex shedding frequency. In order to avoid resonant vibration, adequate tube supports are provided. Because the problem of cross-flow-induced vibration was of major concern o* in the design of shell and tube heat exchangers, Westinghouse has given consideration to the experimental evaluation of the behavior of tube arrays under cross flow. While consideration was given to instrumentation of actual units in service, the hostile environment would limit the amount and quality of information obtained theref rom. As a result, it was deemed prudent to undertake a research program that would allow the study of fluid elastic vibration behavior of tubes in arrays. A wind tunnel was built specifically for this purpose and Westinghouse has invested approximately 3 years of research into the study of this problem. The research facilities for the tube vibration study have expanded with the construction of a water tunnel facility. The results of this research confirm the vortex shedding mechanism. More significant, however, is the evaluation of a fluid elastic mechanism not associated with vortex shedding. This is not commonly understood from the literature and could be a source of vibration failure. Westinghouse steam generators are evaluated on this basis in addition to the aforementioned techniques and were found to be adequately designed. Testing has also been conducted using specific parameters of the steam generator and the results show the support system to be adequate. Summarizing the results of analysis and tests of steam-generator tubes for flow-induced vibration, it can be stated that a check of support adequacy has been made using all published techniques believed appropriate to heat exchanger tube support design. In addition, the tube support system is i
NAPS UFSAR 5.5-19 I
.g consistent with accepted standards of heat exchanger design used throughout l the industry (spacing, clearance, etc.). Furthermore, the design techniques .
are supplemented with a continuing rer,earch and development program to ! understand the complex mechanism of concern. r Se rvice experience of Westinghouse PWR steam generators shows that flow-induced vibration and cavitation ef fects do not cause tube thinning. Preliminary estimates of tube degradation f rom erosion / corrosion mechanisms indicate that approximately 2.5-mils wall thinning (2-mils primary, 0.5-mil secondary side) will result over the 40-year lifetime, o. The effects of vibration, erosion, and cavitation have been given consideration, and the stress limitations for each category have been met.. The analysis of LOCA blowdown forces on as-fabricated U-tubes has shown that the maximum bending load elastic stress intensity -is well below the faulted condition limit. The maximum bending load elastic stress intensity'(based on the nominal tube wall thickness) would still be below the faulted ~ condition limit. Therefore, as a minimum, at least 2.5-mils (per wall) thinning can be O tolerated without exceeding the allowable stress limits. Vibration effects are eliminated during normal operation by the supporting system. Under LOCA conditions, vibration is of a short duration and there is no endurance problem. 5.5.2.4 Tests and Inspections The steam generator quality assurance program is given in Table 5.5-5. Radiographic inspection and acceptance standard are in accordance with the requirements of Section III of the ASME Code, 1968. Liquid penetrant inspection is performed on weld-deposited tubesheet cladding, channel head cladding, tube-to-tubesheet weldments, and weld-deposited cladding. Liquid-penetrant inspection and acceptance standards are in accordance with the requirements of.Section III of the ASME Code, 1968. O
+
,c .
NAPS UFSAR 5.5-20 4 Magnetic particle inspection is performed on the tubesheet forging, J channel head casting, nozzle forgings, and the following weldments:
- 1. Nozzle to shell. "
- 2. Support brackets.
- 3. Instrument connections (primary and secondary). ~
- 4. Temporary attachments af ter removal.
- 5. All accessible pressure containing welds after hydrostatic test.
4 Magnetic particle inspection aad acceptance standards are in accordance with the requirements of Section III of the ASME Code, 1968. on An ultrasonic test is performed on the tubesheet forging, tubesheet cladding, secondary shell, and head plate and nozzle forgings. 1 The heat-transfer tubing is subjected to eddy current test. i 1 Hydrostatic tests were performed in accordance with Section III of the ! i ASME Code, 1968. In addition, the heat-transfer tubes are subjected to a hydrostatic test pressure, before installation into the vessel, which is not less than 1.25 times the primary-side design pressure multiplied by the ratio of the material allowable stress at the testing and design temperatures. Manways are to provide access to both the primary and secondary sides. A specific plan for inservice inspection of steam generator tubes is not available. Because of the activity in the channel head and the large number of tubes involved, tube testing is done on a per plant basis. The extent of tube testing planned in any particular plant will depend on tube performance l to date, the channel head activity, and the results.of tube sample testing. Inservice inspection of the steam-generator tubes is not planned at this time, " but the eddy current testing method is available. O
- ~
_ , . . . . x a H
=
I NAPS UFS/.h 5.5-81 l l O Table 5.5-3 STEAM GENERATOR DESIGN DATA Parameter Value Design pressure, reactor coolant side, psig 2485 Design pressure, steam side, psig 1085 Design temperature, reactor coolant side, 'F 650 Design temperature, steam side, 'F 600 Total heat transfer surface area, f t 51,500
. .s Maximum moisture carryover, wt %
0.25 Overall height, ft-in. 67-8 Number of U-tubes 3388 U-tube o.d., in. 0.875 Tube wall thickness, nominal, in. 0.050 Number of manways 4 1.d. of manways, in. 16 Number of handholes 2 1.d. of handholes, in. 6 Table 5.5-4 STI;AM-CENERATOR WATER (STEAM-SIDE) CHEMISTRY SPECIFICATION (BLOWDOW _Pa rame t e r Value pH (normal operation) 25*C 8.5 to 9.0 Cation conductivity, maximum micromhos at 25'c 2.0 I 1 l D
) NAPS UFSAR .- 5.5-82 m
Table 5.5-5 i l
- STEAM GENERATOR QUALITY ASSURANCE PROGRAM Examination RT UT PT MT ET
, Tube sheet i Forging Yes Yes Cladding Yes* Yes Channel head g4 Casting Yes Yes Cladding Yes Secondary shell and head Plates Yes Tubes Yes Yes Nozzles (forgings) Yes Yes Weldments Shell, longitudinal Yes Yes Shell, circumferential Yes Yes Cladding (channel head-tubesheet joint cladding restoration) Yes Steam and feedvater nozzle to shell Yes Yes Key: RT = radiographic UT = ultrasonic PT = dye penetrant MT = magnetic particle ET = eddy current
" Flat surfaces only.
b Weld deposit areas only. 0,
**' NAPS UFSAR 5.5-83 Table 5.5-5 (continued)
O STEAM GENERATOR QUALITY ASSURANCE PROGRAM Examination RT UT PT MT ET k'eldments (continued) Support brackets Yes Tube to tubesheet Yes Instrument connections (primary and secondary) Yes Temporary attachments after removal Yes After hydrostatic test (all welds and complete channel head, where accessible) Yes Nozzle safe ends (if forgings) Yes Yes Nozzle safe ends (if weld deposit) Yes Key: RT = radiographic UT = ultrasonic PT = dye penetrant MT = magnetic particle ET = eddy current O
NAPS UFb.R Figure 5.5-3 i i STEAM OUTLET MOZZLE UPPER HEAD f h! l l c .a p' .:" UPPER SHELL 3C i i
- I :
m l >C , l ,, FEEDWATER RING % o _Z~ D! N j : g TRANSITION CONE J WRAPPER I TUBE %; J
] : ANT l-V IBRAT ION BARS
@ l$
LOWER SHELL
, !M TUBE SUPPORTS l, :
l lm .
",!'N STAYROD N l'l ,
l 1 i , SUPPORT PAD s msm w s[ TUBE SHEET PR IMARY INf.ET N0ZZLE CHANNEL HEAD 1 8 51 SERIES STEAM GENERATOR l
) FEURE 2 Tube Support Plate /Tubesheet Nomenclature E B A t -
2AVB 3AVB g 1AVB % 4AVB 7H- % -.
--7C 6H ,,,,,,,,,,,,,
6C q-c7 0 o SH SC l
,' ,' n , . 4 1, 4H 4C '
, u ,-
_g , SH 30 9. c(- . 2H 2C mamn"""" 1C 1H P: - .< f d HTS
~~ ~~"
i (: . , q,. ; , Westinghouse e Series 51 Inlet ! Outlet
l FIGURE 2.3-1 TUBE DAMAGE LOCATIONS DETAll OF THROUGH-WALL
, j DAMAGE IN AVB ZONE e
I ,
' * ' ' ~~~ imuum uiuun
]
~
M (..I j [ AVB'S u Y ROW 1 U-BEND TANGENT l POINT CRACKING ANTIVlBR ATION B ARS \ ( AV B'S)
- TUBE BUNDLE q
TUBE SUPPORT PL ATES - 1 IGC AT SUPPORT PLATE
~ INTERSECTIONS DENTING & IGC AT 3 TOP OF TUBE SHEET 3
s c \ FRETTING DAMAGE AT TUBE
, LANE BLOCKING DEVICE TUBE SHEET u
@ SERIES 51 STEAM GENERATOR 46 REVISION 0
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